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Home My WebLink About204-143 �4. Alaska Oil andGas or �'� THE STATE ti� i � ®.fLAsicA Conservation Commission z _ = 333 West Seventh Avenue ®� ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov November 8, 2017 Mr. Tim Jones Cook Inlet Energy, LLC 1 -; 1,2.4 `1 r1 ; 601 W. 5th Avenue, Suite 310 NE° Anchorage, AK 99501 Dear Mr. Jones: The Alaska Oil and Gas Conservation Commission did not witness the surface abandonment of WF-1 (PTD 1610490), WF-2 (PTD 2041430), and WF-3 (PTD 2140030) but accepts photos of cement to surface, casing cutoff, and marker plate installed on each well prior to burial. In lieu of a separate location inspection, AOGCC accepted photographs taken after burial of the abandoned wells and clean-up of the aforementioned West Foreland drill sites. The provided photographs show the West Foreland drillsites to be in compliance with onshore location clearance requirements as stated in 20 AAC 25.170. In addition, an onsite inspection by landowner, Cook Inlet Regional Inc., was completed, and accepts the pad as left. The AOGCC requires no further work on the subject wells or locations art this time. However, Cook Inlet Energy, LLC remains liable if any problems were to occur in the future with this well. Sincerely, Hollis S. French, Chair, Commissioner • • Link, Liz M (DOA) From: Regg,James B (DOA) Sent: Tuesday, October 31, 2017 4:21 PM To: Colombie, Jody J (DOA); Link, Liz M (DOA) Subject: RE: Ciri's Plan of Abandonment for West Foreland Gas Wells We did not witness the surface abandonment of these wells but accepted photos of cement to surface, casing cutoff, and marker plate installed on each well prior to burial. Copies of emails with photos attached should be in well files for the following wells: - /'WF�-1 (PTD 1610490J 'WF-1—(PTD 204143000 WF-3 (PTD 2T40030) We have also not done a location clearance inspection but can accept the letter from CIRI/Salamatof in lieu of that. I recommend preparing a location clearance approval letter to CIE for our records. Doesn't really accomplish anything other than closing out the well history record unless the WForeland field has a separate bond instead of a blanket bond covering all Cook Inlet Energy operations. Jim Regg Supervisor, Inspections AOGCC scANNED 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 orjim.regg@ialaska.gov. From: Colombie,Jody J (DOA) Sent:Tuesday, October 31, 2017 3:48 PM To:Seamount, Dan T(DOA) <dan.seamount@alaska.gov>; Foerster, Catherine P (DOA)<cathy.foerster@alaska.gov>; French, Hollis (DOA) <hollis.french@alaska.gov>; Ballantine, Tab A(LAW) <tab.ballantine@alaska.gov>; Regg,James B (DOA) <jim.regg@alaska.gov>; Bettis, Patricia K (DOA)<patricia.bettis@alaska.gov>; Schwartz, Guy L(DOA) <guy.schwartz@alaska.gov> Subject: Ciri's Plan of Abandonment for West Foreland Gas Wells ,Toctti/ T. Colbmble l(. CC"Special:.Ass tans Alaska- Oil and (las Conner'val.ion Co IV mi s'i n _>.5 13'est .;1venue ,Anchorage, _Alaska 995ot Off Ike: (0o7) 793-1221 :Tax: (907) 276-7542 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged 1 RBDIVIS - 1 2017 • • a0L-/ / 2/ .3 44tysALAMA14F _ \ .:soe' C IR ' 1/44.4ctti sic October 25, 2017 Hollis French,Chair sF , Alaska Oil and Gas Conservation Commission ""� �`� 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Plan of Abandonment for West Foreland Gas Wells, Lease C-060324/ADL 392210,ADL 359111, and ADL 359112 Dear Chairperson French: Cook Inlet Region Inc. (CIRI)and Salamatof Native Association, Inc. (SNAI)have received an abandonment plan from Glacier Oil and Gas Company indicating its intent to plug and abandon those wells related to the above referenced leases and leave in place for future development opportunities the West Foreland Gas Pad (WFGP). SNAI and CIRI reviewed the proposed plan for abandonment and also inspected the site after the approved P &A plan was executed. Please accept this letter as consent for leaving the WFGP in place as it currently exists. Respectfully, SALAMATOF NATIVE ASSOCIATION, INC Christopher Monfor President COO/,�INLET REGION, INC 6 -ezei,.1it-df,&-.__, Colleen Miller Manager Resources • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned E] Suspended lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑✓ Exploratory ❑ GINJ ❑ WINJ ❑ WAGE] WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6.Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: COOK INLET ENERGY LLC Aband.: 9/5/2017 204-143/317-349 ' 3.Address: 7.Date Spudded: 15.API Number: 601 W.5th AVE.SUITE 310,ANCHORAGE,AK,99501 9/17/2004 50-133-20542-00-00 ' 4a.Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 886'FSL,571'FEL,Sec.21,T8N,R14W,SM 11/4/2004 WEST FORELAND#2 Top of Productive Interval: 9.Ref Elevations: KB: 25' 17. Field/Pool(s): West Foreland 2933'FNL,898'FEL,Sec.21,T8N,R14W,SM GL: n/a BF: n/a Field/Tyonek Undefined 4.2 Total Depth: 760'FNL, 1146'FEL,Sec.21,T8N,R14W,SM 10.Plug Back Depth MD/TVD: 18.Property Designation: surface , AG3g4ADL 359112 4b.Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 191452 y- 2475582 Zone- 4 11387'MD/9853'TVD • Salamantof Native Assoc. TPI: x- 190162 y- 2477051 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 189967 y- 2479229 Zone- 4 n/a n/a 5.Directional or Inclination Survey: Yes LJ (attached) No E] 13.Water Depth,if Offshore: 21.Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 n/a (ft MSL) n/a 22.Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper,resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary n/a RECEIVED SEP 13 2017 AOGCC 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT. TOP BOTTOM TOP BOTTOM PULLED 20' n/a N/A 25' 145' 25' 145' Driven n/a none 13 3/8" 68# L-80 25' 3003' 25' 3001' 17 1/2" 761sx lead,508sx tail none 7 5/8" 29.7# P-110 25' 8490' 25' 7973' 9 7/8" Stage 1:238 bbls none 7" 29# N-80 8490' 11380' 7973' 9849' 9 7/8" Stage 2:270 bbls none 24.Open to production or injection? Yes ❑ No 2 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number;Date Perfd): 2 3/8"(long string) 10304' 10304'MD/9198'TVD 2 3/8"(short string) 8302' 8283'MD/7838'TVD fk(' '"C)""''"-)0 26.ACID,FRACTURE,CEMENT SQUEEZE, ETC. SCANNED N°V 0 3 NOV201Z Was hydraulic fracturing used during completion? Yes ❑ No ❑ 5/11 Per 20 AAC 25.283(i)(2)attach electronic and printed information �` DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED L L- 27. 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): n/a Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period ..... Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate . . Form 10-407 Revised 5/201/' CONTINUED ON PAGE 2 Submit ORIGINIAL o 1°/3//> 7J 7-2-7 i7 RBDMS ill/ SEP 2 1 2017Ci • 28.CORE DATA Conventional e(s):C • Yes ❑ No ❑ Sidewall Cores: Yes ❑ No ❑ If Yes,list formations and intervals cored(MD/TVD,From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑ Permafrost-Top If yes,list intervals and formations tested,briefly summarizing test results. Permafrost-Base Attach separate pages to this form,if needed,and submit detailed test Top of Productive Interval information,including reports,per 20 AAC 25.071. Formation at total depth: T�0h4-11—' i 10-4411- 31. 0.4•Il31. List of Attachments: Summary of daily operations,wellbore schematic,photo of cut off,photo of welded abandonment marker,photo of backfill Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Conrad Perry Contact Name: Amanda Dial Authorized Title: Sr i residentContact Email: adial@glacieroil.com Authorized Contact Phone: 907-433-3808 Signature: Date: 9/13/2017 INSTRUCTIONS General: This form and th e u red att ments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 II comple n report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 1b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 19: Report the Division of Oil&Gas/Division of Mining Land and Water:Plan of Operations(LO/Region YY-123),Land Use Permit(LAS 12345), and/or Easement(ADL 123456)number. Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results,including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only . • GLACIER RECEIVED SEP 13 2017 September 13t', 2017 ��G� Mr. Hollis French, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Well Completion Cook Inlet Energy, LLC: West Foreland#2 Permit to Drill NO: 204-143 API No: 50-133-20542-00-00 Dear Mr. French, Cook Inlet Energy(CIE)hereby submits a Well Completion Report for the abandonment of West Foreland #2. The work performed was covered under Approved Sundry 317-349. CIE requests the official status of West Foreland#2 be changed to P&A. If you have any questions, please contact me at(907) 727-7404. Sincerely, Conrad Pe Sr. Vice President Cook Inlet Energy, LLC (a Glacier Oil & Gas Corp. owned company) 10-407 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax • • West Foreland #2 Daily Operations Summary API: 50-133-20542-00-00 PTD#: 204-143 Date Activity 10 Aug 2017 Rig up and pump 1 gallon of cement each down long string (2B) and short string (2A) chemical injection lines. 13 Aug 2017 RU and pump 20 gallons of produced water down 0.25" capillary strings in long string (2B) and short string (2A). 15 Aug 2017 RU cementers on 2-3/8" short string (2A), 165 psi tubing pressure. Pump at 3 bpm with 8.3ppg water and catch fluid at 47 bbls pumped. Kill short string, short string (2A)tubing pressure = 0 psi. Long string (2B)tubing pressure =0 psi. Rig up Spooling unit on 2-3/8" Long string (2B). Test pull line. Strip and pull 10330ft of 0.25" Dyna Coil from long string. Rig down Spooling Unit. 16 Aug 2017 Rig up Spooling unit on 2-3/8" Short string (2A). Test pull line. Strip and pull 8330 ft of 0.25" Dyna Coil from short string. Rig down Spooling Unit. RU cementers on 2-3/8"tubing long string(2B) and pressure test surface lines. Pump at 2.5 bpm with 8.3 ppg water and catch fluid at 26.5 bbls away. Establish injection rate of 1.2 bpm at 3000 psi. Prepare for pumping cement. 17 Aug 2017 RU cementers on 2-3/8" tubing long string(28).Mix and pump 21.5 bbls (66 sx) of 13.0 ppg cement at 1.4 bpm. Displace with 30 bbls of water, final pump pressure of 0.5 bpm, 3300 psi. CIP 08:15. (PLUG #1—Cement through long string between packers). RU slickline on 2-3/8" tubing 9'16) short string (2A). RIH with 2-3/8" PXN Plug to 2770' WLM, unable to vy pass tight spot, POH. RIH with 1.99" wireline brush to 8330' and work through tight spots as needed, POH. RIH with 2-3/8" PXN plug to 8202' WLM, X-nipple, unable to pass, POH. Redress plug and add knuckle joint, RIH with 2-3/8" PXN plug and worth through to 8276' WLM. Set plug in XN-nipple, POH. Confirm plug set. RD lubricator. (PLUG #2— Isolate perfs through short string). 18 Aug 2017 RU wireline on short string (2A). RIH with prong and set in PXN plug at 8276' WLM, POH. RD wireline. RU Eline on short string (2A). RIH with 1- 9/16" tubing punch, 4 spf, 10 shots, 0 phase, and perforated from 8265.7'—8268' MD, good indication of fire, POH. Confirm all shots fired. RD Eline. RU cementers on short string (2A) and pressure test surface (' lines. Pump water down short string and up annulus for 33 bbls, confirm 21Page • returns and circulation through tubing punch. Mix and pump 10 bbls (31 sx) of 13.0 ppg cement at 3 bpm and displace with 30.5 bbls water. CIP at 14:30. Wash up and RD cementers. (PLUG #3—placed cement on top of top packer). rA '7G, m 19 Aug 2017 RU Slickline on short string tubing (2A). RIH with 1.85" GR and tag TOC at 7650_KB, POH. RD from short sting and RU on long string (2B). RIH with 1.75" GR and tag TOC at t 7154' KB, POH. RD slickline. . -7 7 II 23 Aug 2017 RU cementers on OA (7-5/8"x 13-3/8" annulus) and pressure test surface lines. Pump water down annulus at 0.5 bpm, increasing rate to 1.5 bpm, catch pressure at 16.2 bbls away. Establish injection at 3 bpm at 1350 psi. Prep for pumping cement. 24 Aug 2017 Finish prepping for pumping cement down OA. Pump 15.9 bbls of water at 2 bpm to verify injectivity in OA ahead of cement. Mix and pump 284 DP( bbls (1146 sx) of 14.5 ppg cement at 2 bpm, 1360 psi. CIP at 12:50. ,Lumped all available cement in bulk truck. Wash lines and RU cementers 9_0 on IA (2-3/8" x 7" annulus). Pressure test surface lines. Conduct in-house pressure test on IA to 1600 psi. While monitoring IA pressure, increase of pressure on Short string tubing noted. Bled off pressure on both. Re- pressure up on IA to 1620 psi and short string pressure increased to 280 psi as IA decreased to 1589 psi over 30 mins. Bleed down pressure. Swap lines and line up to pump into Short string (2A) and monitor IA. Pressure up on short string to 1625 psi while monitoring IA,tubing decreased to 1550 psi and IA increased to 20 psi. Increase short string pressure to 1700 psi, pressure dropped to 1618 psi and IA increased to 50 psi. Pressures held for 30 mins. Attempt to increase pressure on IA to match short string pressure, short string pressure increase immediate. Bleed off pressures from short string and IA. Notify AOGCC Rep, Mike Quick, of communication between Short string and IA. Receive approval from Mike Quick to pressure test Short stringtubing and IA together for witnecsPr1 pre sIlrP tPct 26 Aug 2017 RU pressure test pump on long string. Pressure test long string tubing ? /� (2B)to 1650 psi for 30 mins and chart same—good. RU pressure test pump on short string with gage on IA (2-3/8" x 7" annulus) to monitor. Pressure test short string to 1640 psi with 245 psi on IA, for 30 mins an chart same—good. Pressure tests witnessed by AOGCC Rep, Matt Herrera. RD pressure test pump. RU Eline on short string (2A). RIH with 1-9/16"tubing punch, 4 spf, 10 shots, 0 phase, and perforate from 630' —632.3' MD, good indication of fire, POH. Confirm all shots fired. RU Eline on Long string. RIH with 1-9/16"tubing punch, 4 spf, 10 shots, 0 637e 31Page • • phase, and perforate from 630'—632.3' MD, good indication of fire, POH. Confirm all shots fired. RD Eline. 27 Aug 2017 RU Cementers on short string and long string, pressure test surface lines. Prep and mix 20 bbls Viscous polymer pill. Pump 0.5 bbls of water down short string tubing, taking returns through IA, confirm circulation. Pump 0.5 bbls of water down long string tubing, taking returns through IA, confirm circulation. Pump 2.4 bbls of pill down short string at 0.5 bpm. Switch to long string and pump 17.6 bbls of pill taking returns through the IA. Displace long string with 0.6 bbls of water, switch to short string and displace with 0.6 bbls of water. Wash lines and RD cementers. 28 Aug 2017 RU Eline on short string. RIH with 1-9/16"tubing punch, 4 spf, 10 shots, 0 phase, and perforate from 203.7'—206' RKB, good indication of fire, POH. Confirm all shots fired. RU Eline on Long string. RIH with 1-9/16" tubing punch, 4 spf, 10 shots, 0 phase, and perforate from 203.7' —206' MD, good indication of fire, POH. Confirm all shots fired. RD Eline. RU cementers to both long string and short string, pressure test surface �. lines. Mix and pump 9 bbls (36 sx) of 14.4 ppg cement down short string_ ' taking returns through IA. Switch to long string and pump 9 bbls (36 sx.) of 14.4 ppg cement down long string taking returns through IA. Pump remaining 49 bbls (197 sx) of 14.4 ppg cement until returns at 12.9 ppg cement. CIP at 17:30. Wash lines and RD cementers. 31 Aug 2017 Excavate dirt from around cellar. Pull cellar. Continue excavation. Prep area for welder. Cut wellhead at 44" below native soil/original ground level. Cement to surface in short string, long string, and IA. Cement 6" below cut in 7-5/8" x 13-3/8" annulus. Cement 3 ft down from cut in 13- 3/8" x 20" annulus. 3 Sept 2017 Mix and cement 13-3/8"x 20" annulus with approx. 2 cuft of cement. Prep for plate weld. 5 Sept 2017 Receive verbal approval from AOGCC Rep, Jim Regg, to weld Abandonment plate on well. Provided photos of plate, cement at top, depth of cut from original ground level, and video of cement competency. Weld Abandonment marker plate on well. Send photo of welded plate to Jim Regg. Receive verbal approval from AOGCC Rep,Jim Regg, to back fill hole. 6 Sept 2017 Back fill hole and level area. 41Page . • • West Foreland#2 Final P&A Schematic 9/13/2017 Forest O4F Fattened 02 284 bbls of 14.5 ppg cement 0 411111.411014{ NavertlUer 9014 .:p • •: ,, pumped down 7-5/8"x 13- Surface Plug:67 bbls 14.4 ppg I'I 5p� cI 3 3/8"annulus " J s. cement pumped down SS&LS, e LMAI !. 20-Cznauexr tit 145 II21 i Yi up annulus 7. Viscous Pill Tubing Punch in LS @ 203-206" TubingPunch in SS @ 203'-206' w . 133'8.88&L-8I Surface Camp Rr 6. at 3.003'. Cemented to sultioe , Tubing Punch in SS @ 630'-632' ( I Tubing Punch in LS @ 630'-632' 2 1'Innen stllmn Int tam v P. f 3'U'29.744,0.110 Gawp at 8,480 In sbsltsprg it 2,100" 'ICS` 1, Icraacs cvcr li r aawpbibwt in long Wring of ZBOW 11;I - - . _ r� - 2 3V'4 7iii.,-po TF.H.Turarg :Win wirings:. 2-1441'it fareargnppax• t TOC tagged @ 7154'in long string; ":„.•In r'tnrir.^rinq al 8.230 TOC tagged @ 7650'in short string 1 7. In 1512n8 bintgi rt:8.29 i' 1^ :,,,:::,,;.. kf X / 10 bbls of 13 ppg cement pumped down SS/up Tubing Punch in short s,i string @ 8265'-8268' k, r' HESTyas Mel eat pleat41.2e3 PXN Plug set @ 8301' Ctj — t • ; "+ 2-3+'B'Landry-umes Short staid 2-3Wt.EG at&.3Q2 µ 18• — ,'MIn Short sire.X4 al C 301' gt , In Wig6^fng x et 6297' 2-3:il'bast feints SAS.'.5 551' _- - i F"arb-a:ers 6494.6,ea3' f f •. HEti Type WO 6raductl51 pk+at 73.900 • :A,::: 2 a'a'XN taming NPCP al.10 321 4.�,w'r:p easy 10.328-10.383 r-- Petfemearts 10. 75-18353 Bull nose at 10.384' +•+ta.y 21.5 bbls of 13.0 ppg cement pumped down LS • • " r(; •. _ -- St C.-n1rrD+eiaepot;10.6at"-'uiii n' ',..A., _—_ Z ~- Prtcrahens 16425' 114 niso sr „f ttQ.. ❑ante calm'at 11 255' i. i. f 124 of ani-hlcc atm track •_• lbw -1.1„,.........r.- 1.-. no,y Be c ,,,,,r i i 363 Intact Calnwy r - - i Ceira-tca wi:n 102 Cas Cw:x 6 O. *.1:',0., ;At , # --,."1.0 Z;''' .;... a.. . #14i:' *.s 'Clk . 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V,0 .,' '' I ',A 1) 4 z "lit' e • ! 214 t 430 Regg, James B (DOA) From: Regg,James B (DOA) Sent: Tuesday, September 5, 2017 3:34 PM1\e �' ,1-7 To: Production Field Superintendent Subject: RE: AOGCC Test Witness Notification Request: P &A, Cook Inlet Energy, West Foreland Field,wells 1, 2 and 3 Thank you for sending the pictures. You can proceed with burying the abandoned wells. Jim Regg Supervisor, Inspections AOGCC SCANNED tib 2 >,; 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From: Production Field Superintendent [mailto:prodfieldsupt@glacieroil.com] Sent:Tuesday, September 5, 2017 3:31 PM To: Regg,James B (DOA)<jim.regg@alaska.gov> Subject: RE: AOGCC Test Witness Notification Request: P&A, Cook Inlet Energy,West Foreland Field, wells 1, 2 and 3 Jim, Attached are pictures of the marker plates welded to the 20" casings of WF#1, WF#2 and WF#3. When I get confirmation from you that this satisfies the P&A I will start filling the holes back in. Thanks and regards. Dan From: Regg,James B (DOA) [mailto:jim.regg@alaska.gov] Sent:Tuesday, September 05, 2017 10:18 AM To: Production Field Superintendent<prodfieldsupt@glacieroil.com> Subject: RE: AOGCC Test Witness Notification Request: P&A, Cook Inlet Energy,West Foreland Field, wells 1, 2 and 3 As discussed this morning, AOGCC witness is waived. Send photos/video evidence showing cutoff depth, competent cement to surface, and marker plate (info, before and after installation). Jim Regg Supervisor, Inspections AOGCC 1 } • • AOGCC Memorandum Date: 9/5/2017 To: West Foreland#2 (PTD 2041430) From: Jim Regg of S(l Supervisor, Petroleum Inspections Subject: Surface P&A Attached are photos provided by Cook Inlet Energy (CIE) documenting the surface abandonment of West Foreland#2. Photos show the cut-off depth below original ground level, cement to surface, the information included on the marker plate, and the marker plate welded onto the casing stub. 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'-hl*, T , , , w +Iry;,k4 l n 1Ar .m 4j . ` i r tpa'8.. . . , ` :--„,,,,.,, .. .-..;.,-:.'!-,-.b;:f,,,..„..{'"'.”',.. 1 o - �. •� . ' i ^4. •,d 31+ . ° ... .. y >t �Y ; 4. F{4g�6K ♦ '+ � `, Y e tx }. t-.i..„.1:7;:-.41,741.,,,,:,' jr ifix ^ y,, ,�6 P ak!rsr-:.:.� � ' ' � ha .,4,d7..-4e: rtr� ? •i 5' Y� Yr�:, 1 ` � „ ,i ,',If‘Ni '.-? 4baaa� .,#.7 J,r ,t, ...N1. j v'�id7, .£ r . , • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ."-ZC 11'l O DATE: August 26, 2017 P.I. Supervisor SUBJECT: Well Bore Plug &Abandonment West Foreland #2 , FROM: Matt Herrera Cook Inlet Energy Petroleum Inspector West Foreland PTD# 2041430 - Sundry# 317-349 Section: 21 Township: 8N - Range: 14W - Meridian: Seward - Drilling Rig: n/a - Rig Elevation: n/a ' Total Depth: 11387 ft MD . Lease No.: ADL359112(BH) Operator Rep: Mike Murray Lease No.: FEDA35017 (Surf) Casing/Tubing Data: Casing Removal: Conductor: 20" O.D. Shoe@ 145 Feet(MD) Casing Cut@ Feet Surface: 13 3/8" O.D. Shoe@ 3003 - Feet(MD) Casing Cut@ Feet Intermediate: 7 5/8" - O.D. Shoe@ 8490 - Feet(MD) Casing Cut@ Feet Production: O.D. Shoe@ Feet Casing Cut@ Feet Liner: 7" O.D. Shoe@ 11380 - Feet(MD) Casing Cut@ Feet Tubing: 2 3/8" - O.D. Tail@ 10304 - Feet(MD) Casing Cut@ Feet Plugging Data: Type Plug Founded on Bottom of T.O.C. Depth T.O.C. Mud Weight Pressure (bottom up) Cement Verified? above plug Test Perforations Balanced , 7650 ft SS , Wireline Tag 13.0 " 1650 psi - 7154 ft LS - Wireline Tag 13.0 " 1650 psi - Type Plug Founded on: Verified? Open Hole Bottom Drillpipe tag Perforation Bridge plug Wireline tag Annulus Balanced C.T. Tag -,, c �2,'r7, Casing Stub Retainer No SCANNED I F.:B 0 / " F Surface It was determined from a prior pressure test on the Short String (SS)tubing there was communication with the IA. The Long String (LS) tubing was pressure tested to 1650psi for 30 minutes(chart recorder)-test held tight. The SS tubing was pressure tested to 1650psi as '' well: the IA started at 230psi and came up to 250psi while the SS tubing pressure dropped to1550psi. Pressure was held and recorder for 30 minutes. The chart recorder was a Barton Dry Flow Meter from IISCO with cal due date 11/10/2018 cc: none Attachments: none rev.4-20-16 2017-0826_Plug_Verification_WForeland-2_mh 1111. • II V OF 4,-.„1,7,,--„, s THE STATE Alaska Oil and Gas �� _ _ =__:... _ -y_2��—''�, Of LAsIKA. Conservation Commission 'er„-= ___ 333 West Seventh Avenue ” - TI — r Anchorage, Alaska 99501-3572 T GOVERNOR BILL WALKER e'4 Main: 907.279.1433 OF SyC2' Fax: 907.276.7542 www.aogcc.alaska.gov Conrad Perry Sr. Vice President Cook Inlet Energy, LLC SChos) AUG 1 1'�` ' 601 W. 5th Ave., Ste. 310 Anchorage,AK 99501 Re: West Foreland Field, Tyonek Undefined 4.0 and 4.2 Gas Pools, West Foreland 2 Permit to Drill Number: 204-143 Sundry Number: 317-349 Dear Mr. Perry: 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 AOGCC grants for good cause shown,a person affected by it may file with the AOGCC 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, a7-4 Cathy . Foerster Commissioner DATED this 3'`�day of August,2017. RBDMS L(AUG - 9 2017 • • • f STATE OF ALASKA p7, r /�" ALASKA OIL AND GAS CONSERVATION COMMISSION UL 2 7` 17 �, APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCC 1.Type of Request: Abandon 0 • Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing El Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: COOK INLET ENERGY,LLC Exploratory ❑ Development Q. 204-143 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 601 W 5TH AVE#310,ANCHORAGE,AK 99501 50-133-20542-00-00• 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A+ Will planned perforations require a spacing exception? Yes ❑ No ❑., 1 WEST FORELAND#2•' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 359112 % FFA .5o/7 qx} WEST FORELAND,TYONEK UNDEFINED 4.0 GAS,TYONEK UNDEFINED 4.2 GAS 1 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): 9551 Junk(MD): 11387 < 9853 . 10646 . , 9415 3497 psi None None Casing Length Size MD TVD Burst Collapse Structural Conductor 145' 20" 145' 145' N/A N/A Surface 3003' 13 3/8" 3003' 3001' 5020 psi 2270 psi Intermediate 8490' 7 5/8" 8490' 7973' 9470 psi 5340 psi Production 2890' 7" 11380' 9849' 8160 psi 7020 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8494'-8529', 10371'-10383' • 7976-7994',9241'-9249' 2 3/8"6.5#(both same) N80 short:8302'/long: 10304' Packers and SSSV Type: HES RDH dual pkr Packers and SSSV MD(ft)and TVD(ft): ' 8283'MD/7838'TVD HES WD pkr . 10304'MD/9198'TVD 12.Attachments: Proposal Summary U Wellbore schematic [d 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑✓ - Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 8/7/2017 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown El Abandoned Q , r d re approved I hereby certify that the foregoing is true and the p oce u herein will not be deviated from without prior written approval. Authorized Name: Conrad Perry Contact Name: Amanda Dial Authorized Title: Sr.Vice s'dent Contact Email: adial@glacieroil.com Contact Phone: 907-382-0124 Authorized Signature: t!�/ Date: tfl"1/ l COMMN UBE ONLY Conditions of approval: Notify Commission so that representative may witness Sundry Number: fli) / Plug Integrity WI BOP Test ❑ Mechanical Integrity Test p❑ Location Clearance Other: []� Other: j pi � ..�.ti a(3 e-f.. . .� c: ..5 t C.•u t•e C ej e.O f€( , Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS �v AUG - 9 101/ Spacing Exception Required? Yes ❑ No ®' Subsequent Form Required: r o / L APPROVED BY O Approved by: e(_.. COMMISSIONER THE COMMISSION Date: p—3— )7 `'Y 712 0- ,e eil7 0RIGINAL / Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval Attachments in Duplicate • • RECEIVED GLACIER JUL 2 7 2017 July 25th, 2017 AOGCC Mr. Hollis French, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage,Alaska 99501 RE: Application for Sundry Cook Inlet Energy, LLC: West Foreland #2 (PTD 204-143) Dear Mr. French, Cook Inlet Energy, LLC, hereby applies for a Sundry for West Foreland #2 well located on ADL 035017, requesting to permanently abandon the well, leaving the completion in place and completing the operations rigless. If you have any questions, please contact me at (907) 727-7404. Sincerely, Conrad Perry Sr. Vice President Cook Inlet Energy, LLC (a Glacier Oil & Gas wholly owned company) 601 W. 5th Avenue, Suite 310 Anchorage,AK 99501 1 • GLACIER 1. WELL NAME - West Foreland #2 Well Summary Current Status: West Foreland#2 is shut-in. Current pressures are SS= 160 psi; LS=0 psi; IA=0 psi; OA=0 psi Current Perforations: 9336'-9352'MD 9504'-9524'MD Scope of Work: • Check tubing and all annulus pressures. • Rig up cement unit.Test lines to 2500 psi. • Bullhead produced water down short string to kill well. • Rig up Capillary string pulling unit or alternative. 1-5 • Pull capillary string from short string and long s ring. rL 1e -` '51-4 ''`` • Rig up cement equipment. • Abandonment Plug#1: Pump 21.5 bbls 12.5 ppg cement down long string. • WOC.Pressure test tubing/cement to 1500 psi for 30 mins and chart same. • Abandonment Plug#2: Pump 289 bbls 12.5 ppg cement down 13 3/8"x 7 5/8"annulus. • Rig up Slickline. • Abandonment Plug#3: Set plug in Short string at 8301'. • Tubing punch short string at 8275'. • Abandonment Plug #4: Circulate 8 bbls 12.5 ppg cement down short string tubing and up annulus, placing 200'cap on top of packer at 8283'. • WOC.Pressure test tubing/cement to 1500 psi for 30 mins and chart same. • Tubing punch short string and long string at 200'. A..5/5�( 64- le S F=.P. • Abandonment Plug#5:Circulate 10 bbls 12.5 ppg cement down tubing and up annulus,placing 200'cap at surface. • WOC.Check well dead on all valves.Remove tree.Recover cellar. • Cut casing 3'below original ground level.Weld on ID CAP.Backfill pad to grade. General Well Information: Reservoir Pressure/TVD: 4039 psi @ 9249'TVD/10383'MD MASP: 3115 psi 2 • • GLACIER 1. WELL NAME - West Foreland #2 Well Summary Current Status: West Foreland#2 is shut-in. Current pressures are SS = 160 psi; LS = 0 psi; IA= 0 psi; OA= 0 psi Current Perforations: 9336'- 9352' MD '7 9504'-9524' MD - Scope of Work: • Check tubing and all annulus pressures. • Rig up cement unit.Test lines to 2500 psi. • Bullhead p o duced water down short st ng to kill well. • Rig up Capilla string pulling unit. • Pull capillary st .ngs from short str. g and long string. • Rig up slickline a test lubricato, to 3500 psi. • Abandonment Plug • 1: Set plu", n XN nipple at 9459'. • Open sliding sleeve at 8291'. • Establish injection rate , r4 gh sliding sleeve. n • Abandonment Plug#2: : 4 lhead 9.5 bbls 12.5 ppg cement(9221'- 9423' MD) ! • Abandonment Plug#3• :ul i ead 210 bbls 12.5 ppg cement down 13 3/8"x 9 5/8" annulus. • Abandonment Plug#, : Bullh•.d 132 bbls 12.5 ppg cement down 9 5/8"x 7" annulus. • Fill control line wi cement to t andrel at 2939'. • WOC. Pressure t-.t tubing/cemen. to 1500 psi. • Tubing punch . 7090'. • Abandonmen• Plug#5: Circulate 7 bb 12.5 ppg cement down tubing and up annulus,placing 200' cap on top of p. er at 7095'. • WOC. Pre ure test tubing/cement to 1501 'si. • Tubing nch at 200'. • Aband nment Plug#6:Circulate 10 bbls 12.5 p.; cement down tubing and up annulus,placing 200'cap at su ace. • W .Check well dead on all valves. Remove tree. R- over cellar. • Cut casing 3'below original ground level.Weld on ID AP. Backfill pad to grade. General Well Information: Reservoir Pressure/TVD: 4039 psi @ 9249'TVD/ 10383' MD MASP: 3115 psi �rO PP�d Aohcf-/04 f t)r 74 welt 443 2 r COycvr, !Wm, tt Wag pcoI'-c1?. T/1// • • • GLACIER Wellhead Type/Pressure Rating: Vetco Grey— 5000 psi—Wellhead&Tree BOP Configuration: Lubricator Well Type: Gas Producer Estimated Start Date: August 7, 2017 Drilling Manager: Drilling Engineer: Production Manager: Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907) 433-3808 (907) 433-3822 cperry@glacieroil.com sratcliff@glacieroil.com dkumar@glacieroil.com Program 1) Give 48 hours' notice to AOGCC for plugging ops. 2) Check tubing and all annular pressures. 3) Rig up to short string and pump produced water to kill well. a. Verify well is dead. 6,1".e"LW- - o 4 ) Rig up capillary pulling truck. �� G S� 1...e7P1 eke ctt�. ( 5) Pull 0.25" capillary string set at 10330' in Long tubing string. 6) Pull 0.25" capillary string set at 8330' in Short tubing string. 7) Rig down capillary pulling truck. ioo ) Rig up to 2 3/8" long string tubing. Test lines to 2500 psi. 5-(N 9) Establish injection rate with water. Monitor annulus pressures. 10) Pump 21.5 bbls of 12.5 ppg cement and displace cement with 30 bbls water. a. Estimated TOC inside tubing—8000'. P 11) Rig up cement unit to 13 3/8" x 7 5/8" annulus. Test lines to 2500 psi. 12) Establish injection rate with water. Max allowable injection pressure is 1500 psi. a. If no injection call town. 13) If Injection is established, cement 13 3/8" x 7 5/8" annulus with 289 bbls of 12.5 ppg cement. 14) WOC—Test tubing to 1500 psi for 30 mins and chart same. 1-0106 S7X/A1e1 15) Rig up Eline on short string. Test lubricator to 3500 psi. 16) Set 2 3/8"XN plug in Short String in XN nipple at 8301'. 17) Tubing punch short string at 8275'. 18) Rig up to 2 3/8" short string tubing. Test lines to 2500 psi. 19) Establish circulation down tubing up annulus. 20) Pump 8 bbls of 12.5 ppg cement, displace with 30 bbls of water capping packer at 8283' with 200' of cement. a. Estimated TOC in short string tubing—7760'. b. Pump 1 gallon cement into chemical injection lines. 21) WOC—test tubing and annulus to 1500 psi for 30 mins and chart same. 65/1.57/,4 - , # tic 3h 3 • • , GLACIER l. 'Pc�- (-`` Sit 5 22) Rig up Elin and perforate both tubing strings at 200'. 23) Establish circulation. Pump cement until good returns to surface+/- 10 bbls. fait 24) Rig down cement unit. WOC. �5 5,: DI 25) Nipple down tree. 26) Dig out to 8' below original ground level. Ensure grade is sufficient to allow safe access for welder to cut casing. / 27) Cut casing 3' below ground level. ____-- Ai. 4- . 7-ye dor -/-i, t✓;1-,c.- - a. Top up with cement if it's not to surface in all casing strings. 28) Install well cap as follows: (1) is constructed of steel that is at least 1/4 inch thick; (2) is welded to, and covers,the outermost casing string, including the conductor casing; (3) does not extend beyond the outermost casing string; and (4) contains the following information bead-welded directly to the marker plate: (A)The name of the operator that plugged and abandoned the well; (B)the number assigned by the commission to the Permit to Drill (Form 10-401) for the well under 20 AAC 25.040(b); (C)the name designated for the well by the operator under 20 AAC 25.005(f); (D)the API number for the well,with any suffix appended to the number under 20 AAC 25.005(f). cCOOK INLET ENERGY 204-143 West Foreland #2 50-133-20542-00 29) Take pictures of casing stubs with cement,welded cap, and final after grading pad. Submit to town for inclusion in final report. 4 • • West Foreland#2 Current Schematic 11/1/2004 t Forest Oil Cosporation ; West Foreland C2 + �t No.emEor.26M t. ^" _.' ` I -- •..-� i ... I" n PC Gcncurx.-0145 lo'nc-i 1 I_ 13-3'B'8P.L.-03 Suture Caen; 91 3.003' Ce•nented to surface11-11 . 2-&'{I'r,i a eIeni m w7:, •ail ' r o'@' 25 r>.c i'c Gasrg a:9,4C0 In sncr,99r-9 al.ocea ! 11.i!! is !cremes cvcr to t•Gas re Gahw' .n In tong sir ng a•2,9.09' I A'li - II ' i ,.,,p 4.7it,hi-80-TRH.TUdr. i :bon sines; RuIC'X boxing moles' MO 0 I 18imp mane Nt1.2S1" wr �I r II —.,_i ' FE8 Ty;n.F.7-1 ural pr;al t.2W /�Jzi5 R I ■F=�,a�r1 �� 141144 2-3;13'larding apps. ,-,r 5 Snort siring 2-3.E•Y1�EG at 8.302' � — 4• tn short strrr�XV at 8301' ate` In hang eHing X at 6287' 0.25"Cap string @ 5330'MD L i is il F- m 2.U1.1 'baa paints H t5".5 551' - - __ PoM*a:cre B49r-@,528' a4 , •t � t • 1 '..- Ut III. H15 Typa von praduc115n pkre:12.3C.4 L!1h11` AM"'i ID .c.Etg'CF easy 10.320`-10.383' r+3. 0.25"Cap string @ 10330'MD .:;5,, ,,,..i. — Pe ferr♦eore 1031r•1C,382 Etcll nose at 10 384' Lir I. f{tj #r%:&-rr C-ni cc onklai,Avg 10.848'-'0811' _• thrld8e pugs 17,@71" '-i Pe•TaraSans 18,12'v 141GO Daffte cata•at 11 2011' 1.124'of a'nl-fil cc shoe_track -' r,log,'9 EC Gama s 11 797 wast baleel Ff t.,*e.i. . : C.e ncrrca A.e.-1oc los Gras C • • West Foreland#2 Proposed P&A Schematic 7/18/2017 Forest Oil Corporation West Foreland 02 November 207,4 *tt14411.74;,.8*“ " Ccnr..-4, 14..4 11./^toen, ' • Tubing Punch @ 200 ' 11111 mai 111111 13-3,0*dB, L-83 S1-1 feu.Casina ' at 3 OW Ce-nented tn suga= 9.8 25:a -1.0 Cairo a: 2 3,8'Nors c.we,n in,aut., Ir slcrt send at 2 BCC cro=ein parr r case;ba*.' Irlong strIG Al 215W 1111111.:1 d ii 2 3,8 4iII N-to TS/44 Tuber, 'bOri Strlig4, rar 2381 X orrarra rippes • In Woe strinra ei 0 2-03 • it',*114 r if- I- ta Iola saws'at 523' —13.#3ti t;st:' .1‘ („..,,e Tubing Punch @ 8275' 1*5 l'yoa RO-1 II 0,283 2-383*La.:arc nodes , 11116 :t In traxt strag XV at e sot Snon sInng 2-3.1*VAIG ei 302 1 lin tog fe'in3 X at 2'NA'tias:turns s ss1 ; • .0= Pertratcrt 8494 e SI:5 ckt ,. • . • 141 Hite lypa150 prof:W[1191W a"10 3C4 .;• • .0.7‘..4,..„-!! 2 24.8 XN landing nopo at'0 321 4-5.1er-0P espy 27e• _ Petransters 10 3/1 IC 383 Butt nose at 10384 21.5 bbls . • Cm,.r trild401 Plug 80 640'-,oeri Vegotations 10,/20 IC 16C7 Baffle calm-at n 255 t 1124 ta'ant Stec sheet tratik r Ate rst Bc Casna 11 3t3,:r intact hataiii. Corre-terg'wort 891 Lt.s.C1441, • • • Schwartz, Guy L (DOA) From: Amanda Dial <adial@glacieroil.com> Sent: Tuesday,August 01, 2017 4:52 PM To: Schwartz, Guy L(DOA) Subject: RE:West Foreland#2 P&A (PTD 204-143) Attachments: Sundry- 10-403 -WF-02 - P&A 2017 - Page 2.pdf Guy, Attached is the corrected work scope page. Thank you for accepting it via email. The cap string will be handled similar to the methanol string. And yes,the short cap string will be pulled using proper well control. Thank you, Amanda Dial Office:(907)433-3818 Cell:(907)382-0124 From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Tuesday,August 1,2017 4:13 PM To:Amanda Dial<adial@glacieroil.com> Subject: RE:West Foreland#2 P&A( PTD 204-143) Amanda, You can just resubmit a new work scope page via email.. I will update the sundry. You can also leave capillary string in the long string as it will not impact the cement plug. It should be handled similar to the methanol string(pump cement into it). As far as pulling the short string capillary string with a crane...fine as long as proper well control is still used. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Amanda Dial [mailto:adial@glacieroil.com] Sent:Tuesday,August 01,2017 3:16 PM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Subject: RE:West Foreland#2 P&A( PTD 204-143) Guy, 1 • You are correct.The scope of work did not get corrected for WF 2. It is a copy ofthe Scope from WF 1. Thank you for catching that. Would you like it to be corrected and that page resent? I also actually have another question regarding the WF#2 Program. Per the submitted program,I planned to use a capillary string pulling unit.I learned yesterday that the unit will not be available for this job. Without the unit,the cap strings will likely need to be pulled utilizing a crane.I'd like to change the program to leave the cap string in the long tubing string. We will address the cap string at surface in addition to the methanol injection line and pump the 21.5 bbls of cement down the long string since this can be completed without pulling the capillary string.Leaving the cap string in the long tubing string will save significant operational time. The rest of the program will stay the same,i.e.the cap string will be pulled from the short string tubing with a crane since we need access to set a plug and punch the tubing. Please let me know if a Change Program Sundry is needed to approve this request. Thank you, Amanda Dial Office:(907)433-3818 Cell:(907)382-0124 From:Schwartz,Guy L(DOA) (mailto:guy.schwartz@alaska.gov] Sent:Tuesday,August 1,2017 2:47 PM To:Amanda Dial<adial@glacieroil.com> Subject:West Foreland#2 P&A( PTD 204-143) Amanda, Can you relook at the"Scope of work"summary section of your sundry for this well. It does not follow the procedure steps and may have some carry over from the other wells. The procedure steps itself is fine. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). 2 :27% — %V3 4 Y � " . ;, t TOO8N R014W LAA ` /'1. -1West McArthur E w River Production iI .11 Facility Fra t 1 >' t�� i f West _ .-" ° `°.��,+ f McArthur '°` ) 1 ! • 1 •• River Unit '4. °ill* Tract 1 (ADL " .! 359111) '"`4 #,.101 West ` k �� McArthur Y, f ,. , c I1: ..'• joi\ '+ . River Unit %� ,� •,�> ADL 392210 Tract 2 (ADL \..', ' (State 359112) , f , _4„,.,041' 1 • )2 1 ir • ,. • .•• Subsurface) ir. , '1 • ( :14 '''''. '4:;;Illars;1• , ' ' I.* ,1 jilt+ ,.. 1,1,1; f +M. 4"".. [West Foreland Pad "4.4`• •, ... •' • ,• `> J w • f *!. 00— ) ,,, S;;$,,_,! i root , .0i a` B CIRI Lease C-060324 4 ' . z / �t t Salamatof Surface/CIRI --- - 44:r1 i Subsurface 1 , II.. L'i._. a sCANNED JAN 2 2 2015 16 15West 14 McArthur River Unit Tract 1 (ADL 359111) WF-3 West McArthur River Unit Tract 2 (ADL 21 22 23 359112) WF 3 Proposed Wellbore I 1 West Foreland Pad I 1 28 27 26 Scale=1'.21112 0 1000 2000 3000 ft -ice Davies, Stephen F (DOA) From: Tim Jones <Tim.Jones@cookinlet.net> Sent: Monday, January 05, 2015 9:12 AM To: Davies, Stephen F (DOA) Subject: RE: West Foreland 1,2, and 3 Surface Lease Question Attachments: Map for WF 3 POO New CIRI Lease Number.pdf Steve, I hope you had a good weekend. Here is a simple ownership map that shows the boundaries of C-060324 and ADL 392210 in relation to ADL 359111 and 359112.The surface locations for all the West Foreland wells are from the West Foreland Pad. I looked at that purple shape, queried it, and looked in the legend, and I do not know what it is. It is approximately where the West Foreland Pad is located but the shape is not exactly right. I hope this helps. If you need more detail please let me know. Tim From: Davies,Stephen F(DOA) [mailto:steve.davies@alaska.gov] Sent: Friday,January 2, 2015 5:15 PM To:Tim Jones Subject: RE: West Foreland 1,2, and 3 Surface Lease Question Tim, Here's what I'm struggling with. The map on the left is from my workstation. It shows the surface location of the West Foreland 1, 2, and 3 wells in the SE corner of Section 21. The screen on the right is from the DNR's webmapper application, and it shows Section 21 at approximately the same scale. State lease ADL 392210 consists of the two purple cross-hatched polygons near the center of the section. The orange-colored dot represents the surface locations of the three wells. These surface locations lie within a light purple- shaded polygon. The legend on DNR's map doesn't explain what the light purple shading represents. Do you know what it represents? Does the onshore portion of Section of 21 belong entirely to CIRI with the exception of the two areas that constitute State lease ADL 392210? This shows why I'm hoping that CIE can provide a better land plat for Section 21. 1 Clookato Coci_lsift,.ro,K1PormekCCINIICOMPAALIPACII rm34u01.1.1`rr+,,.,w4r.4 0410#i�. fsr ssw.l+Yur.Fwn...ws 1 - 1 fM `F+w 1,4 I$ - W$, fsH;v.,. iryn t.ANiSh i,rr C..,. ,..,.. V H1 O a las II MID ft r- ?\ e**4 `a N LR++ :J• X • d i. a,....w« vnn%w.0.Ovens r+Juuewz - kr ,c: , t%maser.• W M N U 4 ��.«.,., Mc.R' - WEST F( — J , km I'k city. e et tit W FOR: LAND 2 A f..i.,...aaywsn ■ S- 0 OtelitIP■ X w+�i.noirir J ■ Aim am..M.NY 11J rm.Lk 6131Ms9001 asa dr .ORELAND 1 f ti..:i..i�$2 - ..$.45122) tae 1, -_ _. 1111.1101110111.111111111.1 ,*set ,m • n o - by ■ t it lila .c. T„,; * r ._...... _ 'ET* T --.- l Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7`h Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Tim Jones [mailto:Tim.Jones@cookinlet.net] Sent: Friday, January 02, 2015 4:14 PM To: Davies, Stephen F (DOA) Cc: Bettis, Patricia K (DOA); Dianna Lewis Subject: RE: West Foreland 1,2, and 3 Surface Lease Question Hi Steve, 2 Thanks, happy New Year to you too! The lease in question, A-035017,was initially conveyed to CIRI on October 26, 1982, and the former Native allotment contained in 3 US surveys within the boundaries of the A-035017 lease was conveyed to the State on October 2, 2009. The BLM managed this lease in trust for CIRI and the state of Alaska until it waived administration of the lease on January 25, 2012. I have attached a copy of the Amended Decision waiving BLM administration of the A-035017 lease. The new CIRI lease number is C-060234 and the State lease number is ADL 392210.The legal descriptions for each are contained in the attached letter. If you have any questions regarding this issue, please let me know.Thanks. Tim From: Davies,Stephen F(DOA) [mailto:steve.davies@alaska.gov] Sent: Friday,January 2, 2015 2:36 PM To:Tim Jones Cc: Bettis, Patricia K(DOA) Subject: West Foreland 1,2, and 3 Surface Lease Question Hi Tim, Happy New Year! While quality checking AOGCC's database today, I noticed on BLM's ACRES website that Federal Lease A 035017 has a status of"case closed." This particular lease contains the surface locations of wells West Foreland 1, 2, and 3. BLM's case abstract for the lease doesn't mention conveyance of the land, at the bottom of the file, it merely notes that the mineral interest ownership is now CIRI=0.941503 STATE OF ALASKA= 0.058497 FEDERAL OWNERSHIP=0 Could you please help clarify this? Is this now a CIRI lease? If so,what is CIRI's lease number for this property? Could you please provide a legal description for this parcel of land? Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 3 2 - /44 gNT pp United States Department of the Interioreirmit4 1J `o BUREAU OF LAND MANAGEMENT 'T " tRCH � ,� Alaska State Office TN KMERIE' AA 222 West Seventh Avenue, #13 Anchorage, Alaska 99513-7599 �` E.G -,•- http://www.ak.blm.gov , f — r-' A035017 COOK INLET" 3111 (AK930) ENERGY CERTIFIED MAIL RETURN RECEIPT REQUESTED February 29, 2012 AMENDED DECISION Cook Inlet Region Inc Attn: Land and Energy Development: P.O. Box 93330 Anchorage, Alaska 99509 State of Alaska, Dept of Natural Resources Division of Oil & Gas, Attn: Wendy Woolf 550 W. 7th Ave., Suite 1100 Anchorage, Alaska 99501 Cook Inlet Energy LLC Walter J. Wilcox, II 605 W. 5th Ave., Suite 310 Anchorage, Alaska 99501 Federal Oil and Gas Lease Administration Waived This decision amends the Decision Waiving Administration on Federal Oil and Gas Lease dated January 25, 2012. The purpose of this decision is to amend subsurface legal descriptions and capture in part, actions taken by the Bureau of Land Management as part of this waiver. On October 26, 1982, the Bureau of Land Management(BLM) issued Interim Conveyance 561 and Patent 50-83-0007 for the subsurface estate including oil and gas to Cook Inlet Region Incorporated (CIR1) on lands where the surface was conveyed to Salamatof Native Association Incorporated. On October 2, 2009, the Bureau of Land Management (BLM) issued Patent 50-2010-0004 for all of the coal and oil and gas and 50-2010-0005 for the oil and gas to the State of Alaska(SOA) on lands where the surface was conveyed to Alaska Native Allotees in Certificates 50-97-0273 and 50-66-0510. 2 The subsurface estate including all oil and gas is no longer owned by the United States and the United States has no residual interest or benefit derived from the lease which would justify continuing the federal administration of the lease. Pursuant to Section 14(g)of the Alaska Native Claims Settlement Act, as amended, and pursuant to Section 6(h) of the Alaska Statehood Act, as amended, this decision hereby waives administration of federal lease A035017 to CIRI and to the State of Alaska as co-tenants as agreed upon in the Memorandum of Agreement signed by the SOA, CIRI, and the BLM, and made effective on August 1, 2011 (MOA). The BLM accepted from Cook Inlet Energy LLC (CIE)two Certificates of Deposit in increments of$500,000 totaling $1,000,000 in satisfaction of the bonding requirement under the Bankruptcy Order. The BLM worked with CIRI, the SOA, and CIE to redeem the Certificates of Deposit to enable CIE to file suitable replacement bonding acceptable to CIRI and the SOA. The CIRI subsurface as it pertains to federal lease A035017 located in T. 8 N., R. 14 W., Seward Meridian, Alaska is: Section 16 41.00 acres Section 21 305.00 acres Section 22 2.27 acres Section 27 93.73 acres Section 28 360.00 acres U.S. Survey 4524 Lot 1 5.00 acre Total 807.00 acres. The SOA subsurface as it pertains to federal lease A035017 located in T. 8 N., R. 14 W., Seward Meridian, Alaska is: U.S. Survey 4523 5.00 acres U.S. Survey 11865 35.00 acres U.S. Survey 4522 10.14 acres Total 50.14 acres The total lease acreage for lease A035017 is: 857.14 acres. As of the effective date of the bankruptcy sale in the matter of Pacific Energy Resources Ltd., case no. 09-10785 in the U.S. Bankruptcy Court for the District of Delaware, December 11, 2009, lessees and/or operators pay rentals and royalties for the above lease to CIRI for their portion of the lease and to the State of Alaska for their portion of the lease. As agreed upon in the MOA, CIRI and the SOA entered into amended and restated royalty sharing agreements associated with the A035017 lease in which the U.S. Department of the Interior is not a party. 3 If you have any questions regarding this Decision, please contact Carol Taylor at 907-271-4402 or me at 907 271-4407. Wayne-Svejnoha Branch Chief, Energy & Minerals cc: Office of Natural Resource Revenue Salamatof Native Association Alaska Oil and Gas Conservation Commission Bureau of Indian Affairs SOA, DNR, Division of Mining, Land & Water, Attn: Jerri Sansone · . Image Project Well History File Cover Page XHVlE 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. JQ Lt - lId-.3 Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: Lf.s-c¡ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES ~ Date: J lal J07 Organizing (done) ~wo-sided III II 11111111 1/"" RES CAN ~olor Items: ~reYSCale Items: o Poor Quality Originals: DIGITAL DATA o Diskettes, No. )2(6ther, NolType: G 1/ J o Other: NOTES: Date II,?J /07 Date I/ð/j 07 J Li:) x 30 = LJ.SO + Date: JL~J J 07 BY: ~ Project Proofing BY: ~ Scanning Preparation BY: ~ BY: Stage 1 If NO in stage 1, page(s) discrepancies were found: BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: o Rescan Needed III /I 111111 II III III OVERSIZED (Scannable) o Maps: ~ther Items Scannable by J-~ 6 a Large Scanner .... J OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: m,P 151 111111111111111111I 151 mp ~ = TOTAL PAGES ~ (Count does not include cover sheet) J AA {J 151 I'rt/-- 111111111111111111I NO 151 Y11p NO YES 151 III 1/11111111111111 III 1/11111111111111 151 Quality Checked 111111111111 1111111 10/6/2005 Well History File Cover Page.doc • • sluf[E oy n[LnsEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 June 24, 2011 Mr. David Hall Cook Inlet Energy 601 West 5 Avenue Anchorage, AK 99501 Re: Safety Valve System Testing JON 2 4 2 D 1 L Dear Mr. Hall: The Alaska Oil and Gas Conservation Commission (Commission) finalized and readopted revisions to well safety valve system (SVS) regulations — 20 AAC 25.265 — that became effective on December 3, 2010. In conjunction with those regulations, the Commission also published Industry Guidance Bulletin 10 -004 ( "Safety Valve Systems ") dated December 16, 2010. Weblinks to both documents were provided to Cook Inlet Energy (CIE) on December 30, 2010 by electronic mail with a request to establish a single - point -of- contact and to identify for the Commission the months CIE intends to test its well SVS. A response was requested by January 21, 2011. A second reminder was provided to CIE on February 11, 2011. CIE has not responded to the Commission's request. A review of Commission production records indicates the following CIE wells have produced during the first six months of the effective date of the readopted SVS regulations and therefore the SVS should have been tested not later than June 3, 2011: - West McArthur River Unit 1A (PTD 1951180) - West McArthur River Unit 2A (PTD 1931550) - West McArthur River Unit 5 (PTD 1980470) - West McArthur River Unit 6 (PTD 200107) - Kustatan Field 1 (PTD 2001530) - West Foreland 2 TD 204143 C� I The Commission requests the following not later than July 8, 2011: 1) SVS tests performed on the above - listed wells since December 3, 2010; the Commission provided CIE the proper SVS test report forms by electronic mail dated June 1, 2011; 2) CIE's schedule for testing wells in the West McArthur River, West Foreland, Kustatan, and Redoubt fields; 3) CIE single - point -of- contact for SVS matters. Mr. David Hall • • June 24, 2011 Page 2 of 2 You are reminded that a functional SVS must be installed, maintained and tested as described in 20 AAC 25.265 for all completed wells except water source wells, disposal injectors, observation wells, and those wells that are isolated from the flowline. Performance testing of the well SVS must be conducted semi - annually. Depending on well location, the Commission must be notified at least 24 to 48 hours prior to testing for an opportunity to witness those tests. Failure to comply with the SVS test requirements may result in the Commission pursuing enforcement action. Please direct any questions regarding SVS testing requirements to Jim Regg at 907 - 793 -1236. Sincerely, (11 Cathy P Foerster Commissioner From: Saltmarsh, Arthur C (DOA) Sent: Monday, March 09, 2009 11:08 AM To: Maunder, Thomas E (DOA); Seamount, Dan T (DOA); Davies, Stephen F (DOA); Roby, David S (DOA); McMains, Stephen E (DOA); Williamson, Mary J (DOA); Regg, James B (DOA); Fleckenstein, Robert J (DOA); Colombie, Jody J (DOA); Gary Carlson; Norman, John K (DOA); Foerster, Catherine P (DOA); Laasch, Linda K (DOA); IongmereC~verizon.net Subject: FW: Pacific Energy files chapter-11, it's official!!! FYI. c~C~~-\- \`-t~ PACIFIC ENERGY RESOURCES LTD. Via, ~ r5 ,~;;,v~~;,;?~'~~ ~~`~ `' ~~~~ 111 West Ocean Blvd., Suite 1240 Long Beach, California 90802 Telephone: (562) 628-1526; Fax: (562) 628-1536 Files for Chapter it to Facilitate a Restructuring LONG BEACH, CALIFORNIA, Monday, March 9, 2009 - -Pacific Energy Resources Ltd. (the "Company")(TSX:PFE) announces today that it and its wholly owned subsidiaries have filed voluntary petitions for reorganization under Chapter 11 of the U.S. Bankruptcy Code in the U.S. Bankruptcy Court for the District of Delaware. The filing was precipitated by the dramatic decrease in the market price of oil over the past five months. Combined with the Company's pre-existing level of debt related to past acquisitions and poor capital market conditions, the Company's liquidity and cash flow is insufficient to operate its business and invest in its oil producing assets to increase production. Faced with these constraints, the Company and its subsidiaries filed petitions for reorganization under chapter 11 to facilitate access to an immediate source of liquidity as it works to restructure its debt. In connection with the filing, the Company is seeking customary authority from the Bankruptcy Court that will enable it to continue operating its business in the ordinary course of business. The requested approvals include requests for the authority to make wage and salary payments and continue various benefits for employees. In addition, the Company has negotiated a commitment for $40 million in debtor-in-possession ("DIP")financing. The DIP facility wraps and replaces two of the Company's three asset-based credit facilities and is being provided by the lenders of the two credit facilities that are being replaced. Upon Court approval, the DIP financing combined with the Company's operating revenue will provide sufficient liquidity to fund working capital, meet ongoing obligations and ensure that normal operations continue without interruption during its restructuring. About Pacific Energy Resources Pacific Energy Resources Ltd. is an oil and gas exploration and production company based in Long Beach, California, U.S.A. Additional information relating to the Company may be found on SEDAR at www.sedar.com. The Company's web site is www.PacEnergy.com. ON BEHALF OF THE BOARD OF DIRECTORS PACIFIC ENERGY RESOURCES LTD. Pacific Energy Resources Ltd. 310 K. Street, Suite 700 Anchorage, AK 99507 Office: 907-25$-8600 Fax: 907-258-8601 David Hall Alaska Operations Manager Main: 907-868-2133 Cell: 907-317-8239 dmhall pacenerQy.com www.pacener~y.com ~. ~¢ ~~~ ~,,,~ ~~ . ~~ ~_ ~;,~:, MICROFILMED 03/0/2008 DO NOT PLACE AIVY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CWrPgs_In~rts\Microfilm Marker.cbc . ~V~VŒ rm~ ~~~(~}f{~ . 4"~ASIi4 OIL AlQ) GAS CONSERVATION COMMISSION SARAH PALIN, GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501·3539 PHONE (907) 279·1433 FAX (907) 276-7542 David Hall Production Manager Forest Oil Corporation 310 K St, Suite 700 Anchorage, AK 99501 SCANNED NOY () 1 2007 Re: West Foreland Field, Tyonek Undefmed Gas Pool, West Foreland #2 Sundry Number: 307-323 Dear Mr. Hall: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may me with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ¡{day of October, 2007 Enc!. Qó4- 1'i3 .J . . Forest Oil Corporation 310 KStreet, Suite 700 RECEIVED Anchorage, Alaska 99501 (907) 868-2133 or 776-7108 Fax: (907) 258-8601 or 776-7119 OCT)'9 2007 Alaska Oil &. GtJ! Cont. Cømmi~.iøn October 16, 2007 Anr;:horlgl '~., Mr. John Norman, Chairman Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Dear Mr. Norman, Re: West Foreland #2 CaDillarv Strinq Installation: ,/ Forest Oil Corp proposes to install ~" capillary strings in both production tubing strings of the West Foreland #2 dual completion. A foaming agent will be periodically pumped through the strings to assist in production of produced water and condensate from this well. A coil tubing unit will be used to perform the installation. We anticipate the work to be performed on or about October 26. The capillary strings will be run inside the production tubing and will extend from the top of the perforations through the wellhead and out the swab valve at the top of the tree where they will be packed off. Should an emergency arise that requires the well be shut in, one of the master valves would be closed, severing the capillary strings. If you have any questions, please contact me at 868-2133. Si"y À /Jfi David Hall Production Manager Forest Oil Corporation Attachments: Sundry Application Well bore Schematic .. . t'( C\'" t: I " L. Li ú}iY(' I.~~TATEOFALASKA c.¡l}'iÐI-'ð1 t. OCT - ALASKA OIL AND GAS CONSERVATION COM SION ,u,i)h~ 1 9 Z007 APPLICATION FOR SUNDRY APPROVALSaska Oil & Gas Cons. CommissiuH 1. Type of Request: Abandon 0 Alter casing 0 Change approved program 0 2. Operator Name: Forest Oil CorDoration Suspend 0 Repair well 0 Pull Tubing 0 20 AAC 25.280 Operational shutdown 0 Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development EI.- Stratigraphic 0 Anr.horane Perforate 0 Waiver 0 Other EI Stimulate 0 Time Extension 0 Install capillary Re-enter Suspended Well 0 string 5. Permit to Drill Number: Exploratory 0 204-143 SeNice 0 6. API Number: 50-133-20542-00 3. Address: 310 K St, Suite 700, Anchorage, AK 99501 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes 0 9. Property Designation: 8. Well Name and Number: 11,387' Casing Structural Conductor Surface Intermediate Production Liner - Total Depth TVD (ft): 9,853'/ Length No EI West For:elap4f#2 /) 10. KB Elevation (ft): 11, Field/Pool(s): 'Th~ Lf¿.t.pt¿f ~ f ~~ ~ 25' AGL --rJJI. Wëst Fòreland ' 7J::. PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 10,646' " 9,415' /' MD TVD Plugs (measured): / ADL 359112 None /- lo~2-5,Ø 'I Junk (measured): None" Collapse 12. Total Depth MD (ft): " Size Burst 120' 2,978' 8,465' 2,890' 20" 145' 145' N/A N/A 13-3/8" 3,003' 3,001' 5,020 psi 2,270 psi 7 -5/8" 8,490' 7,973' 9,470 psi 5,340 psi 7" 11,380' 9,849' 8,160 psi 7,020 psi Perforation Depth MD (ft): 8494'-8529', 10371'-10383' Packers and SSSV Type: Perforation Depth TVD (ft): Tubing Size: Tubing Grade: 7975'-7994',9241'·9249' 2-3/8" (both strings) N·80 (both strings) HES Model RDH, HES Model WD Packers and SSSV MD (ft): Tubing MD (ft): 8,202' and 10,384' 8,283' and 10,304' 13. Attachments: Description Summary of Proposal EI Detailed Operations Program 0 BOP Sketch D 15. Estimated Date for 10/26/2007 Commencing Operations: 17. Verbal Approval: Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowtedge. Printed Name David Hall Title Date: 14. Well Class after proposed work: Exploratory 0 Development EI " SeNice D 16. Well Status after proposedJV,$: Oil ..' Gas ~ C~-C:>~IUgged D Abandoned WAG 0 GINJ 0 /0' WINJ 0 WDSPL o o Contact Production Manager Signature /Jf-tAÃ1 ---- .4/cLÞ' Phone Date 868-2133 /0 - /? - 0 ~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: &> 7 - 3~ Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: (.. ~ ~'t>~ "\ ~ ú..Lc:...c ~ ~ ( a-<J ~~ t.. ð.-S- \. 3- ~ <0 tt~~~'E:.<:'~'-.)~ ::. <;.\,~ "" S I ~~\ ~ I ~\>~\ ~,~\~~""' Su''''''u"", Fonn Rooui"'" , W{) \...\ caJ1'f)" I Approved by: ~MMISSIONER ~L ..- ""\ .J.or "\: -. Form 10-403 Revised 06/2006 [J.cJ~-' ,_.. ; ~{¡. \ft:. RBDMS 8Ft 0 CT 2 4 2DD7 APPROVED BY THE COMMISSION Date: If).- J1.f AJ1' ORIGINAL ¿ dL Su~t in DURlicate /h. iy~ ~p t'O ,'2, ~ . °7 I'~ ;¡t Forest Oil Corporation West Foreland #2 November, 2004 2-3/8" Nova chem inj subs: In short string at 2,800' In long string at 2,809' 2-3/8" X landin9 nipples: In short string at 8,230' I n long string at 8,231' Short string 2-3/8" WLEG at 8,302' 2-3/8" blast joints 8,491' - 5,551' 4-5/8" TCP assy 10,328" - 10,383' Bull nose at 10,384' Baffle collar at 11,256' (124' of cmt-filled shoe track intact below) J L 20" Conductor @ 145' (Driven) 13-3/8",68#, L-80 Surface Casing at 3,003'. Cemented to surface. 7-5/8",29,7#, P-110 Casing at 8,490' (crosses over to 7" casing below) 2-3/8",4.7#, N-80, TSHP Tubing (both strings) 1" DV collar at 9,260' HES Type RDH dual pkr at 8,283' 2-3/8" Landing nipples: In short string XN at 8,301' In long string X at 8,291' Perforations 8,494' - 8,525' HES Type WD production pkr at 10,304, 2-3/8" XN landing nipple at 10,321' Perforations 10,371' - 10,383' Cmt on bridge plug 10,646' - 10,671' Bridge plug at 10,671" Perforations 10,725' - 10,760' 7",29#, N-80 Casing at 11,380' Cemented with 508 bbls Class G / . . Page 1 of 1 Maunder, Thomas E (DOA) From: David Hall [DMHall@forestoil.com} Sent: Tuesday, October 23,20073:11 PM To: Maunder, Thomas E (DOA) Cc: Davies, Stephen F (DOA); Roby, David S (DOA); Rebekah Haynes Subject: RE: West Forland Sundry Applications Tom \""'l d () \..\ - \ \..\ ~ , Yes the water production is reported the same from WF1 and WF2 (LS & ST). After the individual wellhead gas flow meters the wells are routed to a common scrubber therefore we calculate water production based off the results when one of the wells was down for what ever reason. For example, in the past when WF1 was down the total water production received was reduced by 1/3. And as a result the total water production received is divided equally between WF1, WF2-LS, and WF2-ST as reported. Please do not hesitate if you have anymore questions. Thank you, David Hall David Hall Production Manager Office 907-776-7108 -868-2133 Cell 907-317-8239 Fax 907-776-7119 -----Original Message----- From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov) sent: Tuesday, October 23, 2007 12:26 PM To: David Hall Cc: Davies, Stephen F (DOA); Roby, David S (DOA) SUbject: West Forland Sundry Applications David, I am beginning to review the sundry applications for the installation of the capillary strings in the WF wells. I was curious about the water production. I have pulled the production reports for WF #1 and WF #2 Land S. The water production for all strings is reported as the same: 214 bbls for May 2007, 190 bbls for June, 234 bbls for July, 253 bbls for August and 185 bbls for September. Would you look into what appears to be erroneous information and provide corrected numbers? It may be necessary to revise how Forest is reporting production from the WF wells. Is water produced from all strings? Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 10/23/2007 • Subject: [Fwd: WF #2 Schematic & 407 Completion Rpt] From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Tue, 12 Jun 200714:47:22 -0800 To: Steve Davies <steve_davies@admin.state.ak.us> Here is an email you and I got a while back. Might have bearing on what you are doing. Tom -------- Original Message -------- Subject: WF #2 Schematic & 407 Completion Rpt Date: Thu, 19 Apr 2007 19:00:48 -0600 From: Paul Winslow <PMWinslow@forestoil.com> To: Stephen F Davies <steve davies@admin.state.ak.us> CC: Thomas E Maunder <tom maunder@admin.state.ak.us>, art saltmarsh@admin.state.ak.us Steve, Here is a copy of the 407 completion report that was submitted and a wellbore schematic that was done by Halliburton just prior to the actual completion. I can't find a later schematic, but after reviewing this one it looks to be accurate. Let me know if you need anything else. Paul Paul Winslow Sr. Reservoir Engineer Forest Oil Corporation 310 K Street, Suite 700 Anchorage, AK 99501 Work: (907) 868-2131 Cell: (907) 317-8193 Fax: (907) 258-8601 pmwinslow@forestoil.com WF #2 Completion Schematic.pdf Content-Type: application/octet-stream Content-Encoding: base64 __ _ __ _ __ WF #2 Completion 407 Rpt.pdf Content-Type: application/octet-stream Content-Encoding: base64 Forest Oil Corporation West Foreland #2 ' November, 2004 2-3/8" Nova them inj subs: In short sbing at 2,600' In long string at 2,809' 2-3/8" X landing nipples: In short string at 8,230' In long string at 8,231' Short string 2-318" WLEG at 8,302' 2-3/8" blast joints 8,491' - 5,551' 45/8" TCP easy 10,328" -10,363' Bull nose at 10,384' Battle collar at 11,256' (124' of cmt-filled shoe track intact below) ~}, ~.1'' ~~ ' ~~ 20" Contluclor (B 745' (Driven) 13-318", 6B#, L-80 Surface Casing at 3,003'. Cemented to surface. il6", 29-7#, P-110 Casing at 8,490' oases over to 7" casing below) -318", 4.7#, N-80, TSHP Tubing loth strings) ' DV cotlar at 9,260' ES Type RDH tlual pkr at 6,263' ?-318" Landing nipples: n short string XN at 8,301' n long string X at 8,297' erforatiors 8,494' - 8,525 ES Type WD production pkr at 10,304, 2-318" XN landing nipple at 10,321' erforations 10.371' -10,383' nt on bridge plug 10,648' - 10,671' ridge plug at 10,671" ertorations 10,725' - 10,760' 29#, N-BO Casing at 11,360' men[ed with 506 bbls Class G 1 ( Jtv-.- ;'.~I,,<...;:)) DATA SUBMITTAL COMPLIANCE REPORT 12/11/2006 ßf!t,i,¿ /7 ~ ~ ~ MD 11387 /" TVD 9853 ....----- Completion Date 12/11/2004 Completion Status 2-GAS Current Status i-GAS API No. 50-133-20542-00-00 ~) Permit to Drill 2041430 Well Name/No. W FORELAND 2 Operator FOREST OIL CORP REQUIRED INFORMATION DATA INFORMATION M~ ~.- Samples No Directional Survey ~__ Types Electric or Other Logs Run: Dipole Sonic, Array Induction, Litho-Density, Compensated Neutron, G Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Electr ( Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments !~ 12894 Mud Log 2 Col 4450 11387 1/13/2005 OIL & GAS MUD LOG cAD C 12896 See Notes 12/17/2004 Formation Water Analysis, gas analysis, gas well test, PBU data, Completion vA Summary Drilling Reports ~ 12895 FefFfl.a.tiOM T~!lèr J......J. ~~ ..c.et' ...r- 3160 10378 1/18/2005 MDT (LG. DIAMCTER t. 45 PP.o~C) on - 60g 12895 Sonic Col 8000 1 0700 1/12/2005 DIPOLE SHEAR SONIC TOOL, DSI-GR A 12895 Sonic Col 8000 1 0700 1/12/2005 DIPOLE SHEAR SONIC TOOL DSI GR TVD LOG Gamma Ray 8000 1 0700 1/12/2005 ~- Las ~å94 Sonic Col 8000 10700 1/13/2005 OIL,& GAS MUD LOG, SHEER SONIC DSI-GR- TVD LOG AD·" C Ase Directional Survey 0 11426 ( Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 12/11/2006 Permit to Drill 2041430 Well Name/No. W FORELAND 2 Operator FOREST OIL CORP MD 11387 Completion Date 12/11/2004 Completion Status 2-GAS TVD 9853 ADDITIONAL INFORMATION Well Cored? @ Chips Received? 'Y I N Daily History Received? Formation Tops Analysis "1'+M""'"" Received? Comments: Compliance Reviewed By: ¿ API No. 50-133-20542-00-00 Current Status 2-GAS ~ (?/ N UIC N ( Date: r'l Ò \ ~-------- ~ d_tN-_______________2 ( Summary by Month: Individual Well Production Well Name: W FORELAND 2 C\;)OD API: 50-133-20542-00-00 Permit to Drill: 2041430 Operator: FOREST OIL CORP FieldlPool: W FORELAND, TYONEK UNO 4.0 GA Sales Cd: 92 Acct Grp: 2 Final Status: 2-GAS Current Status: 2-GAS 2004 Jan Feb Mar Apr May Jun Jut Aug Sep Oct Nov Dee Meth Shut-In Days 0 Oil 0 Wtr 0 Gas 0 2004 Totals: Oil 0 Water 0 Gas 0 Cum Oil 0 Cum Wtr 0 Cum Gas 0 2005 Jan Feb Mar Apr May Jun Jut Aug Sep Oct Nov Dee Meth Shut-In Shut-In Shut-In Flowing Flowing Flowing Flowing Flowing Flowing Flowing Flowing Flowing Days 0 0 0 22 31 30 30 31 30 31 30 31 Oil 0 0 0 0 0 0 0 0 0 0 0 0 Wtr 0 0 0 0 0 0 0 0 0 0 0 0 Gas 0 0 0 52,649 80,378 70,945 74,784 87,112 64,603 39,540 85,951 71,491 2005 Totals: Oil 0 Water 0 Gas 627,453 Cum Oil 0 Cum Wtr 0 Cum Gas 627,453 2006 Jan Feb Mar Apr May Jun Jut Aug Sep Oct Nov Dee Meth Flowing Days 31 Oil 0 Wtr 0 Gas 75,995 2006 Totals: Oil 0 Water 0 Gas 75,995 Cum Oil 0 Cum Wtr 0 Cum Gas 703,448 ( Well Name: W FORELAND 2 <'::;)h~\\C~(L" API: 50-133-20542-00-00 Permit to Drill: 2041430 Operator: FOREST OIL CORP FieldlPool: W FORELAND, TYONEK UNO 4.2 GA Sales Cd: 92 Acct Grp: 2 Final Status: 2-GAS Current Status: 2-GAS 2004 Jan Feb Mar Apr May Jun Jut Aug Sep Oct Nov Dee Meth Flowing Days 15 Oil 0 Wtr 0 Gas 50,884 Thursday, February 23,2006 Page 1 Summary by Month: Individual Well Production 2004 Totals: Oil 0 Water 0 Gas 50,884 Cum Oil 0 Cum Wtr 0 Cum Gas 50,884 2005 Jan Feb Mar Apr May Jun Jul Aug Sep Oet Nov Dee Meth Flowing Flowing Flowing Flowing Flowing Flowing Flowing Flowing Flowing Flowing Flowing Flowing Days 31 28 31 30 31 29 31 31 30 31 30 31 Oil 0 0 0 0 0 0 0 0 0 0 0 0 Wtr 0 0 0 0 0 0 0 0 0 0 0 0 Gas 142,122 130,694 138,179 84,009 75,253 70,140 68,320 77,428 73,704 82,184 151,261 135,152 2005 Totals: Oil 0 Water 0 Gas 1,228,446 Cum Oil 0 Cum Wtr 0 Cum Gas 1,279,330 2006 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dee Meth Flowing Days 31 Oil 0 Wtr 0 Gas 134,522 2006 Totals: Oil 0 Water 0 Gas 134,522 Cum Oil 0 Cum Wtr 0 Cum Gas 1,413,852 Thursday, February 23, 2006 Page 2 STATE OF ALASKA ALASKA"'tnt AND GAS CONSERVATION COMMIS~-.J WELL COMPLETION OR RECOMPLETION REPORT AND LOG Oil U Gas lJ Plugged 0 Abandoned 0 Suspended 0 WAG 0 1 b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory D No. of Completions /. ~ Other Service D Stratigraphic Test D 5. Date comp~UJJ]j ~I¡ ß¡ð¿ 12. Permit to Drill Number: Forest Oil Corporation Aband.: q-~1ÃI(Ø 204-143 6. Date SpuddecJ: 13. API Number: 9/17/04 50-133-20542-00 7. Date TD Reached: 14. Well Name and Number: 11/4/04 8. KB Elevation (ft): 15. Field/Pool(s): 251 AGL West Foreland 9. Plug Back Depth(MD+ TVD): . 10,646IMD/9,41S'TVD TYol1e.k Ûlnæ~ F i.1 J~ 10. Total Depth (MD + TVD): 16. Property Designation: Zone- 4 11,387IMD/9,853ITVD ADL-359112 Zone- 4 11. Depth Where SSSV Set: 17. Land Use Permit: Zone- 4 Surf SV on tree Salamatof Native Assoc. 19. Water Depth, if Offshore: 20. Thickness of Permafrost: N/A feet MSL N/A Dipole Sonic, Array Induction, Litho-Density, Compensated Neutron, GR, MDT, DSI, CBL 1a. Well Status: GINJD WINJD WDSPLD 2. Operator Name: 3. Address: 310 K Street, Suite 700, Anchoraqe, Alaska 99501 4a. Location of Well (Governmental Section): Surface: 886' FSL, 571' FEL, Sec. 21, T8N, R14W, SM Top of Productive Horizon: 29331 FNL, 898' FEL, Sec. 21, T8N, R14W, SM Total Depth: 760' FNL, 1146' FEL, Sec. 21, T8N, R14W, SM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 191452 y- 2475582 TPI: x- 190162 y- 2477051 Total Depth: x- 189967 y- 2479229 18. Directional Survey: Yes lJ No U 21. Logs Run: WF#2 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 20" Condo 251 1451 251 1451 Driven N/A 01 13-3/8" 68# L-80 251 3,0031 251 3,0011 17-1/2" 761sx lead, 508 sx tail 01 7-5/8" 29.7# P-110 251 8,4901 251 7,9731 9-7/8" Staqe 1: 238 bbls 01 7" 29# N-80 8,4901 11 ,3801 7,9731 9,8491 9-7/8" Staqe 2:270 bbls 01 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.): Flowinq Water-Bbl: SS-O; LS-O Water-Bbl: SS-O; LS-O December 12, 2004 Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Dec 12,2004 SS-13; LS-17 Test Period", 0 S-3986; L-2671 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Press. S-681; L-807 24-Hour Rate ... 0 S-9992; L-5494 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". 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 84941 - 85251MD (7,9751 - 7,994ITVD), 6 spf 26. Date First Production: None RBDMS 8Ft FE8 0 3 2005 , ;~ Of: ~~.'t ~:I ~ IØ~~o/ _}1i:;J,': 24. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/8" (long string) 10,304' 10,304' 2-3/8" (short string) 8,302' 8,302' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A Gas-Oil Ratio: Choke Size: S-18/64; L-18/64 Oil Gravity - API (corr): N/A N/A RECEIVE JAN 1 3 2005 Alaska Oil & Gas Cons. Commission Anchorage r C \/ "'" I=nrm 1 n...dn7 RAvi~Ad 12/2003 CONTINUED ON REVERSE NAME GEOLOGIC MARKERS MD-" TVD 29. -~ORMA TION TESTS Include and briefly surl\~ze test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 28. Tyonek- 2 gas sands tested: see page 1 Sterling 100 100 Beluga 2178 2178 Tyonek 2914 2914 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Printed Name: Ted Kramer Signature: -Ø~ ~ Title: Alaska Production ManaQer 907-868-2137 Date: 1,11.,./0 )' Phone: INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for I njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 .~ - .~\~. ~ .,,, S''dO>-? , . .. :~:;:,"c"<~':~::::::2_\) " \L. ~> ~'.. /f /'í ~'Í.'\ -. / . _'_..=~,.,._) . "--I ~. ----//~. "-.. .~" 'ij. .\\\. ~ '. ~.' .. ......... ... .~... ,:"-;~~~-'l~ \~~.'/ / /:¿..~ -~ .-.,.. /\. ~ ~~- l Ct!._.R.~-v~, . - -~~,5;;~ .r I; ,--.... t'-, _. ~\\~~·{s~ ~\\ '\~ 0~~ \ .~ IJ-..) I 0 {'-~I \ <>,,~ <: ~\a~~C'\~) ~ b-\-~~ (l}.,~' s ~a ~ JJ9..~ ~ · ~ .\ \~.. \..' \u ,~ ~- r~O ··"'----··~-·T. . ~-_.....-..".""'..--....- 7 \ r~ \ . ~ \ ""~ ". }... I \.... I i Ii. \ .. i ¡ \ Regulation 20 AAC 25.252 (i) 20 AAC 25.252 U) 20 AAC 25.252 (k) 12/1/2004 Underground Disposal of Oil Field Wastes Regulatory Requirements Requirement Commission will publish notice of disposal or storage application and provide opportunity for hearing per 20 AAC 25.540 If disposal operations are not begun within 24 months after approval, the approval will expire Annular disposal covered under 20 AAC 25.080 is not included. Goal of Requirement Notify all affected parties and provide opportunity to be heard Ensure local conditions have not substantially changed Regulated separately from "conventional" disposal. MPU 8-50 Public notice will be published, 30-day comment period will apply, and there is potential for public hearing: 6 to 8 week process. Recognize that permit will expire after 24 months. Page 5 of 5 '''-"' Forest Oil Corporation W est Forelands #2 Operations Summary 9/16/04 Finish rigging up. Load BRA and pipe on pipe rack. Function test diverter. Pressure test mud lines. PIU 4-1/2" DP. 9/17/04 PIU BRA. RIH, tag bottom at 35'. Swap around BRA. Spud well at 0430 hrs, 9/17/04. Drill 17-1/2" hole 35' to 432', picking up additional BRA components and taking gyro surveys. 9/18/04 Drill 17-1/2" hole 432' to 1 ,348', taking gyro surveys. 9/19/04 Drill 17-1/2" hole 1,348' to 2,025'. Make short trip - gumbo in hole causing swabbing difficulties. Clean up hole and mud and return to bottom. C&C mud and hole on bottom. 9/20/04 Drill 17-1/2" hole 2,025' to 3,003', taking directional surveys. 9/21/04 C&C hole, POR. Run back in hole, circ and thin mud. POH, L/d collars. RID to run casing. Run 13-3/8", 68#, L-80, BTC casing. 9/22/04 Finish running 13-3/8" casing to 3,003'. Cement casing with 761 sx Class G lead at 11.0 ppg and 508 sx Class G tail at 15.8 ppg. Good returns throughout job. Bumped plug with 1,100 psi. WOC. 9/23/04 N/D diverter system. Set wellhead and land 13-3/8" casing. NIU BOPE and run gyro in well. 9/24/04 Finish NIU BOPE. Test all BOPE to 500 psi low, 5,000 psi high. Install bell nipple and flowline. MIU 12-1/4" bit and RIH. 9/25/04 Finish Rill, tag cement at 2,880'. CBU and test casing to 2,300 psi - OK. Drill plugs, float collar, cement, float shoe and 20' of new hole. Perform FIT with 9.2 ppg mud at Page 1 of 9 "'--'"' '"-,,,' 510 psi, yielding 12.4 ppg EMW. Clean pits and lines in preparation for taking on oil base mud. Displace hole with OBM and fill pits with same. CONFIDENTIAL 9/26/04 POR to P/u directional drilling BRA. Work BRA, RllI to bottom. C&C oil base mud. Ran out of base oil, wait for additional. 9/27/04 Wait on base oil. Receive additional base oil, add to mud and adjust mud weight to 9.4 ppg. Drill 3,023' to 3,475'. 9/28/04 Drill and survey 3,475' to 4,150' with short shutdowns for rig repairs and maintenance. 9/29/04 Drill and survey 4,150' to 5,000' with short shutdowns for rig repairs and maintenance. 9/30/04 C&C mud, POR. Modify BRA and make repairs to top drive. RllI to bottom. Drill and survey 5,000' to 5,133'. 10/1/04 Drill and survey 5,133' to 5,255'. Circulate out thick mud and gas. Drill to KOP at 5,317'. Directionally drill 5,317' to 5,885'. 10/2/04 Directionally drill 5,885' to 5,995'. Build mud weight from 9.5 ppg to 9.7 ppg. Short trip to casing shoe. Repair top drive. RllI to bottom, C&C mud. 10/3/04 Directionally drill 5,995' to 6,184'. Stopped to repair rig engine. POR to shoe at 3,003' while waiting on parts. 10/4/04 Service rig. Finish POR. Test BOPE. RIH to shoe, slip and cut drilling line. C&C mud while waiting on parts to repair #1 Generator motor. 10/5/04 Wait on parts. Replace injectors on #1 generator motor. Rlli 10 stands, #2 RPU motor went down. Pull back to shoe and work on #2 RPU. RllI to 5,100', start circulating. #2 RPU went down again. 10/6/04 POR to shoe. Wait on parts. 10/7/04 Monitor well on trip tank while waiting on parts. Parts arrived piecemeal during day. Work on #2 RPU while C&C mud. Page 2 of 9 ."-,, CONFIDENTIAL 1 0/8/04 Work on #2 RPU while C&C mud. Rill to bottom and slow to take slow pump rates/pressures. #1 pump would not power back up. POR while trouble shooting #1 pump. 10/9/04 Trouble shoot #1 pump while circulating at shoe. Test surface BOP equipment while waiting for new computer for #1 pump engine. Install new computer and test pump - OK. Rill, wash and ream to bottom at 6,184'. 10/10/04 Directionally drill 6,184' to 6,696'. Short trip to 6,050'. 10/11/04 Directionally drill 6,696' to 6,888' at reduced RPM's while trouble shooting overheating #1 mud pump. Directionally drill 6,888' to 7,117'. 10/12/04 Directionally drill 7,117' to 7,384'. 10/13/04 Directionally drill 7,384' to 7,648'. 10/14/04 Short trip bit to 7,000'. CBU and Rill. Directionally drill 7,648' to 7,958'. POR to 7,805', service top drive, Rill. 10/15/04 Directionally drill 7,958' to 8,240'. Torque increasing, BRA hanging up, directional control becoming difficult. Circ prior to POR. POR. 10/16/04 POR, stand back BRA. Test BOPE. PIU new BRA and Rill. 10/17/04 Directionally drill 8,277' to 8,677'. Getting rubber back over shakers and pressure spiking. 10/18/04 POR to change motor. MIU new motor and Rill to bottom. Directionally drill 8,677' to 8,850' . 10/19/04 Directionally drill 8,850' to 9,243'. Mud weight rose to 10.3 ppg. PIU and C&C mud. 10/20/04 Page 3 of 9 CONFIDENTIAL ~. C&C mud, cut mud weight from 10.3 ppg to 10.0 ppg. Directionally drill 9,243' to 9,440' . 10/21/04 Directionally drill 9,432' to 9,438'. C&C mud and pump out of hole, reaming out key seat 8,882' to 8,820'. POR, change out bit and stabilizer. Rill 10/22/04 Finish Rill. Directionally drill 9,438' to 9,741 ' . 10/23/04 Directionally drill 9,741' to 9,930' with stops to work on #1 mud pump. Lost #1 RPU motor, could not repair, order parts from town. POR on one motor to test BOP's and repair #1 motor. 10/24/04 Finish POR. Service BRA, repair #1 RPU motor, test BOP's. M/U new bit and Rill. 10/25/04 Finish Rill. Directionally drill 9,930' to 10,171' with frequent stops to repair mud pump #1. 10/26104 Directionally drill 10,171' to 10,381' with frequent stops for mud pump repairs and monitoring of drilling breaks. 10/27/04 Directionally drill 1 0,381' to 10,615', with pauses to circulate up drilling breaks. 10/28/04 Directionally drill 10,615' to 10,717' TD. C&C mud in preparation for logging. 10/29/04 Finish C&C mud for logging. POR, LID BRA. R/U Schlumberger to run quad-combo. Rill wi logging tools. Rit bridge at 9,650, could not go further. Log up from 9,650' 10/30104 Log up to 3,003' (surface casing shoe). POR and shorten logging tool string. Rill, stopped at same depth - 9,650'. POR, RID wireline. Test BOPE. M/U 9-7/8" hole opener and Rill reaming tight spots. 1 0/31/04 Rill to 8,402' wi hole opener. Rec'd orders to change to drilling assembly and drill deeper. POR, LID hole opener. M/U drilling assembly and Rill. Directionally drill 10,717' to 10,743'. 11/1/04 Directionally drill 10,743' to 11,105'. Page 4 of 9 ~ ',,-,,' CONFIDENTIAL 11/2/04 Directionally drill 11 , 1 05' to 11,284'. Bit stopped drilling. POR. 11/3/04 POR. MID new bit and service BRA. Rlli. 11/4/04 Finish Rlli wi new bit. Directionally drill 11,284' to 11,387', apparent TD. Short trip to 9,000' . 11/5/04 Finish short trip, C&C hole for logs. POR to log. 11/6/04 Finish POR, LID BRA. RID for open hole logging. Rlli wi Schlumberger Platform Express. Sat down at 10,720'. Could not get past. POR logging 10,720' - 8,952'. POR, LID logging tools. P/U MBT and Rlli, taking pressure samples to 10,350'. POR. 11/7/04 Finish POR wi MBT. RID Schlumberger. Test BOPE. P/U 9-7/8" hole opener, Rlli. Wash and ream through bridge 10,715' - 10,850'. Continue in hole to 11,300'. 11/8/04 C&C hole. POR, fighting bridges. POR and Rlli, reaming tight spots. 11/9/04 POR to 3,000'. Shut down ng operations for 10 hours due to weather (heavy snowstorm). Continue POR. 11/10104 Rlli, washing and reaming to bottom. C&C hole. POR, LID drill pipe. 11/11/04 Finish POR to run casing. Set 13-3/8" RTTS and change rams to 7-518" and 7". Test bonnet seals. Retrieve RTTS and commence running casing. 11/12/04 Finish running 7" x 7-518" casing to 11,380'. RID cementers and C&C hole for cementing. 11/13/04 Finish C&C hole for cementing. Pump cement stage #1: 140 bbls Litecrete lead followed by 98 bbls Class G tail wi full returns throughout job. Bump plug and check floats - OK. Open DV tool and C&C upper part of hole. Receive contaminated mud and spacer at surface. Pump cement stage #2: 270 bbls Litecrete wi full returns throughout job. No cement or spacer to surface. WOC, start NID BOP's. Page 5 of 9 ",-,,' n j ß 11/14/04 Finish NID BOP's, set casing slips, cut off casing. Install tubing hanger and DSA. NIU and test BOPE. 11/15/04 Finish testing BOPE. LID 4-1/2" drill pipe out of derrick. MIU 6-1/8" BHA, PIU 2-3/8" tubing. 11/16/04 Rill wi BHA while pIU 2-318" tubing. Tag DV tool and cement and drill same. Rlli and tag baffle plate. CBU and test casing to 3,600 psi for 30 min - OK. Build KCI water system and spacers. 11/17/04 Finish mixing KCI water and spacers. Displace OBM in hole with KC1 completion fluid. Clean pits and lines. POH wi bit and scraper 11/18/04 Finish POR, LID BHA. R/U wire line and run CBL. Run DSI/GR. Run second CBL wit 500 psi pressure on casing. POH. 11/19/04 Finish POR wi CBL tool. RIH with 6" gauge ring and junk basket on WL. Tag at 11,100' WLM. POR. MIU packer wi 35' of perf guns (4-5/8", 5 SPF) and Rlli on WL. Attempt to set packer at 10,671'. Would not set. POR. 11/20104 Finish POR wi pIa and guns. Repair firing head and RIH wi same pkr and guns. Set pIa at 10,671' with guns spaced out to shoot 10,725' - 10,760'. POR and RID Schlumberger. Commence MID and running dual 2-3/8" completion, including perf guns in the short string spaced out to shoot 8,494' - 8,529'. 11/21/04 Run 1.875" gauge through tubing to check for mashed joints resulting from malfunctioning tongs. Continue running dual completion. 11/22/04 Finish running dual completion. Space out and install hangers. Circ out dirty fluid through long string. Land hangers and run in lock down screws. Circ corrosion inhibitor via short string. 11/23/04 Finish circulating in corrosion inhibitor. Set BPV. N/D BOP's, NIU and test dual tree. LID drill pipe out of derrick and prep to swab. 11/24/04 Swab long string down to 3,400'. RID swabbing unit. Prep loc for testing equipment and start unloading test equipment from barge. Page 6 of 9 ~ CONFIDENTIAL 11/25/04 Transport well testing equip from barge landing to location and RID. Pressure test equipment. 11/26/04 Pressure up to 500 psi on csg and drop bar to fire guns in long string. Perforate interval 10,725' - 10,760'. Open well to testers. Had small blow on tbg. RID swabbing unit. Rlli and tag fluid level at 725'. Swabbed well down to 1,904'. Fluid level attempting to stabilize between 1,300' and 1,500'. Open well to testers - small blow. 11/27/04 Finish monitoring well on 10/64 choke. No fluid to surface. Swab well a total of 6 bbls over tubing capacity. Start getting clear formation water with no gas. RID swabbing unit. Set BPV and RID test lines. N/D tree, NIU BOP's. 11/28/04 Test all BOPE to 4,000 psi. RID landing joints and pull 2-way checks from tbg strings. Back out lock down screws and PIU hanger 10'. Reverse fin water out of tubing. Pump slugs down both tbg strings and POH with same. 11/29/04 POR wi dual completion. RID to test bottom BOP rams. 11/30104 Test bottom BOP rams, completing BOP test. RID WL unit and RIH wi bridge plug and set at 10,671'. POR wi WL and RID. Close blind rams and test bridge plug wi 1,500 psi for 30 minutes - OK. Change top rams to 2-3/8" single and test to 4,000 psi. RID slickline unit and cement bailer. Commence making bailing runs to place cement on top of bridge plug. 12/1/04 Finish dump bailing cement. Placed total of25' of cement from 10,646' to 10,671'. RID WL, make gauge ring/junk basket run. Tag at 10,646'. POR and RID WL. Change upper rams to 2-3/8" dual and test to 250/4,000 psi. PIU 12' of 4-5/8", 5 SPF perf guns and packer and Rill on 2-3/8" tbg. Transport well testing equip from barge landing to location and RID. Pressure test equipment. 12/2/04 Finish Rill with lower perf assembly to 10,370'. RID WL and run correlation strip to place guns on depth. POG, RID WL. Position guns to shoot 10,371' - 10,383'. Drop ball and pump down. Pressure up to set pkr at 10,304'. Shear out ball, release from pkr and POR wi 2-3/8" DP. RID to run dual string and upper guns. 1213/04 RIH wi dual 2-318" string and upper gun assembly. Page 7 of 9 .~ fl n 12/4/04 Finish Rill wi dual string. Space out, orient and land. R!U slickline and run 1.7" gauge ring to 1 0,300. POR. Rill wi tbg plug and set in nipple at 8,297'. R!U on short string, run gauge ring to 8,300'. Rill, set prong in long string plug. POR and RID slickline. Pressure up on long string to set pIa at 8,203'. Pressure up on longstring backside for 15 minutes - OK. R!U slickline, Rill, pull plug, POR, RID slickline. Set BPV in hanger. 12/5/04 LID extra tbg out of derrick, RID tbg running equipment. N/D BOPE. Install and test tree. Pull BPV from hanger. Displace top 21' water in annulus with diesel. Commence swabbing on long string. 12/6/04 Continue swabbing down long string to 5,426'. Swabbing unit starting to act up. Swab down short string to 20' and replace volume with diesel for freeze protection. Install BPV's in both strings, finish cleaning pits and release rig. RID rig. 12/7/04 Demob rig. 12/8/04 Demob rig. 12/9/04 Demob drilling rig. 12/10104 Finish demobing drilling rig. Pull BPV's from long and short strings. R!U swabbing unit. Swab long string down to 6,300'. Set up test equipment. 12/11/04 Swab long string down to 7,750'. RID swabbing unit, R!U nitrogen unit. Drop bar, fire guns on long string. Guns fired, open well to tame S/I to perforate short string. Pressure up with nitrogen, fire guns on short string. 12/12/04 Flow test long string. Conduct step rate test. Shut in well at wing valve and monitor pressure. 12/13/04 Take final pressure on long string. R!U test lines on short string. Open well and flow test short string. Conduct step rate test. Shut in well and monitor pressure. 12/14/04 Finish taking shut in pressures. Close in well. RDMO testing equipment. 12/15/04 Page 8 of 9 F! '--' Wait on weather. Barge cannot land due to wind and seas. All testing equipment at barge landing. Clean up well location. 12/16/04 Finish loading equipment on barge. Finish cleaning location. Final report. Page 9 of 9 ~\ < 1, Name §J~rli'!9______~_ _'ª_~! uga_~______ Il~~ek___mm_________ "-- ~/ 1/12/2005 WestForeland #2, API# 50-133-20542-00 Geologic Markers Measured Depth TVD 100' 100' 2,178' 2,178' 2,914' 2,914' <-_.----._-------------_._------_._-~ ~~----_._-------_.~-----~-------_.--~-_._~-_._-~-------- ----_._~----~------------------~-~-- --_.~_._----------.---~~--~-~---_.~~ --_.----------_...----~._-~- _._-----~~---->~-~------ Name Iy<:>ne_~__(~£:#2 --ª_~ºmd) I~Q!l_E3!_(~f#1-~00tvdss ) --_._-~~_._-~-~-~-~-~.- --~--~-~-~-~------ -- ----~--~--.-~.~----~-~------~ --- - -------_._-_._~_._._----~---~.--_. --- '~ WestForeland #2, API# 50-133-20542-00 Oil and Gas Shows Measured Depth 8,494' - 8,525' 10,371' - 10,383' TVD 7,975' - 7,994' 9,241' - 9,249' 12-Jan-05 Gas Show Gas Show '--, Forest Oil West F oreal and #2 Summary of Testing: FLOW TEST #1 Interval10,725-10,760'MD Perforated 11/26/2004 10,725-10,760' Interval Produced Only Formation Water-Interval was P&A. (Onlv Samples #2 and #4 are representative of the formation fluid) The well was completed with 2% KCI and swabbed. When the last swab was pulled the well had barely recovered the tubing volume of water. When the interval was abandoned, the tubing was reverse circulated and four samples of water in the tubing (which had come from the formation) were taken. Unfortunately, the order of these samples was not recorded. A lab analysis was made on the four tubing samples and the swab samples in an effort to determine which sample was the best representation of the formation fluid. The Swab sample is identified and the concentrations of Potassium, Sodium and Chlorides clearly indicate that Samples #1 and #3 have are basically mixtures of the 2% KCI and formation water. Samples #2 and #4 are representative of formation fluid. Following is a summary of the Analysis of the Samples arranged in order of descending Potassium concentration. (Note Sample Numbers 1-4 were assigned after they were taken and do not represent the order in which they were taken!) Analysis Units Swab #3 #1 #2 #4 Fluid Type Completion Mix Mix FormationFormation Chloride mg/l 30,700 23,900 8,280 8,200 8,320 T\)') '/ ') Sodium mg/l 541 463 4,160 4,720 4,770 Potassium ug/l 28,700,000 21,200,000 1,430,000 818,000 773,000 .....- 20.3 Barium mg/l 7.71 14.3 Calcium mg/l 402 276 357 Iron mg/l 3.04 1.70 2.34 Strontium mg/l 22.3 23.5 30.8 Magnesium mg/l 19.4 32.1 40.1 Sulfate mg/l 29.2 27.7 27.5 Resistivity @ 68F ohm-m 1.25 0.370 0.370 pH pH units 9.19 7.65 7.62 Alkalinity mg/l 500 2200 2300 C03 Alkalinity mg/l IOU IOU IOU HC03 Alkalinity mg/l 500 2200 2300 OH Alkalinity mg/l IOU IOU IOU FLOW TEST #2 CONFIDENTIAL West Foreland #2-Long String (WF#1-9200TVDSS) Interval 1 0)371-1 0)383 )MD Perforated 12/11/2004 10)371-10,383'MD Interval Produced Dry Gas. Step Rate Test Results: Step Choke Duration FTP WHT Rate BHFP (10,371 MD (9,241 TVDSS) (Hours) (PSIG) (F) (MMSCF/D) (PSIA) 1 12/64 3 1,756 72 3.842 2,314 2 14/64 3 1,601 74 4.422 2,185 3 16/64 3 1,427 74 5.071 2,061 4 18/64 3 1.313 55 5.493 1,993 Shut In Reservoir Pressure at top perforation 3054.2 PSIA Absolute Open Flow Potential 10.5 MMSCF/Day Gas Sample Analysis Results: Sample 1 Sample 1 Sample 2 Sample 2 Run 1 Run 2 Run 1 Run 2 Molar Mass 16.945 16.944 16.949 16.931 Relative Density 0.5860 0.5859 0.5861 0.5855 Compressibili ty 0.9981 0.9981 0.9981 0.9981 Heating (BTU/lb.) 21408 21402 21386 21434 Heating (BTU/ft^3) 960.0 959.6 959.2 960.4 #m/1000CF 44.8423 44.8384 44.8527 44.8057 W obb Index 1233.54 1233.14 1232.40 1234.57 Methane 93.524 93.518 93.438 93.597 Ethane 0.400 0.389 0.403 0.399 Propane 0.112 0.108 0.112 0.110 i-Butane 0.020 0.020 0.022 0.021 C6+ 0.015 0.015 0.009 0.009 Moisture 0.000 0.000 0.000 0.000 . Nitrogen 5.398 5.426 5.451 5.341 CO2 0.531 0.524 0.536 0.523 " ' ~ ~ '~ CONFIDENTIAL FLOW TEST #3 West Foreland #2-Short String (WF#2-8500MD) Interval 8,494-8,529'MD Perforated 12/13/2004 8,494-8,529'MD Interval Produced Dry Gas. Step Rate Test Results: Step Choke Duration FTP WHT (Hours) (PSIG) (F) 1 12/64 3 2,731.8 71 2 14/64 3 2,506.3 74 3 16/64 3 2,390.0 78 4 18/64 3 2,265.7 74 Rate BHFP (8,494 MD (7,975 TVDSS) (MMSCF/D) (PSIA) 4.273 3,365.8 7.726 3,327.1 8.968 3,311.0 9.992 3,282.5 Shut In Reservoir Pressure at top perforation 3555.5 PSIA Absolute Open Flow Potential 191.3 MMSCF/Day Gas Sample Analysis Results: Sample 3 Sample 3 Sample 4 Sample 4 Run 1 Run 2 Run 1 Run 2 Molar Mass 16.891 16.853 16.862 16.868 Relative Density 0.5841 0.5828 0.5831 0.5833 Compressibility 0.9981 0.9981 0.9981 0.9981 Heating (BTU/lb.) 21530 21659 21664 21662 Heating (BTU/ft^3) 962.4 965.9 966.7 967.0 #m/1000CF 44.7003 44.5983 44.6236 44.6394 Wobb Index 1238.63 1244.58 1245.24 1245.33 Methan 93.907 94.242 94.241 94.221 Ethane 0.346 0.349 0.355 0.359 Propane 0.114 0.115 0.124 0.128 i-Butane 0.016 0.018 0.021 0.023 C6+ 0.007 0.006 0.013 0.017 Moisture 0.000 0.000 0.000 0.000 Nitrogen 5.083 4.736 4.696 4.705 CO2 0.527 0.534 0.549 0.546 BW Brice 1/6/2005 · . '-"" FOREST OIL CORPORATION ALASKA BUISNESS UNIT T.B. Berge, Exploration Manager 310 K Street -Suite 700, Anchorage, Alaska Tel: (907) 868-2145 Fax: (907) 258-8601 January 12, 2005 RECEIVED JAN 1 3 2005 A'aska Oil & Gas Coos. Commission Anchorage Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 RE: Well Completion Report: Forest West Foreland #2 ADL 359112 LaiC I 04-012 Dear Commissioner Norman, In compliance with stipulations in the above referenced Lease Plan of Operations Approval, Forest Oil Corporation (Forest) is pleased to submit this completion report and well data submittal for the West Foreland Well #2 program. 1) Well completion report (AOGCC form 10-407), with attachments 2) Copy of Daily Drilling reports or a summary report of daily drilling (9 pages) 3) List of Formations and other geologic markers encountered and their depth 4) List of depth and formation names for oil and gas shows. 5) Summary of production tests and formation tests ( 4 pages) 6) Copy ofDSTs and Production test data and charts 7) Copy of Geochemical and formation fluid analyses and reports 8) Copy of all open-flow potential test results and report attachments. 9) Paper and digital copies of all directional surveys 10) Copies of final composite mud or lithology log and report. 11) Digital version of all well logs in LAS format and digital version of directional surveys in ascii. 12) Copies of all logs run 13) 2 boxes of drill cuttings from 6,180' to 11,387' MD · Page 2 ,-,I January 12, 2005 If you have any questions or require additional information, please contact me at (907) 868-2145. Sincerely, <Z~TO~CO~N Ti~ Alaska Exploration Manager Forest Oil Corporation Enclosures (X:\ANC _ Well_Info _InProgress\W estForeland _ #2\Final Agency Reports\DNR\DNR _Final Env Rprt_ as _ submitted. doc) . Page 3 '~ January 12, 2005 Attachment, Item #16 Stratigraphic Nomenclature of Tyonek Fm. Productive Intervals Originally West Foreland #1 tested in 1962 in two intervals. The completion interval was 9,336-9,352 MD which is called the "9200' Sand" and the second interval which tested gas 9,504-9,524 MD is called the "9400' Sand". The naming was based upon the TVDSS of the sand as it was encountered in West Foreland #1. Upon the drilling and testing of West Foreland #2 in December 2004 two gas bearing sands were encountered with both testing gas: . 10,371-10,383 MD PerfMD PerffVD PerffVDSS 10,371 9,241.378 9,133.378 10,383 9,249.038 9,141.038 Based upon the initial reservoir pressure this is the same reservoir as the "9200' Sand in West Foreland # 1. . 8,494-8,529 MD PerfMD PerffVD PerfTVDSS 8,494 7,974.681 7,866.681 8,529 7,996.052 7,888.052 This reservoir was not present in West Foreland # 1. NEW NAMING CONVENTION The Tyonek Gas Reservoirs are meandering stream channel deposits and thus are difficult to correlate and may be absent from well to well. Since sands in the same stratigraphic section in neighboring wells, mayor may not be the same reservoir, it is proposed to name the Reservoir based upon the depth it was encountered in the discovery well. This is in accord with standard formation naming practice where a type section is designated for a formation, then other occurrences of the same formation will share that name. So what we propose is that productive sands be named based on the first well in which they were encountered, plus the depth measurement and type (TVD or MD) at which the interval was discovered in that well. This will permit future technical people who are evaluating the data to easily identify the reservoir on the logs. Because West Foreland #2 is a deviated well it will be easier, for identification purposes to carry the MD of the sand 3 · Page 4 ',,-. ~ January 12, 2005 and this convention should be used on future wells. However, since TVDSS was used originally on West Foreland #1, the names associated with these reservoirs will remain the same. With the new naming convention the gas sands will be identified as follows: Well West Foreland #1 West Foreland # 1 West Foreland #2 West Foreland #2 Perforations MD 9,336-9,352 9,504-9,524 10,371-10,383 8,494-8,529 New Reservoir Identification (WF#1-9200'TVDSS) (WF#1-9400'TVDSS) (WF#1-9200'TVDSS) (Wf#2-8500'MD) Original Reservoir Name 9200' Sand 9400' Sand ~. The goal of the New Naming Convention is to be able to link easily keep track of the gas production from specific reservoirs. U' If; 4 ~ West Foreland #2 Formation Water Fluid Samples 10725-60' Interval Tested Water-Water Samples (Onlv Samples #2 and #4 are representative of the formation fluid) The well was completed with 2% KCI and swabbed. When the last swab was pulled the well had barely recovered the tubing volume of water. When the interval was abandoned, the tubing was reverse circulated and four samples of water in the tubing (which had come from the formation) were taken. Unfortunately, the order of these samples was not recorded. A lab analysis was made on the four tubing samples and the swab samples in an effort to determine which sample was the best representation of the formation fluid. The Swab sample is identified and the concentrations of Potassium, Sodium and Chlorides clearly indicate that Samples #1 and #3 have are basically mixtures of the 2% KCI and formation water. Samples #2 and #4 are representative of formation fluid. Following is a summary of the Analysis of the Samples arranged in order of descending Potassium concentration. (Note Sample Numbers 1-4 were assigned after they were taken and do not represent the order in which they were taken!) Analysis Fluid Type Units Chloride mg/l Sodium mg/l Potassium ug/l Barium mg/l Calcium mg/l Iron mg/l Strontium mg/l Magnesium mg/l Sulfate mg/l Resistivity @ 68F ohm- m pH pR units Alkalinity mg/l C03 Alkalinity mg/l RC03 Alkalinity mg/l OR Alkalinity mg/l Bradley Brice 12/21/2004 Swab CompI. 30,700 541 28,700,000 #3 Mix # 1 #2 #4 Mix FormationFormation 23,900 8,280 463 4,160 21,200,000 1,430,000 7.71 402 3.04 22.3 19.4 29.2 1.25 9.19 500 IOU 500 IOU 8,200 4,720 818,000 14.3 276 1.70 23.5 32.1 27.7 0.370 7.65 2200 IOU 2200 IOU 8,320 4,770 773,000 20.3 357 2.34 30.8 40.1 27.5 0.370 7.62 2300 IOU 2300 IOU Pøwer¥@G~ SE VICES Test Dates: 24-Nov-04 through 17-Dec-04 West Forelands #2 Surface Well Testing Report 'II. .,.~ ... ..r 1I.,oa.. '- ,.. -." .-. ..... ¿.¿_.. ~'A..~'- . I¡. Forest Oil ~ PøwerW@[,.: SERVICES Suñace Well Test DISCLAIMER Power Well Services ("PWS") will use its best efforts to furnish customers with accurate information and interpretations as a part of, and incident to, the services provided. However, PWS cannot and does not warrant the accuracy or correctness of such information and interpretations. Under no circumstances should any such information or interpretation be relied upon as the sole basis for any decision regarding drilling, completion, production, financing or any procedure involving any risk to the safety of any drilling venture, drilling rig or its crew or any other third party. These calculations are based on certain data, assumptions and applied mathematical methods. Inaccurate well data, changing well conditions, tolerance variations of mechanical components, mechanical malfunctions and other factors may affect these calculations. In no event will PWS be liable for failure to obtain any particular results or for any damages, including but not limited to, indirect, special or consequential damages, whether due to negligence or otherwise arising out of or in connection with such use of data, calculations, recommendations or opinions provided by PWS. Measurement by Orifice Plate :- where :- C Qg C Hw Pf Fpv Fb Fg Ftf = Ftb Fpb Fr Y2 Fm Unit Conversion Factor = ,-. ~ CONFIDENTIAL Power SERVICES Method of Gas Rate Measurement Qg = C * Sqr ( Hw * Pf ) Fpb * Fb * Fg * Ftf * Ftb * Fr * Y2 * Fm * Unit Conversion Factor Corrected Gas Flow Rate. Orifice flow constant. Differential pressure across orifice plate in inches water gauge at 60 deg.f = Absolute static pressure. Supercompressibility factor ( corrected for N2, H2S and C02 effects ). Basic orifice factor. Specific gravity factor. Flowing temperature factor. = Temperature base factor. Pressure base factor. Reynolds number factor = 1. Expansion factor for downstream pressure tap. Manometer factor = 1. Factor changing flow rate units. = = = = = = We can unite Fu = Ftb * Fpb * Unit Conversion Factor. ( Fu factors are given in the table for different standard conditions and flow rate units ). C1 = Fu * Fg ( theoretically constant during the test ). C2 = Fpv * Fb * Ftf * Y2 Then C = C1 * C2 Rate of Flow units Standard conditions 14.73 psi /60 deg F. 760 mm Hg / 0 deg C. 760 mm Hg /15 deg C. 750 mm hg /15 deg C. Table of Fu Factors Cu Ft / hours 1.00 0.95 1.00 1.01 Cu Ft / day 24.00 22.76 24.01 24.33 M3 / hour 0.03 0.03 0.03 0.03 M3 / day 0.68 0.64 0.68 0.69 POWER WELL SERVICES SURFACE WELL TESTING REPORT ÐATEITIME m/d/yr . hr:mn 11/26/20046:56 11/26/20047:30 11/26/20048:15 11/26/20048:30 11/26/20049:00 11/26/20049:30 11/26/2004 10: 00 11/26/200410:30 11/26/2004 11 : 00 11/26/200411:22 11/26/200411 :26 11/26/200411 :42 11/26/2004 11 :48 11/26/200411 :54 11/26/200411 :58 11/26/200412:20 11/26/200412:25 11/26/2004 13:20 11/26/2004 13:25 Drop bar, fire guns. Very slight blow at choke manifold. Open well to tank. Flowing to tank via 10/64 choke Flowing to tank via 10/64 choke Flowing to tank via 10/64 choke Flowing to tank via 10/64 choke Rig up to swab Weak blow at choke manifold Run in hole for 1st swab run. Open choke all the way Tag fluid at 725' pull 200' swab Run in hole for 2nd swab run Tag fluid at 686' pull 100' swab Run in hole for 3rd swab Tag fluid at 645' pull 200' swab Run in hole for 4th swab Tag fluid at 588' pull 200' swab Run in hole for 5th swab Tag fluid at 480' pull 200' swab Run in hole for 6th swab. Unable to 11/26/200414:10 establish fluid level. 11/26/200414:45 11/26/200414:48 Run in hole for 7th swab Tag fluid at 380' pull 200' swab Pøwer~ SERVICES WELLHEAD CONDITIONS WHP WHT CSG· CHOtæ SSW STATIC (psiG) (deg.F) (psiG) (64ths) (%) (psiG) 500 500 500 10 500 10 42 455 10 42 456 10 42 458 10 42 458 10 42 458 10 42 458 128 42 458 128 42 458 128 42 458 128 42 458 128 42 458 128 42 458 128 42 458 128 42 458 128 42 458 128 42 458 128 42 458 128 42 458 128 COMPANY: FIELD: LEASE: WELL#: CO. REP.: Forest Oil West Foreland WF#2 (WF#1-9200) West Foreland #2 Fred Brent SEPARATOR CONomONS TotAl GAS TOTAL WATER . DIF¡: TEMP ORIFICE GAS GRAV GAS RATE GAS CUMM. WT. CHLORIDeS H20 RATE CUMM, (insH20) (deg f) . (in$.) air=1.0 (mscfld) (mscf) . (ppg) (ppm) (bw/d) (bbls) Page 1 ( -,- rT ~ :r.:: r POWER WELL SERVICES SURFACE WELL TESTING REPORT DATEmME mldlyr hr:mn 11/261200414:53 Run in hole for 8th swab 111261200414:57 Tag fluid at 371' pull 300' swab 11/261200415:05 Run in hole for 9th swab 11/2612004 15:09 Tag fluid at 376' pull 300' swab. Still no returns to tank. 11/2612004 16:52 Close wing valve on tree 11/26/200416:53 Run in hole, swab to trip tanks, recover 1 bbl. Open wing valve, flow to tank, weak blow Close wing valve on tree, swab to trip tank, recover 3 bbl. Open wing valve, flow to tank, weak blow Close wing valve on tree, swab to trip tank, recover .25 bbl. Close wing valve on tree, swab to trip tank, recover 2.3 bbl from 775' 11126/2004 16:58 11/26/200417:01 11/26/200417:08 11/26/200417:16 11/26/200417:24 Open wing valve, flow to tank, weak 11/26/200417:33 blow Close wing valve,RIH W/L,tag fluid @ 530'pull from 900', recovered 1.4 11/26/200417:55 bbls. Close wing,RIH W/L,tag fluid @ 11/26/200418:30 659'pull from 1059' Open wing to Choke manifold, no 11/261200418:45 blow. Close wing,RIH W/L,tag fluid @ 11/26/200418:50 867'pull from 1267', rec. 1.4 bbls. Close wing,RIH W/L,tag fluid @ 11/26/200419:00 1043'pull from 1443',rec.1.0 bbls. Close wing,RIH W/L,tag fluid @ 11/26/200419:05 1217'pull from 1617',rec. 0.6 bbls. Open wing to Choke Manifold, no 11/26/200419:15 blow. Monitor well at Choke Manifold, no 11/26/200419:30 blow. Monitor well at Choke Manifold, 11/26/2004 20:00 slight blow. Pøwer~ SERVICES WELLHEAD CONDITIONS WHP WHT CSG CHOKE BSW STATIC {psiG} {deg F} (psiG) (64ths),' (%) (psjG) 42 458 128 42 458 128 42 458 128 42 458 128 42 458 128 42 458 128 42 458 128 42 458 128 42 128 458 42 458 128 42 458 128 42 458 128 42 458 128 42 458 128 42 458 128 42 515 128 42 515 128 42 515 128 42 515 128 42 515 128 42 515 128 COMPANY: FIELD: LEASE: WELL#: CO. REP.: Forest Oil West Foreland WF#2 (WF#1-9200) West Foreland #2 Fred Brent SEPARATOR CONDITIONS TOTAL GAS TOTAL WATER DIFF TEMP ORIFICE GASGRAV GAS RATE ~s CuM.... .WT. CHLORIDES, H2O RATE CUMM. (insH20) (deg f) (ins.) air=1.0 (mscfld) (msct) (ppg) (ppm) (bw/d) (bbls) Page 2 \{ ~ r- POWER WELL SERVICES SURFACE WELL TESTING REPORT DATEmME m/d/yr hr:mn 11/26/200420:15 11/26/200420:40 11/26/200420:50 11/26/200421 :05 11/26/200421 :40 11/26/200422:00 W/L RIH, tag fluid @ 963', pull from 1463', recover 1.4 bbls. W/L RIH, tag fluid @ 1162', pull from 1662', recover 1.5 bbls. W/L RIH, tag fluid @ 1368', pull from 1868', recover 1.4 bbls. W/L RIH, tag fluid @ 1504', pull from 1904', recover 0.75 bbls. W/L RIH, tag fluid @ 1340', pull from 1740', recover 1.5 bbls. W/L rig down, open well to Choke Manifold, monitor well. 18.75 bbls recovered from swabbing. Monitor well at Choke Manifold, very 11/26/200423:00 slight blow. Monitor well at Choke Manifold. Very 11/27/20040:00 slight blow. Monitor well at Choke Manifold. Very 11/27/20041 :00 slight blow. Monitor well at Choke Manifold. Very 11/27/20042:00 slight blow. Monitor well at Choke Manifold. Very 11/27/20043:00 slight blow. Monitor well at Choke Manifold. Very 11/27/20044:00 slight blow. Monitor well at Choke Manifold. Very 11/27/20045:00 slight blow. Monitor well at Choke Manifold. Very 11/27/20046:00 slight blow. Rig up to swab 11/27/20046:30 Monitor well at Choke Manifold. Very 11/27/20047:00 slight blow. W/L RIH, tag fluid @ 200', pull from 11/27/20047:20 600', recover 1.2 bbls. Monitor well at Choke Manifold. Very 11/27/20048:00 slight blow. Monitor well at Choke Manifold. Very 11/27/20049:00 slight blow. W/L RIH, tag fluid @ 285', pull from 11/27/20049:15 685', recover 1.0 bbls. W/L RIH, tag fluid @ 520', pull from 11/27/20049:27 920', recover 1.5 bbls. Pøwer~ SERVICES WELLHEAD. CONDITIONS WHP WHT CSG. CHOKE BSW STATIC (psiG) (deg F) (psiG). (64ths) (%) (psiG) 42 515 128 42 515 128 42 515 128 42 515 128 42 515 128 42 515 128 42 515 128 42 515 128 42 468 128 42 468 128 42 457 128 42 457 128 42 448 128 42 448 128 42 448 128 42 448 128 42 448 128 42 448 128 42 448 128 42 448 128 42 448 128 COMPANY: FIELD: LEASE: WELL#: CO. REP.: Forest Oil West Foreland WF#2 (WF#1-9200) West Foreland #2 Fred Brent SEPARATOM CONDITI.ONS TOTAL GAS TOTAl WATER DIFF TEMP. ORIFICE GASGRAV GAS RATE GÅS CUMM~ WT. CHLORIDES H20 RATE CUMM. (insH20) (deg f) (ins.) air=1.0 (mscf/d) (mscf) (ppg) (ppm) (bwld) (bbls) Page 3 t \, r- POWER WELL SERVICES SURFACE WELL TESTING REPORT W/L RIH, tag fluid @ 743', pull from 11/27/20049:40 1143', recover 1.75 bbls. W/L RIH, tag fluid @ 950', pull from 11/27/20049:51 1350', recover 1.0 bbls. Monitor well at Choke Manifold. Very 11/27/200410:00 slight blow. W/L RIH, tag fluid @ 815', pull from 11/27/200410:56 1215', recover 1.0 bbls. W/L RIH, tag fluid @ 1000', pull from 11/27/200411:10 1400', recover 1.0 bbls. W/L RIH, tag fluid @ 1150' pull from 11/27/200411:22 1550', recover 1.0 bbls. W/L RIH, tag fluid @ 1275' pull from 11/27/200411:36 1675', recover 1.0 bbls. Monitor well at Choke Manifold. Very 11/27/200412:00 slight blow. W/L RIH, tag fluid @ 1345' pull from 11/27/200412:20 1745', recover 1.2 bbls. W/L RIH, tag fluid @ 1130' pull from 11/28/200413:18 1530', recover 1.0 bbls. W/L RIH, tag fluid @ 1290' pull from 11/28/200413:30 1690', recover 1.50 bbls. W/L RIH, tag fluid@ 1430' pull from 11/28/200413:43 1830', recover .75 bbls. W/L RIH, tag fluid @ 1525' pull from 11/28/200414:00 1925', recover .75 bbls. W/L RIH, tag fluid @ 1360' pull from 11/28/200414:42 1760', recover.5 bbls. W/L RIH, tag fluid @ 1400' pull from 11/28/200415:00 1800', recover 1.0 bbls. W/L RIH, tag fluid @ 1470' pull from 11/28/200415:12 18700', recover .75 bbls. Rig down wireline and pipe back to 11/28/200416:00 choke 11/28/200417:00 Move choke house and SSV 11/28/200418:00 Shift change, continue to rig down 12/10/20048:15 Began RIU Well Test equipment Wireline commence swabbing 12/10/200421:30 operation W/L commences swabbing on long 12/10/200421 :30 string Pøwer~ SERVICES WELLHUQ CQNQlTlONS WHP WHT: C$G..... CHOKE SSW STA'TtC. (psiG) (deg. F) (psiG) (64ths) (%) (psiG) 42 448 128 42 448 128 42 448 128 42 448 128 42 448 128 42 448 128 42 448 128 42 448 128 42 448 128 42 448 128 42 448 128 42 448 128 42 448 128 42 448 128 42 448 128 42 448 128 42 448 128 COMPANY: FIELD: LEASE: WELL#: CO. REP.: Forest Oil West Foreland WF#2 (WF#1-9200) West Foreland #2 Fred Brent SEPARATOJtCON:DITIONS TOTAL GAS TOTAL WAn:~ .~DIFF TEMP ORIFICE. GASGRAV GASAATE GAS CU:MM~ WT. CHLORIDEs H2O RATE.. .CUMM. (insH20) (deg f) (ins.) air=1.0' (mscfld) (mscf) (ppg) (ppm) (bw/d)~(bbls) Page 4 c r- POWER WELL SERVICES SURFACE WELL TESTING REPORT REMARKS . m1d1yr hr.mn 12/101200423:00 Complete RIU of test equipment. 12/101200423:30 Run #2, tag fluid @ 5600', pull from 6350, recovered 3 bbls. Run #3, tag fluid @ 5600', pull from 6200, recovered 0 bbls. Run #4, tag fluid @ 5600', pull from 6200, recovered 0 bbls. Run #5, tag fluid @ 5910', pull from 6650, recovered 7 bbls. Total. 12111/20040:35 12111/20041:15 12111/20042:18 12111/20043:05 Run #6, tag fluid @6365', pull from7300', recovered 0 bbls. Run #7, tag fluid @6345', pull from7000'. Total recovered -long string 10 bbl. Swab run #8 12111/20044:00 12111/20045:30 12/11/20045:50 Wireline having problems 12/11/20046:20 Wireline pull out of hole 12/11/20046:50 Wireline out of hole Run in hole on short string for Swab 12/11/20047:18 #1 Swab run #1, Tag fluid 80', pull from 12/11/20047:25 320'. Swab run #2, Tag fluid ?', pull from 12/11/20047:30 320'. Swab run #3, Tag fluid 120", pull 12/11/20047:40 from 600'. Swab run #4, Tag fluid 390', pull from 12/11/20047:50 900'. Swab run #5, Tag fluid 620', pull from 12/11/20048:00 1250'. Total recovery 5 bbl. Swab run #6, Tag fluid 890", pull 12/11/20048:20 from 1500'. Swab run #7, Tag fluid1400', pull 12/11/20048:40 from 2050'. Swab run #8, Tag fluid1725', pull 12/11/20049:00 from 2450'. Swab run #9, Tag fluid 1770', pull 12/11/20049:40 from 2350'. Total recovery 9 bbl. Pøwer~ SERVICES WELLHEAD CQNDlTlONS WHP WHTcsG. CHOKE SSW STAllC' (psiG) , (deg F) . (psiG) (64ths) (%) {psiG} COMPANY: FIELD: LEASE: WELL#: CO. REP.: Forest Oil West Foreland WF#2 (WF#1-9200) West Foreland #2 Fred Brent SEPARATOR CONDITIONS TOTAl GAS TOTAL WATER . DIFF TEMP ORtFICE GASGRAV GAS RATE, GASCU..ft'.WT. CHLORIDES H20RATE CUMM. (insH20) (deg f) (ins.)air=1.0 (msCfld)' (mscf) (ppg) (ppm) (bw/d) , (bbls) Page 5 "-1 POWER WELL SERVICES SURFACE WELL TESTING REPORT 12/11/200413:00 12/11/200413:30 12/11/200414:15 12/11/200415:00 12/11/200415:40 12/11/200416:20 12/11/200417:10 12/11/200418:40 12/11/200420:00 12/11/200421:00 12/11/200422:00 12/11/200422:30 12/11/200423:45 Swab run #10, Tag fluid 2200', pull from 3400'. Swab run #11, Tag fluid 2900', pull from 4200'. Total fluid recovery 15 bbl. Swab run #12, Tag fluid 3350', pull from 4350' Total recovery 17 bbl. Swab run #13, Tag fluid 3850', pull from 4850' Total recovery 18 bbls Swab run #14, Tag fluid 4750', pull from 5750' Total fluid recovered 19 bbl Swab run #15, Tag fluid 5100', pull from 6200' Total fluid recovery 22 bbl. Swab run #16, Tag fluid 5125', pull from 6125' Total fluid recovery 26 bbl. Swab run #17, Tag fluid 5980', pull from 7200' Total fluid recovery 29 bbl. Swab run #18, Tag fluid 6550', pull from 7300' Total fluid recovery 30.25 bbl. Swab run #19, Tag fluid 7050', pull from 7750' Total fluid recovery from short string-30.25 bbl. Wireline rig down. Total fluid recovered from both strings - 40.25 bbls BJ nitrogen rig up. Safety huddle prior to dropping bar. Drop bar, fire guns on long string. Pøwer~ SERVICES WELLHE4J).CONDITIONS WHP Wl:iT : CS~ CHOKE SSW STAllC (psiG) . (deg F}fpsiG) (64ths) (%) (psiG) Guns fired. 12/11/200423:48 Shut in @ choke. Initial tank start - 12/11/200423:55 40.25 bbls 225 12/12/20040:10 Open to tank@ 12/64 choke 1075 78 12/12/20040:15 Open to tank 1160 66 12 12/12/20040:25 Shut in to peñorate short string. 1160 66 12 COMPANY: FIELD: LEASE: WELL#: CO. REP.: Forest Oil West Foreland WF#2 (WF#1-9200) West Foreland #2 Fred Brent , ,.SEPARATOR CONDITIONS TOTAL GAS TOTÞ4- WATER DIFF TEMP ORIFICE GASGRAV GASRATE,GA$ CUMM. WT. CHLORIDES H20RATE (insH20) (deg t)'(ins.) air=1.0 (mset/d) (mscf) (ppg) (ppm) ,(bw/d) Page 6 (bbls) 1152.00 12.00 COMPANY: Forest Oil POWER WELL SERVICES Pøwer~ FIELD: West Foreland SURFACE WELL TESTING REPORT LEASE: WF#2 (WF#1-9200) SERVICES WELL#: West Foreland #2 CO. REP.: Fred Brent WEl..t..HEAOCONDIT10NS: SEPARATORCONDtt~NS TOTALGAS tOTAl:..WAJ'ER WHP WHTC$G CHOK$,B$W' / StATIC DIFF TEMP '. 'ORlFICE GAS GRAV GAS RAtE GASCUMM;.WT.. CHt..ORlPESH~()·RAT¡: CUMM. (psiG) (degF) (p.siG) "(GoIths) '..,(%) (psiG) (il1sH2Q) . , (degf) (ins.) air=1.0 (mscf/d) ·(msèf) (þpg) (ppm) (bwld) (bbls) BJ start pumping N2,will pressure up 12/12/20041 :00 to 4500 psi. 12.00 12/12/20042:15 Guns fired on short string. 12.00 12/12/20042:53 Bled pressure to 2409 psi. 2409 12.00 Open well to choke manifold to 12/12/20043:00 separator. (long string) 2409 225 12.00 Flowing well to separator & flare @ 12/12/20043:15 10/64 choke 1837 72 225 10 12.00 Flowing on 10/64 choke· Est. Gas 12/12/20043:45 Rate via choke coefficient 1767 68 250 10 0 0.650 988.00 30.88 0.00 12.00 Flowing on 10/64 choke· Est. Gas 12/12/20044:00 Rate via choke coefficient 1842 65 250 10 0 0.650 1033.00 41.64 0.00 12.00 12/12/20044:30 Drop 2.25 plate· 04:10 hrs 1874 68 292 10 0 490 16 95 2.250 0.650 2992.49 103.98 0.00 12.00 Salinity taken on completion fluid 12/12/20045:00 (cushion) 1955 66 308 10 0 450 12 106 2.250 0.600 2536.05 156.81 28000 0.00 12.00 12/12/20045:30 Flowing well to separator & flare 1923 69 332 10 0 450 12 109 2.250 0.600 2527.97 209.48 0.00 12.00 Increase choke to 12/64 450 108 2.250 12/12/20046:00 1995 68 336 10 0 11 0.600 2422.88 259.96 0.00 12.00 12/12/20046:30 Ice plug in line. Shut in at wing valve 1757 70 347 12 0 450 20 110 2.250 0.600 3260.45 327.88 0.00 12.00 Open well (long string) on 12/64 12/12/20047:52 adjustable choke 2087 315 327.88 12.00 12/12/20048:00 Flowing well to separator & flare 1871 70 298 12 0 450 24 95 2.250 0.600 3630.13 348.05 28000 90.00 ~~C 12/12/2004 8:30 Flowing well, dry gas only 1706 64 347 12 0 450 24 104 2.250 0.600 3594.72 422.94 0.00 12.50 12/12/20049:00 Flowing well, 0.5% CO2 1732 69 388 12 0 450 25 106 2.250 0.600 3659.43 499.18 28000 24.00 13.00 12/12/20049:30 Gas gravity 0.598 1748 72 429 12 0 450 26 112 2.250 0.598 3713.90 576.55 0.00 13.00 12/12/200410:00 Flowing well, dry gas only 1747 71 461 12 0 450 26 114 2.250 0.598 3706.15 653.76 0.00 13.00 12/12/200410:30 Flowing well, dry gas only 1749 72 487 12 0 450 28 115 2.250 0.598 3842.14 733.81 0.00 13.00 Increase choke to 14/64ths 72 12 0 450 28 115 2.250 0.598 3842.14 813.85 0.00 13.00 12/12/2004 11 :00 1756 509 Continue to flow well 0 450 110 2.250 0.598 4379.84 12/12/200411:30 1584 75 536 14 36 905.10 0.00 13.00 Continue to flow well 0 450 36 112 2.250 0.598 4370.65 996.15 12/12/200412:00 1590 74 543 14 0.00 13.00 Page 7 POWER WELL SERVICES SURFACE WELL TESTING REPORT Pøwer~ SERVICES COMPANY: FIELD: LEASE: WELL#: CO. REP.: Forest Oil West Foreland WF#2 (WF#1-9200) West Foreland #2 Fred Brent 'WELLHEAD CONDITIONS WHP' WHT CSG CHOKEBSW STATIC (psiG) (deg F) (psiG) (64ths). (psiG) SEPARATOR CONDITIONS TOTAL GAS TOTAL WATER DIFF TEMP, ORIFICE GASGRAV GAS RAT~ GAS,CUMM.. WT. CHLORIDES H20 RATE CUMM. (insH20) (deg f) (ins.) air=1.0(mscfld) · (mscf) (ppg)' (ppm) , (bw/d) (bbls) Continue to flow well 121121200412:30 1592 74 589 14 0 450 36 111 2.250 0.598 4375.23 1087.30 0.00 13.00 12/12/200413:00 Continue to flow well, Dry gas. 1581 74 611 14 0 450 36 112 2.250 0.598 4370.65 1178.36 0.00 13.00 Continue to flow well 121121200413:30 1574 76 631 14 0 450 37 114 2.250 0.598 4421.74 1270.48 0.00 13.00 Increase choke to 16164ths 121121200414:00 1601 74 648 14 0 450 37 114 2.250 0.598 4421.74 1362.60 0.00 13.00 Gas gravity 0.596, no change in tank 121121200414:30 reading 1424 74 665 16 0 450 48 110 2.250 0.596 5065.71 1468.13 0.00 13.00 Continue to flow well 121121200415:00 1429 74 684 16 0 450 46 110 2.250 0.596 4958.93 1571.44 0.00 13.00 Continue to flow well 12/121200415:30 1440 75 701 16 0 450 48 109 2.250 0.596 5071.04 1677.09 0.00 13.00 Continue to flow well 121121200416:00 1431 75 716 16 0 450 48 109 2.250 0.596 5071.04 1782.74 0.00 13.00 Continue to flow well 121121200416:30 1436 74 731 16 0 450 48 109 2.250 0.596 5071.04 1888.38 0.00 13.00 Increase choke to 18164ths 121121200417:00 1427 74 743 16 0 450 48 109 2.250 0.596 5071.04 1994.03 0.00 13.00 121121200417:30 Gas gravity .595 C02 0.3% 1276 71 752 18 0 450 53 104 2.250 0.595 5362.22 2105.74 0.00 13.00 Continue to flow well 121121200418:00 1277 70 763 18 0 450 52 104 2.250 0.595 5311.33 2216.40 0.00 13.00 Continue to flow well 121121200418:30 1300 71 775 18 0 455 53 104 2.250 0.595 5392.61 2328.74 0.00 13.00 Took 1-1000cc & 1-300cc gas sample 1304 71 785 18 0 455 54 104 2.250 0.595 5443.31 2442.15 13.00~ 121121200419:00 0.00 Continue to flow well 121121200419:30 1311 74 796 18 0 455 55 104 2.250 0.595 5493.55 2556.59 0.00 13.00 121121200420:00 Shut well in for 12 hr. build up. 1313 75 807 18 0 455 55 104 2.250 0.595 5493.55 2671.04 0.00 13.00 Monitor build up - Pressures from 121121200420:01 Spider gauge 1831 818 2671.04 13.00 Monitor build up - Pressures from 121121200420:02 Spider gauge 1972 826 2671.04 13.00 Monitor build up - Pressures from 121121200420:03 Spider gauge 2106 830 2671.04 13.00 Monitor build up - Pressures from 12/12/200420:04 Spider gauge 2175 831 2671.04 13.00 Monitor build up - Pressures from 121121200420:05 Spider gauge 2239 831 2671.04 13.00 f=--' Monitor build up - Pressures from 121121200420:15 Spider gauge 2375 804 2671.04 13.00 Page 8 POWER WELL SERVICES SURFACE WELL TESTING REPORT Pøwer~ SERVICES WELLHEAD CONDITIONS WHP WHT CSG, CHOKEBSW STATIC ,(psiS) (deg F) (psiG) (64ths) (%) (psiG) Monitor build up - Pressures from 121121200420:30 Spider gauge 2399 771 Monitor build up - Pressures from 121121200420:45 Spider gauge 2414 736 Monitor build up - Pressures from 12/12/200421 :00 Spider gauge 2423 706 Monitor build up - Pressures from 12/12/200421:15 Spider gauge 2431 677 Monitor build up - Pressures from 12/12/200421 :30 Spider gauge 2436 653 Monitor build up - Pressures from 12/12/200421 :45 Spider gauge 2441 627 Monitor build up - Pressures from 12/12/200422:00 Spider gauge 2445 606 Monitor build up - Pressures from 12/12/200422:15 Spider gauge 2448 589 Monitor build up - Pressures from 12/12/200422:30 Spider gauge 2450 573 Monitor build up - Pressures from 12/12/200422:45 Spider gauge 2453 550 Monitor build up - Pressures from 12/12/200423:00 Spider gauge 2456 535 Monitor build up - Pressures from 12/12/200423:15 Spider gauge 2457 524 Monitor build up - Pressures from 12/12/200423:30 Spider gauge 2460 508 Monitor build up - Pressures from 12/12/200423:45 Spider gauge 2461 497 Monitor build up - Pressures from 12/13/2004 0:00 Spider gauge 2463 484 Monitor build up - Pressures from 12/13/20040:15 Spider gauge 2464 473 Monitor build up - Pressures from 12/13/20040:30 Spider gauge 2465 460 Monitor build up - Pressures from 12/13/20040:45 Spider gauge 2466 450 Monitor build up - Pressures from 12/13/20041:00 Spider gauge 2467 440 Monitor build up - Pressures from 12/13/20041:15 Spider gauge 2469 431 Monitor build up - Pressures from 12/13/20041:30 Spider gauge 2470 421 Monitor build up - Pressures from 12/13/20041:45 Spider gauge 2470 413 COMPANY: FIELD: LEASE: WELL#: CO. REP.: Forest Oil West Foreland WF#2 (WF#1-9200) West Foreland #2 Fred Brent SEPARATORCONPI1l0NS TOTAL GAS TOTAL WATER DIFF TEMP ORIFICE GASGRAV GAS RATE GASCUMM. WT. CHLOQlDES .H20RATE CUMM. (insH20) (deg f) (ins.) air=1.0 (mscf/d) (mscf) (ppg) (ppm) (bw/d) (bbls) 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 Page 9 13.00 13.00 13.00 13.00 ( 13.00 13.00 13.00 13.00 13.00 13.00 13.00 13.00 13.00 13.00( 13.00 13.00 13.00 13.00 13.00 13.00 13.00 13.00 POWER WELL SERVICES SURFACE WELL TESTING REPORT Power!/.Yl@[fß SERVICES . WELLHEADCONDIrtONS WHPWHT CSG CHOKEBSW ~STATIC, (psiG) (degF) (psiG) (64ths) (%) (psiS) Monitor build up - Pressures from 12/13/20042:00 Spider gauge 2471 408 Monitor build up - Pressures from 12/13/20042:15 Spider gauge 2472 397 Monitor build up - Pressures from 12/13/20042:30 Spider gauge 2472 388 Monitor build up - Pressures from 12/13/20042:45 Spider gauge 2473 382 Monitor build up - Pressures from 12/13/20043:00 Spider gauge 2474 375 Monitor build up - Pressures from 12/13/20043:15 Spider gauge 2474 369 Monitor build up - Pressures from 12/13/20043:30 Spider gauge 2475 362 Monitor build up - Pressures from 12/13/2004 3:45 Spider gauge 2475 355 Monitor build up - Pressures from 12/13/20044:00 Spider gauge 2476 349 Monitor build up - Pressures from 12/13/20044:15 Spider gauge 2476 343 Monitor build up - Pressures from 12/13/2004 4:30 Spider gauge 2477 338 Monitor build up - Pressures from 12/13/20044:45 Spider gauge 2477 332 Monitor build up - Pressures from 12/13/20045:00 Spider gauge 2477 326 Monitor build up - Pressures from 12/13/20045:15 Spider gauge 2478 321 Monitor build up - Pressures from 12/13/20045:30 Spider gauge 2478 321 12/13/2004 5:45 Spider gauge failed. 12/13/20047:00 Shut in master valve, test completed. COMPANY: FIELD: LEASE: WELL#: CO. REP.: Forest Oil West Foreland WF#2 (WF#1-9200) West Foreland #2 Fred Brent SEPARATORCONDmONS TOTAL ßASTOTALWATER .. DlFF TI;MP oatFICE GASGRAV GAS8åTE GAS CUMM. WI... CHL.ORIDE$ H20 RATE CUM". (msH20) (clegf) \ (ins.) air=1.0 (mscffd) (mscf) (ppgl (ppm) (bwfd) (bbls) 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 2671.04 Page 10 13.00 13.00 13.00 13.00 . 13.00 13.00 13.00 13.00 13.00 13.00 13.00 13.00 13.00 13.00( 13.00 13.00 13.00 SURFACE WELL TESTING REPORT GAS FLOW RA TE CALCULA TIONS Pøwer~ SERVIces DATEITIME t.MI: rnfdiyrhr:ml1 (.nth) 12/12/20043:45 45 12/12/2004 4:00 15 12/12/20044:30 30 12/12/20045:00 30 12/12/20045:30 30 12/12/20046:00 30 12/12/20046:30 30 12/12/2004 8:00 8 12/12/20048:30 30 12/12/20049:00 30 12/12/2004 9:30 30 12/12/2004 10:00 30 12/12/200410:30 30 12/12/2004 11 :00 30 12/12/2004 11 :30 30 12/12/200412:00 30 12/12/200412:30 30 12/12/2004 13:00 30 12/12/200413:30 30 12/12/200414:00 30 12/12/200414:30 30 12/12/200415:00 30 12/12/200415:30 30 12/12/200416:00 30 12/12/200416:30 30 12/12/200417:00 30 COMPANY: LEASE: WELL#: HI-STAGE METER RUN SIZE: HI-STAGE SEPARATQR CONDITIONS HI-STAGE LO-STAGE SEPARATOR CONDITIONS STAtiC DIFFI GAS.T ORIFICE GASGR H2S C02· GASRAtE GÁS CUMM ... STATIC biFF GÁS T ORIFICE GASGR H2S C02 (psiG) (n we) (deg F } (inches) (air=1) (ppm)(%) (mseffd) (mscf) (psiG) (n we) (deg F) {inches} (aif.=1)(%) (%) Estimated rate via choke coeffient Estimated rate via choke coeffient 490 16 95 2.250 450 12 106 2.250 450 12 109 2.250 450 11 108 2.250 450 20 110 2.250 450 24 95 2.250 450 24 104 2.250 450 25 106 2.250 450 26 112 2.250 450 26 114 2.250 450 28 115 2.250 450 28 115 2.250 450 36 110 2.250 450 36 112 2.250 450 36 111 2.250 450 36 112 2.250 450 37 114 2.250 450 37 114 2.250 450 48 110 2.250 450 46 110 2.250 450 48 109 2.250 450 48 109 2.250 450 48 109 2.250 450 48 109 2.250 0.00 0.00 988.00 0.00 0.00 1033.00 2992.49 2536.05 2527.97 2422.88 3260.45 3630.13 3594.72 3659.43 3713.90 3706.15 3842.14 3842.14 4379.84 0.650 0.00 0.00 0.600 0.00 0.00 0.600 0.00 0.00 0.600 0.00 0.00 0.600 0.00 0.00 0.600 0.00 0.00 0.600 0.00 0.00 0.600 0.00 0.50 0.598 0.00 0.50 0.598 0.00 0.50 0.598 0.00 0.50 0.598 0.00 0.50 0.598 0.00 0.50 0.598 0.00 0.50 4370.65 0.598 0.00 0.50 4375.23 0.598 0.00 0.50 4370.65 0.598 0.00 0.50 4421.74 0.598 0.00 0.50 4421.74 0.596 0.00 0.50 5065.71 0.596 0.00 0.50 4958.93 0.596 0.00 0.50 5071.04 0.596 0.00 0.50 5071.04 0.596 0.00 0.50 5071.04 0.596 0.00 0.50 5071.04 30.88 41.64 103.98 156.81 209.48 259.96 327.88 348.05 422.94 499.18 576.55 653.76 733.81 813.85 905.10 996.15 1087.30 1178.36 1270.48 1362.60 1468.13 1571.44 1677.09 1782.74 1888.38 1994.03 Page 1 Forest Oil WF#2 (WF#1-9200) West Foreland #2 3.826" TOTAL GAS G.ASRATE GAS CUMM (mscf/d) (mscf) 988.00 30.88 1033.00 41.64 2992.49 103.98 2536.05 156.81 ( 2527.97 209.48 2422.88 259.96 3260.45 327.88 3630.13 348.05 3594.72 422.94 3659.43 499.18 3713.90 576.55 3706.15 653.76 3842.14 733.81 3842.14 813.85 4379.84 905.10 4370.65 996.15 4375.23 1087.30 4370.65 1178.36 4421.74 1270.48 4421.74 1362.60 5065.71 1468.13 4958.93 1571.44 5071.04 1677.09 5071.04 1782.74 5071.04 1888.38 5071.04 1994.03 SURFACE WELL TESTING REPORT GAS FLOW RA TE CALCULA TIONS Pøwer~ SERVICES COMPANY: LEASE: WELL#: DATElTIME m/dlyr hr:mn TIME (min) 12/12/200417:30 30 12/12/2004 18:00 30 12/12/200418:30 30 12/12/200419:00 30 12/12/200419:30 30 12/12/2004 20:00 30 HI-STAGE METER RUN SIZE: HI-STAGE SEPARATOR CONDITIONS HI-STAGE LO-STAGE SEPARATOR CONOmONS STATIC DIFF GAS T ORIFICE GAS GR H2s· C02 GASRI\.TE' GAS·CUMM STATIC DIFF GAS T ORIFICE GAS GR H2S C02 (psiG) (D we) (deg F )(in~hes) (air=i1) (PPn1)(%) (msef/d) (mscf) (psiG)' ("we) (deg F) (inches) (air=1)(%) (%) 450 53 104 2.250 0.595 0.00 0.30 5362.22 2105.74 450 52 104 2.250 0.595 0.00 0.30 5311.33 2216.40 455 53 104 2.250 0.595 0.00 0.30 5392.61 2328.74 455 54 104 2.250 0.595 0.00 0.30 5443.31 2442.15 455 55 104 2.250 0.595 0.00 0.30 5493.55 2556.59 455 55 104 2.250 0.595 0.00 0.30 5493.55 2671.04 Page 2 Forest Oil WF#2 (WF#1-9200) West Foreland #2 3.826" TOTAL GAS GASRATE GAS CUMM (mscfld) (msd) , 5362.22 2105.74 5311.33 2216.40 5392.61 2328.74 5443.31 2442.15 5493.55 2556.59 5493.55 2671.04 POWER WELL SERVICES SURFACE WELL TESTING REPORT Pøwer~ SERVICES COMPANY: FIELD: LEASE: WELL#: CO. REP.: Forest Oil West Foreland WF#2 (WF#2-8500) West Foreland #2 Fred Brent WELLHEAD'.C()NDITIONS WHP WHT. ·.CSG· CHOKE SSW .STATIC (psiG) (degF) .(psiG)'. (64ths) (%) (psiG) SEPARATOR CONDITION.$ TOTAL"GÄS. TOTAL WAteR DII=í= TEMP Ò8IFICE .G~G~V GAS SATE GA.$ CUM". .'NT. CHLORIDES .H20RÀTE CUMM. (inSH20) (deg f) (ins.)- air=:t.O (msCfld) (msèf) (ppg) (ppm) (bw/d) (bbls) Open well on 10/64 adjustable choke 12/13/200410:08 to separator and flare. 2740.0 72 220 0 12/13/200410:10 Well flowing 2400.0 72 230 10 Gas at suñace 12/13/200410:15 2200.0 64 250 10 12/13/200410:25 Liquid at surface 2500.0 60 340 10 12/13/200410:30 Choke plugging, increase to 12/64 2450.0 60 350 12 Continue to flow well 12/13/200410:45 2500.0 61 350 12 Continue to flow well. C02 = 0.3% 0 450 18 100 2.250 0.595 3137.13 65.36 12/13/200411 :00 2755.0 72 400 12 3 bbls of cushion recovered in tank. 450 102 2.250 3299.77 134.1 0 12/13/2004 11 : 30 2760.0 72 430 12 0 20 0.595 12/13/200412:00 Start of step rate test 2800.0 74 450 12 0 450 16 107 2.250 0.595 2935.54 195.26 12/13/200412:30 Gas gravity .594 2800.0 76 475 12 0 450 20 108 2.250 0.594 3281.18 263.62 C02 = 0.5% 2.250 3281.18 12/13/2004 13:00 2800.0 76 500 12 0 450 20 108 0.594 331.98 Rock choke, suspect debris (13:10 12/13/200413:30 hrs) 2725.0 75 540 12 0 450 30 106 2.250 0.594 4026.95 415.87 12/13/200414:00 Pressures taken from Spider gauge 2724.0 70 601 12 0 450 32 100 2.250 0.594 4185.95 503.08 Continue to flow well 450 2.250 4237.20 12/13/200414:30 2749.5 71 627 12 0 33 103 0.594 591.35 Increase choke to 14/64ths 450 101 2.250 4273.20 12/13/200415:00 2731.8 71 653 12 0 35 0.594 680.38 Unload mud from reservoir 12/13/200415:30 2548.5 71 717 14 0 450 84 84 2.250 0.594 6907.43 824.28 3 bbls increase in tank level 0 450 98 79 2.250 0.594 7504.86 980.63 12/13/200416:00 2492.5 70 736 14 Continue to flow well 71 14 0 450 98 78 2.250 0.594 7513.52 1137.16 12/13/200416:30 2496.3 822 12/13/200417:00 Gas gravity = .582 2495.1 72 864 14 0 450 100 78 2.250 0.582 7658.09 1296.71 Continue to flow well 450 100 78 2.250 0.582 7658.09 12/13/200417:30 2498.5 74 898 14 0 1456.25 Increase choke to 16/64 ths 14 0 450 102 79 2.250 0.582 7725.62 1617.20 12/13/200418:00 2506.3 74 936 Continue to flow well 74 16 0 450 135 75 2.250 0.582 8932.41 1803.29 12/13/200418:30 2373.6 972 Page 1 25000 0.00 0.00 144.00 3.00 0.00 3.00 0.00 3.00 0.00 3.00 0.00 3.00 0.00 3.00 0.00 3.00 ( 0.00 3.00 0.00 3.00 144.00 6.00 0.00 6.00 0.00 6.00 0.00 6.00 0.00 6.00 0.00 6.00 r- 25000 POWER WELL SERVICES SURFACE WELL TESTING REPORT DA"Æ/TlME mldfYr hr:lTln Continue to flow well, bled csg to 12/13/200419:00 478 psi. 12113/200419:30 Continue to flow well. Continue to flow well. 12/13/200420:00 12/13/200420:30 Continue to flow well. 12/13/2004 21 : 00 Increase choke to 18/64 ths 12/13/2004 21 : 30 Continue to flow well. Continue to flow well. Gas gravity= 12/13/200422:00 .594, C02 =.3 %. 12/13/200422:30 Continue to flow well. Take Gas samples, 1-1000cc & 1- 12/13/200423:00 300cc bottle 12/13/200423:30 Continue to flow well. 12/14/20040:00 Shut well in. Monitor Build Up 12/14/20040:01 Monitor Build up 12/14/20040:02 Monitor Build up 12/14/20040:03 Monitor Build up 12/14/20040:04 Monitor Build up 12/14/20040:05 Monitor Build up 12/14/20040:06 Monitor Build up 12/14/20040:07 Monitor Build up 12/14/20040:08 Monitor Build up 12/14/20040:09 Monitor Build up 12/14/20040:10 Monitor Build up 12/14/20040:15 Monitor Build up Pøwer~ SERVICES COMPANY: FIELD: LEASE: WELL#: CO. REP.: Forest Oil West Foreland WF#2 (WF#2-8500) West Foreland #2 Fred Brent WELLHEAD CONDITIONS, WHP WHT ·CSG CHO.œasW STATIC (psiG) (deg F) (psiG) {64ths}' (%} (psiG) SEPARATOR¡C()NDITIONS TOTAL GAS· TOTAL WATER DIFF TEMP ORIFICE GASGRAV GAS.RATE GASCUMM. WT., CHLORIDES H20 RATE CUMII. (insH20) (<leg f) (ins.) air=1.0 (mscfld) , (mscf) (ppg) (ppm) (bw/d) (bbls) 2376.3 72 478 16 0 450 135 75 2.250 0.582 8932.41 1989.39 0.00 6.00 2377.0 74 519 16 0 450 135 76 2.250 0.582 8922.10 2175.26 0.00 6.00 2383.9 75 545 16 0 450 135 76 2.250 0.582 8922.10 2361.14 0.00 6.00 2384.9 77 569 16 0 450 135 75 2.250 0.582 8932.41 2547.23 0.00 6.00 ( 2390.0 78 589 16 0 450 136 73 2.250 0.582 8986.38 2734.45 0.00 6.00 2240.9 77 606 18 0 455 170 72 2.250 0.582 10062.90 2944.09 0.00 6.00 2269.4 79 626 18 0 455 169 70 2.250 0.594 10027.20 3152.99 0.00 6.00 2278.8 79 642 18 0 455 169 70 2.250 0.594 10027.20 3361.89 0.00 6.00 2264.9 79 655 18 0 455 169 72 2.250 0.594 10003.50 3570.30 0.00 6.00 2260.1 79 669 18 0 455 168 73 2.250 0.594 9961.97 3777.84 0.00 6.00 2265.7 74 681 18 0 455 169 73 2.250 0.594 9991.69 3986.00 144.00 9.00 2931.2 696 3986.00 9.00 2963.5 696 3986.00 9.00 2967.4 690 3986.00 9.00 ( 2969.5 685 3986.00 9.00 2970.8 682 3986.00 9.00 2972.0 677 3986.00 9.00 2973.0 673 3986.00 9.00 2973.8 668 3986.00 9.00 2974.5 664 3986.00 9.00 2975.0 660 3986.00 9.00 2977.2 640 3986.00 9.00 Page 2 POWER WELL SERVICES SURFACE WELL TESTING REPORT Pøwer~ SERVICES COMPANY: FIELD: LEASE: WELL#: CO. REP.: Forest Oil West Foreland WF#2 (WF#2-8500) West Foreland #2 Fred Brent WELLHEAD CONDITIONS SEPARATOR CONDI'fION$ TOTAL. GAS TOTAL WATER WHP WHy eSG cHOKJ;J~$W, STATIC" DIFf TEMP ORIfiCE GASGRAV GAS.RATJ: GAS CUMM. WT. CHLORIDES H20 RAl'É (psiG) (deg f}(psiG) (64ths)· (%) (psiG)· (insH20)' (deg 1) (ins.) air=1.0 (mscf/d) (mscf) (ppg) (ppm) (bW/d) 12/14/20040:30 Monitor Build up 2980.3 585 12/14/2004 0:45 Monitor Build up 2981.5 542 12/14/20041:00 Monitor Build up 2982.2 500 12/14/20041:15 Monitor Build up 2982.6 464 12/14/20041 :30 Monitor Build up 2982.7 431 12/14/2004 1 :45 Monitor Build up 2982.8 400 12/14/20042:00 Monitor Build up 2982.8 372 12/14/20042:15 Monitor Build up 2982.9 345 12/14/20042:30 Monitor Build up 2982.8 320 12/14/20042:45 Monitor Build up 2982.7 298 12/14/20043:00 Monitor Build up 2982.6 276 12/14/20043:15 Monitor Build up 2982.6 255 12/14/2004 3:30 Monitor Build up 2982.5 236 12/14/2004 3:45 Monitor Build up 2982.0 216 12/14/20044:00 Monitor Build up 2982.3 201 12/14/20044:15 Monitor Build up 2982.2 201 12/14/20044:30 Monitor Build up 2981.9 169 12/14/20044:45 Monitor Build up 2982.0 154 12/14/20045:00 Monitor Build up 2981.6 140 12/14/20045:15 Monitor Build up 2981.3 127 12/14/20045:30 Monitor Build up 2981.2 115 12/14/2004 5:45 Monitor Build up 2981.2 103 3986.00 3986.00 3986.00 3986.00 3986.00 3986.00 3986.00 3986.00 3986.00 3986.00 3986.00 3986.00 3986.00 3986.00 3986.00 3986.00 3986.00 3986.00 3986.00 3986.00 3986.00 3986.00 Page 3 cOM",. (bbls) 9.00 9.00 9.00 9.00 ( 9.00 9.00 9.00 9.00 9.00 9.00 9.00 9.00 9.00 9.00 ( 9.00 9.00 9.00 9.00 9.00 9.00 9.00 9.00 '-'-' POWER WELL SERVICES SURFACE WELL TESTING REPORT DAJEmME rn/d/yr hr.mn 12/14/20046:00 12/14/20046:15 12/14/20046:30 12/14/20047:00 Monitor Build up Monitor Build up Monitor Build up Build up complete, Finish Test, rig down. Pøwer~ SERVICES WELLHEAD CONDI11.0NS WHP, WHT CSG. CHOKE ~W STATIC (psiG) (deg F) (psiG) (64ths)(%) (psiG) 2981.2 91 2981.0 63 2981.9 51 2980.6 46 COMPANY: FIELD: LEASE: WELL#: CO. REP.: Forest Oil West Foreland WF#2 (WF#2-8500) West Foreland #2 Fred Brent SEPARATOR CONDITIONS TQ1A1.. GAS TOTAL WATER DtFF ;TEMP,. .ORIFICE GASGAAV GAS RATE GASCUMM. W{. CHLORIDES H20AAtE CUMM. (insH20) «leg f). (ins.) air=1.0 (mscf/d) . (mscf) (ppg) (ppm) (bw/d) (bbts) 3986.00 3986.00 3986.00 3986.00 Page 4 9.00 9.00 9.00 9.00 :J~~' r·r,_. ( 12/13/2004 11 :00 30 450 18 100 2.250 0.595 0.00 0.30 3137.13 65.36 3137.13 65.36 12/13/2004 11 :30 30 450 20 102 2.250 0.595 0.00 0.30 3299.77 134.10 3299.77 134.10 12/13/2004 12:00 30 450 16 107 2.250 0.595 0.00 0.30 2935.54 195.26 2935.54 195.26 12/13/2004 12:30 30 450 20 108 2.250 0.594 0.00 0.30 3281.18 263.62 3281.18 263.62 12/13/200413:00 30 450 20 108 2.250 0.594 0.00 0.50 3281.18 331.98 3281.18 331.98 12/13/2004 13:30 30 450 30 106 2.250 0.594 0.00 0.50 4026.95 415.87 4026.95 415.87 12/13/200414:00 30 450 32 100 2.250 0.594 0.00 0.50 4185.95 503.08 4185.95 503.08 12/13/2004 14:30 30 450 33 103 2.250 0.594 0.00 0.50 4237.20 591.35 4237.20 591.35 12/13/2004 15:00 30 450 35 101 2.250 0.594 0.00 0.50 4273.20 680.38 4273.20 680.38 12/13/2004 15:30 30 450 84 84 2.250 0.594 0.00 0.50 6907.43 824.28 6907.43 824.28 12/13/200416:00 30 450 98 79 2.250 0.594 0.00 0.50 7504.86 980.63 7504.86 980.63 12/13/200416:30 30 450 98 78 2.250 0.594 0.00 0.50 7513.52 1137.16 7513.52 1137.16 12/13/2004 17:00 30 450 100 78 2.250 0.582 0.00 0.50 7658.09 1296.71 7658.09 1296.71 12/13/2004 17:30 30 450 100 78 2.250 0.582 0.00 0.50 7658.09 1456.25 7658.09 1456.25 12/13/200418:00 30 450 102 79 2.250 0.582 0.00 0.50 7725.62 1617.20 7725.62 1617.20 12/13/2004 18:30 30 450 135 75 2.250 0.582 0.00 0.50 8932.41 1803.29 8932.41 1803.29 12/13/200419:00 30 450 135 75 2.250 0.582 0.00 0.50 8932.41 1989.39 8932.41 1989.39 12/13/2004 19:30 30 450 135 76 2.250 0.582 0.00 0.50 8922.10 2175.26 8922.10 2175.26 12/13/2004 20:00 30 450 135 76 2.250 0.582 0.00 0.50 8922.10 2361.14 8922.10 2361.14 12/13/2004 20:30 30 450 135 75 2.250 0.582 0.00 0.50 8932.41 2547.23 8932.41 2547.23 12/13/200421 :00 30 450 136 73 2.250 0.582 0.00 0.50 8986.38 2734.45 8986.38 2734.45 12/13/200421 :30 30 455 170 72 2.250 0.582 0.00 0.50 10062.90 2944.09 10062.90 2944.09 12/13/200422:00 30 455 169 70 2.250 0.594 0.00 0.30 10027.20 3152.99 10027.20 3152.99 12/13/2004 22:30 30 455 169 70 2.250 0.594 0.00 0.30 10027.20 3361.89 10027.20 3361.89 12/13/2004 23:00 30 455 169 72 2.250 0.594 0.00 0.30 10003.50 3570.30 10003.50 3570.30 12/13/2004 23:30 30 455 168 73 2.250 0.594 0.00 0.30 9961.97 3777.84 9961.97 3777.84 Page 1 ( T(}TAL GAS GASRATE 'GAS CUMM (mscf/d) (mscf) Hl4)TAGE SEPARATORCONOmONS1iI~STAGE LQ-SrAGE SEPARATOR CONDITIONS ·DlfF '.' GAS T 'ORIRèeGMGR: ., ms,' COZ GÄSRÄTEGAS CUMM STATIC, DiFF GAS T, ORIFICE GASGR H2S, . CO2 (n we) (deg F) (inehes) · (åÎF1)'(ppm) (%) . (msèfid) (mscf) (psiGf rwe)(dèg F ) (inèhés) (air=1) (%) (%) 3.826" Pøwer~ SERVICES SURFACE WELL TESTING REPORT GAS FLOW RA TE CALCULA T/ONS HI-STAGE METER RUN SIZE: Forest Oil WF#2 (WF#2-8500) West Foreland #2 COMPANY: LEASE: WELL#: SURFACE WELL TESTING REPORT GAS FLOW RA TE CALCULA TIONS 12/14/20040:00 30 455 PowerYr/@{JJ1 SERVICES COMPANY: LEASE: WELL#: HI-STAGE METER RUN SIZE: HI-5TAGE$EPARATOR CONDITIONS HI-5TAGE ' lO-$TAGE SEP~TØRCONDITJONS DlFFGMT ORlFrce.GAS..GRH2S"Ç02;. 'GASRATE GASCU¥MSTATfC OIFF., G~$T' ORIFJtE GA$GR H2S, CO2 (n we) (deg F) (ir.ches) (air=1) (ppm) ('Yo) . (msefld) (mSèf) (pSiG) (n wc) (deg F) (inches) (air-=1) ('Yo) ('Yo) 169 73 2.250 0.594 0.00 0.30 9991.69 3986.00 Page 2 Forest Oil WF#2 (WF#2-8500) West Foreland #2 3.826" TOTAL GAS GA$RATE GAS CUMM (m$cfld) (lffscf) 9991.69 3986.00 ( ( COMPANY: FIELD: LEASE: WELL#: S. O. #: Forest Oil West Foreland WF#2 (WF#1-9200/WF #2-8500) West Foreland #2 PWS-AK-0011 SEQUENCE OF OPERATIONS Pøwer!A'!/@l1J SERVICES 24-Nov-04 3:30 8:20 9:35 9:50 10: 15 11 : 30 11 :55 12:00 12:45 Mike Joiner 14:00 George Bryce 25-Nov-04 5:30 5:45 6:47 7:10 Total hrs: 24 8:15 9:15 9:20 9:35 9:40 9:45 9:55 10:18 10:30 10:50 11:10 12:00 14:45 18:05 Depart Anchorage for Kenai. Arrive at Rediske Air for charter flight Take off for Forest Oil Arrive at Forest Oil airstrip Check into camp. Go to well site, meet with company man. Safety huddle prior to lease inspection Inspect lease and plan equipment layout. Review rig up plans with tool pusher Return to camp, waiting for barge. Arrive on lease Hold Safety Meeting. 1st. Truck arrives, Safety Huddle prior to unloading truck. Began spotting equipment: Flare stack base, propane, transformer house and Generator. 2nd. Truck arrives, continue spotting equipment, flare support box, 1st. Flare anchor, Flare Stack. Mount Flare Stack to Base. 3rd. Truck arrives on lease. Spot heater, notice heater door broken. Spot SSV. Spot flare anchors 2 & 3. Spot Choke house, notice door broken. Spot separator. Spot air compressor. Spot pipe boxes & begin rig up. 4th. (last truck) arrives, finish unloading equipment, continue rig up Mount flare tip & pilot, and test pilot, OK. Raise flare stack. Safety huddle prior to pressure testing. ( ( Page 1 DATE 25-Nov-04 26-Nov-04 COMPANY: FIELD: LEASE: WELL#: S. O. #: Forest Oil West Foreland WF#2 (WF#1-9200/WF #2-8500) West Foreland #2 PWS-AK-0011 SEQUENCE OF OPERATIONS PøwerJ\'!l@{JJ SERVICES 1]"1; 18:15 18:20 18:45 22:40 22:50 Mike Joiner 23:00 George Bryce 5:30 6:00 6:50 6:56 7:00 7:30 8:15 9:00 10:00 10:30 11:00 11 :22 11:26 11 :42 11 :48 11:54 11 :58 12:20 12:25 13:20 13:25 14: 1 0 14:45 14:48 Total hrs: 60 Flush lines to tank. Beøan low pressure test (400psi). Begin high pressure test, finding leaks, changing seal rings and re-testing. Pressure test to 5000 psi. Pressure test good, bleed pressure off, blow lines clear. Stand down for the night. Depart camp for lease. Attend pre-perforating safety meeting. Drop Bar. Indication Guns fired. Initial tank strap==4"= 43.7 bbls. No flow/pressure, very slight blow at needle valve on Choke Manifold. Open well to tank on 10/64 and monitor. Continue to flow to tank - Very weak blow in bubble bucket Continue to flow to tank - Very weak blow in bubble bucket Rig up to swab Jim Wilkin and Ronnie Hinde arrive on location. Hold safety meeting Run in hole for 1st swab Tag fluid at 725' pull 200' swab Run in hole for 2nd swab Tag fluid at 686' pull 1 00' swab Run in hole for 3rd swab Tag fluid at 645' pull 200' swab Run in hole for 4th swab Tag fluid at 588' pull 200' swab Run in hole for 5th swab Tag fluid at 480' pull 200' swab Run in hole for 6th swab. Unable to establish fluid level. Run in hole for 7th swab Tag fluid at 380' pull 200' swab ( ( r"="' Page 2 COMPANY: FIELD: LEASE: WELL#: S. O. #: DATE 26-Nov-04 TIME 14:53 14:57 15:05 15:09 16:52 16:53 16:58 17:01 17:08 17:16 17:24 17:33 17:55 18:00 18:30 18:45 18:50 19:00 19:05 19:15 19:30 20: 00 20:15 20:40 20:50 21 :05 21 :40 22:00 23:00 Forest Oil West Foreland WF#2 (WF#1-9200IWF #2-8500) West Foreland #2 PWS-AK-0011 STECREW.O.N SITE Mike Joiner George Bryce Jim Wilkin Ronnie Hinde Total hrs: 112 SEQUENCE OF OPERATIONS Pøwer~ SERVICES '. .OPERATIONSPERFORMED Run in hole for 8th swab Tag fluid at 371' pull 300' swab Run in hole for 9th swab Tag fluid at 376' pull 300' swab. Still no returns in tank. Close wing valve on tree Run in hole, swab to trip tank recover 1 bbl Open wing valve flow to tank, weak blow Close wing vale, run in hole to swab to trip tank, recover 3 bbl. Open wing valve flow to tank, weak blow Close wing vale, run in hole to swab to trip tank, recover .25 bbl. Swab to 775', recover 2.3 bbl in trip tank. Open wing valve flow to tank, weak blow Close wing, RIH W/L, tag fluid @ 530', pull from 900', recovered 1,4 bbls. Shift change, Safety meeting, monitor well Close wing, RIH W/L, tag fluid @ 659', pull from 1059', recovered 1,2 bbls. Open wing to Choke manifold, no blow. Close wing, RIH W/L, tag fluid @ 867', pull from 1267', recovered 1.4 bbls. RIH W/L, tag fluid @ 1043', pull from 1443', recovered 1 bbl. RIH W/L, tag fluid @ 1217', pull from 1617', recovered 0.6 bbl. Open wing valve to Choke Manifold, no blow Monitor well at Choke Manifold, no blow. "0" psi, very slight blow. Close wing, RIH with W/L, tag fluid @ 963', pull from 1463', recover 1.4 bbl. RIH, tag fluid @ 1162', pull from 1662', recover 1.5 bbls. RIH, tag fluid @ 1368" pull from 1868', recover 1.4 bbls. RIH, tag fluid @ 1504', pull from 1904', recover 0.75 bbls. RIH, tag fluid @ 1340' pull from 1740', recover 1.5 bbls. Open wing valve to Choke Manifold, no blow, monitor well, W/L rig down. 18.75 bbls recovered during swabbing operations. Monitor well at Choke Manifold, very slight blow, no pressure. ( ( I"'""='r""~'i Page 3 COMPANY: FIELD: LEASE: WELL#: S. O. #: DATE 27 -Nov-04 TIME 0:00 1:00 2:00 3:00 4:00 5:00 6:00 6:30 7:20 8:00 9:00 9:15 9:27 9:40 9:51 10:00 10:56 11:10 11 :22 11 :36 12:00 12:20 13:00 13:18 13:30 13:43 14:00 14:42 15:00 15:12 Forest Oil West Foreland WF#2 (WF#1-9200/WF #2-8500) West Foreland #2 PWS-AK-0011 $1"ECREVVQNSll1; SEQUENCE OF OPERATIONS PøwerY1/@{]J SERVICES Monitor well at Choke Manifold, very slight blow, no pressure. Monitor well at Choke manifold, very slight blow, no pressure. Monitor well at Choke manifold, very slight blow, no pressure. Monitor well at Choke manifold, very slight blow, no pressure. Monitor well at Choke manifold, very slight blow, no pressure. Monitor well at Choke manifold, very slight blow, no pressure. Shift change, Safety meeting, monitor well Rig up to swab RIH, tag fluid @ 200' pull from 600', recover 1.2 bbls. Monitor well at Choke manifold, very slight blow, no pressure. Monitor well at Choke manifold, very slight blow, no pressure. RIH, tag fluid @ 285' pull from 685', recover 1.0 bbls. RIH, tag fluid @ 520' pull from 920', recover 1.5 bbls. RIH, tag fluid @ 743' pull from 1143', recover 1.75 bbls. RIH, tag fluid @ 950' pull from 1350', recover 1.0 bbls. Monitor well at Choke manifold, very slight blow, no pressure. RIH, tag fluid @ 815' pull from 1215', recover 1.0 bbls. RIH, tag fluid @ 1000' pull from 1400', recover 1.0 bbls. RIH, tag fluid @ 1150' pull from 1550', recover 1.0 bbls. RIH, tag fluid @ 1275' pull from 1675', recover 1.0 bbls. Monitor well at Choke manifold, very slight blow, no pressure. RIH, tag fluid @ 1345' pull from 1745', recover 1.2 bbls. Monitor well at Choke manifold, very slight blow, no pressure. RIH, tag fluid @ 1130' pull from 1153', recover 1.0 bbls. RIH, tag fluid @ 1290' pull from 1690', recover 1.5 bbls. RIH, tag fluid @ 1430' pull from 1830', recover .75 bbls. RIH, tag fluid @ 1525' pull from 1925', recover .75 bbls. RIH, tag fluid @ 1360' pull from 1660', recover .5 bbls. RIH, tag fluid @ 1400' pull from 1800', recover 1.0 bbls. RIH, tag fluid @ 1470' pull from 1870', recover .75 bbls. ( ( rr Page 4 COMPANY: FIELD: LEASE: WELL#: S. O. #: Forest Oil West Foreland WF#2 (WF#1-9200/WF #2-8500) West Foreland #2 PWS-AK-0011 SEQUENCE OF OPERATIONS Pøwer~ SERVICES DATE TIM.E 27 -Nov-04 16:00 17:00 Mike Joiner 18:00 George Bryce 18:30 Jim Wilkin 19:00 Ronnie Hinde Total hrs: 164 28-Nov-04 6:00 6:30 Mike Joiner 10:30 George Bryce 13:00 Jim Wilkin 14:30 Ronnie Hinde Total hrs: 212 29-Nov-04 7:30 8:00 10:00 13:00 Mike Joiner 14:00 George Bryce 16:00 Jim Wilkin 17:30 Ronnie Hinde Total hrs: 260 30-Nov-04 7:20 9:00 9:10 Mike Joiner 9:55 George Bryce 17: 30 Jim Wilkin Ronnie Hinde Total hrs: 308 1-Dec-04 6:00 7:30 Mike Joiner 12:00 George Bryce 14:00 Jim Wilkin 14:55 Ronnie Hinde Total hrs: 356 2-Dec-04 6:00 Mike Joiner 12:00 George Bryce Rig down wireline and pipe back to choke, DSA in Choke House. Rigged back to heater, move choke house and SSV. Shift change, Safety meeting, continue rig down. Day shift recovered 17.9 bbls swabbing for a total of 36.65 bbls recovered. Peak Super sucker vac water from heater. Shift change, Safety meeting, continue rig down. Put 5 gals anti freeze in heater bath. Crew depart location for Kenai. Call Anchorage office for instructions Check into hotel. Call rig for update Contact Anchorage manager, inform him to contact Forest Oil. Receive call from Anchorage to return to rig. Crew arrives at Rediske air field Receive helicopter safety briefing No flights due to adverse weather conditions. Crew check into hotel for night. Arrive at Rediske Air for charter flight Receive safety briefing from fixed wing pilot George Bryce departs Rediske for location. George Bryce reports to company man at well site. Messrs. Joiner, Wilkin and Hinde still in Kenai. Weather denied them the opportunity to fly. Try again tomorrow. George Bryce standing by in camp. Remainder of crew report to Rediske air field. Waiting for a break in the weather. Receive safety briefing from fixed wing pilot Messrs. Joiner, Wilkin and Hinde arrive at camp. Safety meeting held in camp. Informed by company man that we will rig our gear back prior to rig move. Page 5 (" ( DATE 2-Dec-04 3-Dec-04 4-Dec-04 5-Dec-04 6-Dec-04 7 -Dec-04 COMPANY: FIELD: LEASE: WELL#: S. O. #: TIME 13:00 5:50 6:05 6:55 7:10 8:15 8:45 10:05 11:10 11 :55 12:45 14:45 15:20 6:00 6:00 9:30 9:35 10:15 11 :00 6:00 6:00 Forest Oil West Foreland WF#2 (WF#1-9200/WF #2-8500) West Foreland #2 PWS-AK-0011 . 5TE CREW ON SITE Jim Wilkin Ronnie Hinde Total hrs: 404 Mike Joiner George Bryce Jim Wilkin Ronnie Hinde Mike Joiner George Bryce Jim Wilkin Ronnie Hinde Total hrs: 452 Total hrs:500 Mike Joiner George Bryce Jim Wilkin Ronnie Hinde Mike Joiner George Bryce Jim Wilkin Ronnie Hinde Mike Joiner George Bryce Jim Wilkin Total hrs: 548 Total hrs: 596 SEQUENCE OF OPERATIONS Pøwer!Ä'!l@l}J SERVICES ºP~~1"IC)"'$·.·.·.P~~FfC)ø.MF;[) Stand by waiting for call from rig tool pusher. Arrive at lease, hold safety meeting Begin breaking out pipe. Test ignition system, OK Safety huddle prior to loading pipe on trays. Truck arrives to move separator, safety huddle with driver Separator moved to edge of pad Safety huddle prior moving heater Work on ESD system. Break for lunch Continue working on ESD system, OK Blow air through all polyflo hoses to ensure no blockage. Report to company man and return to camp Safety meeting held in camp. Stand by in camp waiting for rig to move. Stand by in camp waiting for rig to move. Stand by in camp waiting for rig to move. Safety meeting held in camp. Go to lease. Check oil in generator. Check ignition system, OK Return to camp, stand by. Safety meeting held in camp. Stand by in camp waiting for rig to move. Stand by in camp waiting for rig to move. Stand by in camp waiting for rig to move. Safety meeting held in camp. Stand by in camp waiting for rig to move. Stand by in camp waiting for rig to move. ( ( ~-r-l Page 6 COMPANY: FIELD: LEASE: WELL#: S. O. #: Forest Oil West Foreland WF#2 (WF#1-9200IWF #2-8500) West Foreland #2 PWS-AK-0011 SEQUENCE OF OPERATIONS Pøwer~ SERVICES Ronnie Hinde Total hrs: 644 DATE 7-Dec-04 8-Dec-04 TIM!: 9-Dec-04 6:00 15:00 Mike Joiner 15: 15 George Bryce 17:00 Jim Wilkin 17:30 Ronnie Hinde 6:00 10:30 Mike Joiner 11 : 00 George Bryce 11 :30 Jim Wilkin 13:00 Ronnie Hinde 6:00 7:15 7:35 8:00 8:15 10:00 11 :00 11 : 30 12:00 12:30 13:30 14:10 14:30 15:00 15:30 15:55 18:00 18:30 19:30 Total hrs: 740 Total hrs: 692 10-Dec-04 Stand by in camp waiting for rig to move. Safety meeting held in camp. Go to lease. Check oil in generator. Check ignition system, OK Return to camp, stand by. Safety meeting held in camp. Go to lease. Check oil in generator. Check ignition system, OK Return to camp, stand by. Safety meeting held in camp. Called to lease, ready to rig up Arrive at lease, review safety meeting and JSA Safety huddle with forklift driver Begin to rig up to long string connection Choke manifold rigged in. Choke to heater rigged up M. Joiner & R. Hinde return to camp to rest before nightshift. Raise heater chimney Run propane line, test ignition system, OK Clean elbows and pipe. Safety huddle before filling heater bath Fire up heater. Inspect and zero adjustable choke. Hook up air dryer and supply hose. Winch truck arrives to spot separator, safety huddle with driver Crew change and safety meeting Heater to Separator rigged up. Roustabouts build berm for Separator. Rig up Separator fluid outlet & by-pass to tank. ( ( -<'1'- Page 7 COMPANY: FIELD: LEASE: WELL#: S. O. #: Forest Oil West Foreland WF#2 (WF#1-9200IWF #2-8500) West Foreland #2 PWS-AK-0011 SEQUENCE OF OPERATIONS Pøwer~ SERVICES 10-Dec-04 20:15 21 :30 Mike Joiner 22:30 George Bryce 23:00 Jim Wilkin 23:30 Ronnie Hinde 11-Dec-04 0:35 1 :15 2:18 3:05 4:00 5:30 5:50 6:00 6:20 6:50 7:18 7:25 7:30 7:40 7:50 8:00 8:20 8:40 9:00 9:40 12:00 13:00 Total hrs: 792 Tank strap missing from lab Wireline commence swabbing operation on long string. Swab run #1, Tag fluid @? Ft, pull from 6070'. Rig up H.P. gas line & relief line to flare stack. Rig up ESD system. Swab run #2, Tag fluid @5600 ft, pull from 6350 ft, recovered 3 bbls. Swab run #3, Tag fluid @5600 ft, pull from 6200 ft. recovered "0" bbls. Change swab cups. Swab run #4, tag fluid @5600 ft, pull from 6200 ft, recovered "O"bbls. Swab run #5, tag fluid @5910 ft, pull from 6650 ft, recovered 7 bbls. New cups. Swab run #6, tag fluid @6365 ft, pull from 7300 ft, recovered "0" bbls. Swab run #7, tag fluid @6345 ft, pull from 7000 ft. Total long string - 10 barrels Swab run #8 Wireline having problems. Crew change and safety meeting Wireline pull out of hole. Wireline out of hole, rig up to swab short string. Run in hole on short string for Swab Run #1 Swab run #1, Tag fluid 80', pull from 320'. Swab run #2, Tag fluid ?', pull from 320'. Swab run #3, Tag fluid 120", pull from 600'. Swab run #4, Tag fluid 390", pull from 900'. Swab run #5, Tag fluid 620", pull from 1250'. Total recovery 5 bbl. Swab run #6, Tag fluid 890", pull from 1500'. Swab run #7, Tag fluid 1400", pull from 2050'. Swab run #8, Tag fluid 1725', pull from 2450'. Swab run #9, Tag fluid 1770', pull from 2350'. Total recovery 9 bbl. Check generator, add one quart of oil. Swab run #10, Tag fluid 2200', pull from 3400'. ( ( ... - c n ::2 Page 8 :c r COMPANY: FIELD: LEASE: WELL#: S. O. #: Forest Oil West Foreland WF#2 (WF#1-9200/WF #2-8500) West Foreland #2 PWS-AK-0011 SEQUENCE OF OPERATIONS Pøwer~ SERVICES OÄTE 11-Dec-04 12-Dec-04 tiME 13:30 14:15 15:00 15:40 16:20 17:10 18:00 18:40 20:00 21 :00 22:00 Mike Joiner 22:30 George Bryce 23:45 Jim Wilkin 23:48 Ronnie Hinde 0:10 0:25 1:00 2:15 2:25 2:53 3:00 4:10 5:20 5:30 5:35 6:00 6:30 7:52 8:00 8:30 Total hrs: 844 Swab run #11, Tag fluid 2900', pull from 4200'. Total fluid recovery 15 bbl. Swab run #12, Tag fluid 3350', pull from 4350' Total fluid recovery 17 bbl. Swab run #13, Tag fluid 3350', pull from 4350' Total fluid recovery 18 bbl. Swab run #14, Tag fluid 4750', pull from 5750' Total fluid recovery 19 bbl. Swab run #15, Tag fluid 5100', pull from 6200' Total fluid recovery 22 bbl. Swab run #16, Tag fluid 5125', pull from 6125' Total fluid recovery 26 bbl. Crew change and safety meeting Swab run #17, Tag fluid 5980' pull from 7200' Total fluid recovery 29 bbl. Swab run #18, Tag fluid 6550' pull from 7300', Total fluid recovered 30.25 bbl. Swab run #19, tag fluid 7050', pull from 7750', Total fluid from short string - 30.25 bbl. Wireline rig down. Total fluid recovered from short/long strings. 40.25 barrels BJ nitrogen rig up. Safety huddle prior to dropping bar. Drop bar to peñorate long string. Guns fired. Open well to tank on 12/64 adj. (Plugging on 10/64) Shut well in to peñorate short string with N2. BJ start pumping, will pressure up to 4500 psi to peñorate. Guns fired on short string. BJ rig down. Bled pressure to 2409 psi. Open well to choke manifold to separator and flare. (long string) Place 2.25 orifice plate in line. Gas gravity= 0.600, CL= 28,000 ppm. Continue to flow well Crew change and safety meeting Increase choke to 12/64ths Ice plug in line between choke and heater. Open well (long string) on 12/64 adjustable choke Flowing well thru separator to flare Flowing well thru separator to flare ( ( -ï! Page 9 - SEQUENCE OF OPERATIONS COMPANY: FIELD: LEASE: WELL#: S. O. #: Forest Oil West Foreland WF#2 (WF#1-9200IWF #2-8500) West Foreland #2 PWS-AK-0011 Pøwer!A'!/@fJJ SERVICES 12-Dec-04 9:00 Flowing well thru separator to flare 9:30 Gas gravity= 0.598 10:00 Flowing well thru separator to flare ( 10:30 Flowing well thru separator to flare 11 : 00 Increase choke to 14/64ths 11 :30 Flowing well thru separator to flare 12:00 Flowing well thru separator to flare 12:30 Flowing well thru separator to flare 13:00 Flowing well thru separator to flare 13:30 Flowing well thru separator to flare 14:00 Increase choke to 16/64ths 14:30 Gas gravity = .596 15:00 Flowing well thru separator to flare 15:30 Flowing well thru separator to flare 16:00 Flowing well thru separator to flare 16:30 Flowing well thru separator to flare 17:00 Increase choke to 18/64ths 17:30 Gas gravity .595 co2 0.3% 18:00 Crew change and safety meeting ( Flowing well thru separator to flare 18:30 Flowing well thru separator to flare 19:00 Took 1-1000cc gas samples, Whitey bottle # W-2863 Took 1-300cc gas samples, Whitey bottle # EKO-79. 19:30 Flowing well thru separator to flare 20:00 Mike Joiner Shut well in for 12 hr. build up. 21 :00 George Bryce Monitor well build up. 22:00 Jim Wilkin Monitor well build up. 23:00 Ronnie Hinde Total hrs: 896 Monitor well build up. 13-Dec-04 0:00 Monitor well build up. --r 1:00 Monitor well build up. I-¡- Page 10 COMPANY: FIELD: LEASE: WELL#: S. O. #: Forest Oil West Foreland WF#2 (WF#1-9200IWF #2-8500) West Foreland #2 PWS-AK-0011 '" SEQUENCE OF OPERATIONS Pøwer~ SERVICES 13-Dec-04 2:00 3:00 4:00 5:00 5:45 6:00 7:00 7:15 10:08 10: 15 10:25 10:30 10:45 11 : 00 11 :30 12:00 12:30 13:00 13:10 13:30 14: 00 14:30 15:00 15:30 16:00 16:30 17:00 17:30 Mike Joiner George Bryce Jim Wilkin Ronnie Hinde Monitor well build up. Monitor well build up. Monitor well build up. Monitor well build up. Spider gauge ceased to function, inform FOC company man. Crew change and safety meeting Shut in master valve test complete Rig left location without returning hammer wrenches Rig down from long string, connect to short string. See "FOC short string.xls" for next test. Open well on 10/64 adj. choke to separator and flare. (short string) Gas at surface Liquid at surface. Initial tank strap 15.25" Increase choke to 12/64, choke plugging. Flowing gas only. Continue to flow well. Continue to flow well. Begin step rate test gas gravity .594 CO2 = 0.5% Rock choke, suspect debris causing blockage. Continue to flow well. Spider gauge operational, record pressures from Spider. Continue to flow well. Increase choke to 14/64 No change in tank level. 3 bbls increase in tank level. (63 bbls). Continue to flow well. Gas. gravity .582 Continue to flow well. ( ( --r rr Page 11 :;r.::: r- SEQUENCE OF OPERATIONS COMPANY: FIELD: LEASE: WELL#: S. O. #: Forest Oil West Foreland WF#2 (WF#1-9200/WF #2-8500) West Foreland #2 PWS-AK-0011 PøwerJ\!lii!J SERVICES 13-Dec-04 17:45 Crew change and safety meeting 18:00 Increase choke to 16/64. 3 bbls increase in tank level (66 bbls). 18:30 Bled casing to 478 psi. 20:00 Total hours from previous 896 Continue to flow well. 21 :00 Mike Joiner Increase choke to 18/64. 22:00 Ronnie Hinde Continue to flow well. Gas gravity = .594, CO2 = 0.3 0/0. 23:00 Jim Wilkin Took 1- 500cc gas sample, bottle # W-2863, 1- 300cc gas sample, George Bryce Total hrs: 948 bottle # 2EK088 14-Dec-04 0:00 Shut well in for build up. 0:30 Monitor well build up, blow lines & separator down to tank. 1:00 Monitor well build up. 1:15 Safety huddle prior to rig down 1:30 Monitor well build up. Began rig flare & vent line down. 2:00 Monitor well build up. Disconnect ESD system. 2:30 Monitor well build up. 3:00 Monitor well build up. 3:30 Monitor well build up. 4:00 Monitor well build up. 4:30 Monitor well build up. ( 5:00 Monitor well build up. 5:30 Monitor well build up. 6:00 Crew change and safety meeting 7:00 End of build up 7:15 Mike Joiner Continue with rig down and load out. 9:00 Ronnie Hinde Discover damaged tool box on diverter manifold, inform company man. 18:00 Jim Wilkin Crew change and safety meeting 22:30 George Bryce Total hrs: 1000 Last trailer loaded 15-Dec-04 6:00 Mike Joiner Safety meeting in camp 9:30 Ronnie Hinde Depart camp for air strip 10:15 Jim Wilkin Arrive at Rediske Air Field. ¡--'1t"- . i Page 12 15-Dec-04 16-Dec-04 17 -Dec-04 COMPANY: FIELD: LEASE: WELL#: S. O. #: Forest Oil West Foreland WF#2 (WF#1-9200IWF #2-8500) West Foreland #2 PWS-AK-0011 SEQUENCE OF OPERATIONS Pøwer!A'!/@{JJ SERVICES 11 :00 6:45 7:00 11 :30 16:30 7:00 9:00 10:00 11 :30 11 :40 12:00 16:00 16:05 17:40 18:15 George Bryce Mike Joiner Ronnie Hinde George Bryce Mike Joiner Ronnie Hinde George Bryce Arrive at hotel. Telephone Weaver Bros for update on equipment arrival Safety meeting with crew in hotel. Telephone Weaver Bros, equipment will arrive 16:30 hours Arrive Weaver Bros. Informed separator will not arrive until tomorrow am. Safety meeting with crew in hotel. Arrive at Weaver Bros. Collect items required for cleaning separator. Arrive at R&K facility. Separator arrives at R&K. Safety huddle prior to standing separator. Begin rigging up for cleaning. Safety huddle prior to pressure testing. Begin filling vessel. Pressure test complete Separator ready for transport, depart R&K. ( ( -"~r c:: rT Page 13 "--./ West Foreland #2 (WF#2-8500'MD) Perforations: 8,494-8,529 MD IP*(surface) 2982.997 PSIA 12/13/2004 Final Rate 9991.69 MSCF/D Cum 3986 MSCF T 9.57435629 Hours Delta T Homer Plot Homer MM/DDIYYY y Hours Tubing PSIA Casing PSIA (dT) Time Sqrt (dT) d Pressure Homer Derivative (T +dT)/(dT) Time (PSi/Cycle) 12/1312004 23:00:00 9.7667 2258.054 656.924 12/1312004 23:00:30 9.7750 2260.943 657.000 12/1312004 23:01 :00 9.7833 2267.875 657.296 12/13/2004 23:01 :30 9.7917 2272.398 657.640 12/1312004 23:02:00 9.8000 2275.415 657.980 12/13/2004 23:02:30 9.8083 2273.420 658.191 12/13/2004 23:03:00 9.8167 2267.448 658.390 12/13/2004 23:03:30 9.8250 2270.250 658.558 12/13/2004 23:04:00 9.8333 2274.080 658.845 12/13/2004 23:04:30 9.8417 2271.583 659.086 12/13/2004 23:05:00 9.8500 2267.048 659.218 12/1312004 23:05:30 9.8583 2269.232 659.406 12/13/2004 23:06:00 9.8667 2269.280 659.657 12/1312004 23:06:30 9.8750 2269.127 659.850 12/1312004 23:07:00 9.8833 2269.497 660.089 12/13/2004 23:07:30 9.8917 2271.472 660.330 12/13/2004 23:08:00 9.9000 2264.976 660.622 12/13/2004 23:08:30 9.9083 2259.155 660.639 12/13/2004 23:09:00 9.9167 2263.937 660.842 12/1312004 23:09:30 9.9250 2261.716 661.029 12/13/2004 23: 1 0:00 9.9333 2267.916 661.305 12/13/2004 23:10:30 9.9417 2263.458 661.522 12/1312004 23:11:00 9.9500 2267.577 661.777 12/13/2004 23:11:30 9.9583 2264.074 662.031 12/13/2004 23:12:00 9.9667 2269.077 662.255 12/1312004 23:12:30 9.9750 2261.596 662.449 12/13/2004 23: 13:00 9.9833 2269.807 662.616 12/1312004 23: 13:30 9.9917 2269.208 662.956 12/13/2004 23:14:00 10.0000 2271.916 663.170 12/13/2004 23:14:30 10.0083 2269.758 663.401 12/13/2004 23:15:00 10.0167 2263.546 663.577 12/13/2004 23: 15:30 10.0250 2263.681 663.704 12/13/2004 23:16:00 10.0333 2260.952 663.888 12/13/2004 23:16:30 10.0417 2263.869 664.100 12/1312004 23:17:00 10.0500 2269.202 664.408 12/13/2004 23:17:30 10.0583 2272.564 664.735 12/1312004 23: 18:00 10.0667 2276.682 665.008 12/13/2004 23:18:30 10.0750 2268.372 665.192 12/13/2004 23:19:00 10.0833 2264.748 665.293 12/13/2004 23:19:30 10.0917 2259.311 665.410 " 12/13/2004 23:20:00 10.1000 2261.016 665.535 12/13/2004 23:20:30 10.1083 2264.542 665.771 12/13/2004 23:21:00 10.1167 2267.056 666.036 12/13/2004 23:21 :30 10.1250 2268.890 666.326 12/13/2004 23:22:00 10.1333 2270.738 666.567 12/13/2004 23:22:30 10.1417 2276.384 666.901 12/13/2004 23:23:00 10.1500 2276.823 667.204 12/13/2004 23:23:30 10.1583 2269.788 667.272 12/13/2004 23:24:00 10.1667 2267.468 667.412 12/13/2004 23:24:30 10.1750 2265.294 667.561 12/13/2004 23:25:00 10.1833 2259.778 667.655 12/13/2004 23:25:30 10.1917 2256.412 667.727 12/13/2004 23:26:00 10.2000 2255.294 667.909 12/13/2004 23:26:30 10.2083 2255.625 668.114 12/13/2004 23:27:00 10.2167 2254.563 668.292 12/13/2004 23:27:30 10.2250 2257.300 668.521 12/13/2004 23:28:00 10.2333 2256.111 668.680 12/13/2004 23:28:30 10.2417 2258.398 668.942 "--- '-"" West Foreland #2 (WF#2-8500'MD) Peñorations: 8,494-8,529 MO IP*(suñace) 2982.997 PSIA 12/1312004 Final Rate 9991.69 MSCF/D Cum 3986 MSCF T 9.57435629 Hours Delta T Homer Plot Homer MM/DDNYY y Hours Tubing PSIA Casing PSIA (dT) Time Sqrt (dT) d Pressure Homer Derivative (T +dT)/(dT) Time (PSilCyde) 12/1312004 23:29:00 10.2500 2261.276 669.256 12/13/2004 23:29:30 10.2583 2257.367 669.408 12/13/2004 23:30:00 10.2667 2260.264 669.648 12/13/2004 23:30:30 10.2750 2257.420 669.807 12/1312004 23:31:00 10.2833 2264.896 670.074 12/13/2004 23:31:30 10.2917 2262.017 670.342 12113/2004 23:32:00 10.3000 2264.339 670.543 12/13/2004 23:32:30 10.3083 2272.137 670.852 12/13/2004 23:33:00 10.3167 2270.956 671.122 12/13/2004 23:33:30 10.3250 2270.112 671.311 12/1312004 23:34:00 10.3333 2265.563 671.414 12/13/2004 23:34:30 10.3417 2265.561 671.603 12/1312004 23:35:00 10.3500 2270.335 671.823 12/1312004 23:35:30 10.3583 2269.415 672.077 12/13/2004 23:36:00 10.3667 2267.869 672.249 12/1312004 23:36:30 10.3750 2268.547 672.441 12/13/2004 23:37:00 10.3833 2267.322 672.647 12/1312004 23:37:30 10.3917 2265.696 672.829 12/13/2004 23:38:00 10.4000 2272.049 673.036 12/1312004 23:38:30 10.4083 2265.081 673.234 12/1312004 23:39:00 10.4167 2264.660 673.379 12/13/2004 23:39:30 10.4250 2265.425 673.500 12/13/2004 23:40:00 10.4333 2271.201 673.799 12/13/2004 23:40:30 10.4417 2273.019 674.075 12/13/2004 23:41 :00 10.4500 2273.635 674.351 12/13/2004 23:41 :30 10.4583 2278.771 674.575 12/13/2004 23:42:00 10.4667 2278.549 674.880 12/13/2004 23:42:30 10.4750 2281.511 675.101 12/13/2004 23:43:00 10.4833 2277.521 675.307 12/13/2004 23:43:30 10.4917 2275.390 675.393 12/1312004 23:44:00 10.5000 2275.072 675.524 12/13/2004 23:44:30 10.5083 2279.071 675.773 12/13/2004 23:45:00 10.5167 2278.235 676.001 12/13/2004 23:45:30 10.5250 2277.781 676.171 12/13/2004 23:46:00 10.5333 2279.784 676.361 12/13/2004 23:46:30 10.5417 2268.517 676.401 12/13/2004 23:47:00 10.5500 2265.541 676.433 12/13/2004 23:47:30 10.5583 2263.321 676.573 12/13/2004 23:48:00 10.5667 2271.079 676.806 12/13/2004 23:48:30 10.5750 2266.196 676.959 12/13/2004 23:49:00 10.5833 2273.689 677.258 12/13/2004 23:49:30 10.5917 2267.312 677.453 12/13/2004 23:50:00 10.6000 2268.644 677.608 12/13/2004 23:50:30 10.6083 2270.754 677.765 12/13/2004 23:51:00 10.6167 2282.442 678.146 12/13/2004 23:51:30 10.6250 2269.818 678.271 12/13/2004 23:52:00 10.6333 2271.545 678.385 12/13/2004 23:52:30 10.6417 2267.819 678.532 12/13/2004 23:53:00 10.6500 2264.666 678.694 12/13/2004 23:53:30 10.6583 2277.336 678.920 12/13/2004 23:54:00 10.6667 2276.616 679.249 12/13/2004 23:54:30 10.6750 2269.142 679.313 12/13/2004 23:55:00 10.6833 2277.627 679.556 12/13/2004 23:55:30 10.6917 2278.891 679.856 12/13/2004 23:56:00 10.7000 2280.558 680.070 12/13/2004 23:56:30 10.7083 2273.042 680.244 12/13/2004 23:57:00 10.7167 2275.781 680.332 12/13/2004 23:57:30 10.7250 2268.861 680.471 ~ West Foreland #2 (WF#2-8500'MD) Perforations: 8,494-8,529 MD IP*(surface) 2982.997 PSIA 12/13/2004 Final Rate 9991.69 MSCFID Cum 3986 MSCF T 9.57435629 Hours Delta T Homer Plot Homer MMlDDIYYY y Hours Tubing PSIA Casing PSIA (dT) Time Sqrt (dT) d Pressure Homer Deñvative (T +dT)/(dT) Time (PSi/Cycle) 12/13/2004 23:58:00 10.7333 2273.772 680.632 12/13/2004 23:58:30 10.7417 2275.298 680.829 12/1312004 23:59:00 10.7500 2284.401 681.196 12/1312004 23:59:30 10.7583 2269.999 681.244 12/14/2004 0:00:00 10.7667 2268.030 681.301 12/14/2004 0:00:05 10.7681 2269.596 681.342 12/1412004 0:00:10 10.7694 2265.712 681.338 12/1412004 0:00:15 10.7708 2393.766 681.763 0.00139 6893.9851 0.0373 128.054 12/1412004 0:00:20 10.7722 2526.396 683.183 0.00278 3447.4925 0.0527 260.684 4875 440.680 12/14/2004 0:00:25 10.7736 2606.824 684.714 0.00417 2298.6617 0.0646 341.112 2815 456.904 12/1412004 0:00:30 10.7750 2671.867 686.487 0.00556 1724.2463 0.0745 406.155 1991 520.862 12/14/2004 0:00:35 10.7764 2726.873 687.935 0.00694 1379.597 0.0833 461.161 1542 567.968 12/14/2004 0:00:40 10.7778 2774.069 689.285 0.00833 1149.8308 0.0913 508.357 1259 596.525 12/14/2004 0:00:45 10.7792 2814.496 690.844 0.00972 985.71216 0.0986 548.784 1065 604.436 12/14/2004 0:PO:50 10.7806 2848.549 691.950 0.01111 862.62314 0.1054 582.837 922 587.840 12/1412004 0:00:55 10.7819 2876.647 692.966 0.01250 766.9485 0.1118 610.935 813 550.349 12/14/2004 0:01 :00 10.7833 2899.384 694.034 0.01389 690.34814 0.1179 633.672 728 497.549 12/14/2004 0:01:05 10.7847 2917 .378 694.745 0.01528 627.67602 0.1236 651.666 658 435.346 12/14/2004 0:01:10 10.7861 2931.060 695.196 0.01667 575.44989 0.1291 665.348 601 362.648 12/14/2004 0:01 :25 10.7903 2953.284 696.188 0.02083 460.5544 0.1443 687.572 515 229.761 12/14/2004 0:01 :45 10.7958 2961.135 696.183 0.02639 363.81618 0.1624 695.423 409 76.671 12/14/2004 0:02:05 10.8014 2963.692 695.317 0.03195 300.71377 0.1787 697.980 331 30.908 12/14/2004 0:02:35 10.8097 2965.681 693.520 0.04028 238.70684 0.2007 699.969 268 19.833 12/1412004 0:03:15 10.8208 2967.630 690.715 0.05139 187.3114 0.2267 701.918 211 18.509 12/1412004 0:04:00 10.8333 2969.141 687.353 0.06389 150.85923 0.2528 703.429 168 16.076 12/14/2004 0:05:00 10.8500 2970.695 682.958 0.08056 119.85342 0.2838 704.983 134 15.552 12/14/2004 0:06:10 10.8694 2972.167 677.809 0.10000 96.743563 0.3162 706.455 108 15.823 12/14/2004 0:07:45 10.8958 2973.565 670.980 0.12639 76.753082 0.3555 707.853 86 13.907 12/1412004 0:09:45 10.9292 2974.914 662.552 0.15972 60.943504 0.3997 709.202 68 13.467 12/14/2004 0:12:10 10.9694 2976.111 652.684 0.20000 48.871781 0.4472 710.399 55 12.486 12/14/2004 0:15:15 11.0208 2977 .271 640.583 0.25139 39.08582 0.5014 711.559 44 11.954 12/14/2004 0:19:10 11.0861 2978.397 625.911 0.31667 31.234778 0.5627 712.685 35 11.563 12/14/2004 0:24:05 11.1681 2979.418 608.430 0.39861 25.019237 0.6314 713.706 28 10.595 12/14/2004 0:30:15 11.2708 2980.266 587.737 0.50139 20.095665 0.7081 714.554 22 8.910 12/14/2004 0:38:05 11.4014 2981.007 563.094 0.63195 16.150616 0.7949 715.295 18 7.807 12/14/2004 0:47:50 11.5639 2981.636 534.544 0.79445 13.051629 0.8913 715.924 15 6.798 12/14/2004 1:00:10 11.7694 2982.261 501.322 1.00000 10.574356 1.0000 716.549 12 6.837 12/14/2004 1:15:45 12.0292 2982.606 463.240 1.25972 8.6003663 1.1224 716.894 10 3.845 12/14/2004 1 :35:20 12.3556 2982.793 420.408 1.58611 7.0363684 1.2594 717.081 8 2.145 12/14/2004 1 :59:55 12.7653 2982.869 372.696 1.99583 5.7971707 1.4127 717.157 6 0.903 12/14/2004 2:08:35 12.9097 2982.997 357.180 2.14028 5.4734171 1.4630 717 .285 6 5.129 Edited Data Start Time Perforations Location : :12/1212004 2:47:00 10,371-10,383 MD WFU # 2 Data Units MM/DDNYY 1211212004 1211212004 1211212004 1211212004 12112/2004 12/1212004 12/12/2004 12/12/2004 1211212004 12/1212004 12112/2004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 12112/2004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 12112/2004 12/12/2004 1211212004 1211212004 12112/2004 12112/2004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 12112/2004 12/12/2004 12112/2004 12/12/2004 12112/2004 12/12/2004 12/12/2004 12112/2004 1211212004 12112/2004 1211212004 12/12/2004 12/12/2004 12/12/2004 12112/2004 12/12/2004 12112/2004 Clock Time Hours 2:48:00 2:49:00 2:50:00 2:51:00 2:52:00 2:53:00 2:54:00 2:55:00 2:56:00 2:57:00 2:58:00 2:59:00 3:00:00 3:01 :00 3:02:00 3:03:00 3:04:00 3:05:00 3:06:00 3:07:00 3:08:00 3:09:00 3:10:00 3: 11 :00 3: 12:00 3: 13:00 3:14:00 3:15:00 3: 16:00 3:17:00 3:18:00 3: 19:00 3:20:00 3:21:00 3:22:00 3:23:00 3:24:00 3:25:00 3:26:00 3:27:00 3:28:00 3:29:00 3:30:00 3:31:00 3:32:00 3:33:00 3:34:00 3:35:00 3:36:00 3:37:00 3:38:00 3:39:00 3:40:00 3:41:00 3:42:00 3:43:00 3:44:00 5.493 MMSCF/D 2.671 MMSCF 11.67 Hours Homer Time Tubing PSIA Casing PSIA Delta Time Delta Press (T + dT)/dT 13.854 13.957 2423.501 13.900 2423.111 13.882 2422.828 13.851 2422.679 13.824 2422.598 13.807 2422.465 13.779 2422.373 13.787 2422.254 13.799 2421.692 13.773 2422.064 13.774 2417.044 13.767 2398.678 13.741 2336.996 13.733 2228.191 13.730 2144.129 13.728 2076.323 13.715 2020.637 13.721 1976.683 13.751 1944.196 13.730 1920.145 13.711 1902.377 13.726 1888.373 11.426 1880.594 11.449 1872.484 11.439 1866.685 11.431 1859.817 11.422 1853.445 11.400 1847.408 11.395 1842.389 11.390 1839.172 11.401 1835.110 11.347 1831.429 11.365 1830.255 11.366 1829.494 11.376 1827.383 11.340 1826.070 11.341 1824.338 11.329 1820.869 11.325 1819.372 11.314 1817.881 11.300 1815.117 11.289 1814.223 11.312 1811.830 11.309 1808.602 11.281 1805.276 11.297 1802.715 11.271 1802.043 11.272 1801.610 11.269 1800.222 11.284 1796.628 11.275 1796.189 11.273 1794.197 11.243 1793.833 11.248 1794.506 11.256 1791.949 11.264 1792.577 11.249 0.017 0.033 0.050 0.067 0.083 0.100 0.117 0.133 0.150 0.167 0.183 0.200 0.217 0.233 0.250 0.267 0.283 0.300 0.317 0.333 0.350 0.367 0.383 0.400 0.417 0.433 0.450 0.467 0.483 0.500 0.517 0.533 0.550 0.567 0.583 0.600 0.617 0.633 0.650 0.667 0.683 0.700 0.717 0.733 0.750 0.767 0.783 0.800 0.817 0.833 0.850 0.867 0.883 0.900 0.917 0.933 0.950 Final Rate Cum Rec T Plot Homer Time Homer Slope (PSIICyde) ,-,' Edited Data Start Time :12/12/2004 2:47:00 Final Rate 5.493 MMSCF/D Perforations 10,371-10,383 MD Cum Ree 2.671 MMSCF location : WFU # 2 T 11.67 Hours Homer Plot Homer Data Units Clock Time Homer Slope MM/DDNYY Time Hours Tubing PSIA Casing PSIA Delta Time Delta Press (T + dT)/dT Time (PSI/Cycle) 12/1212004 3:45:00 0.967 1785.294 11.253 12/12/2004 3:46:00 0.983 1782.974 11.250 12/12/2004 3:47:00 1.000 1781.047 11.249 12/12/2004 3:48:00 1.017 1779.479 11.231 12/12/2004 3:49:00 1.033 1778.697 11.240 12/1212004 3:50:00 1.050 1780.693 11.222 12/1212004 3:51:00 1.067 1784.571 11.212 12/12/2004 3:52:00 1.083 1792.515 11.200 12/12/2004 3:53:00 1.100 1796.981 11.192 12/12/2004 3:54:00 1.117 1807.521 11.182 12/12/2004 3:55:00 1.133 1815.483 11.192 12/12/2004 3:56:00 1.150 1822.824 11.181 12/12/2004 3:57:00 1.167 1830.217 11.163 12/12/2004 3:58:00 1.183 1836.458 11.151 12/12/2004 3:59:00 1.200 1842.962 11.139 12/1212004 4:00:00 1.217 1848.781 11.142 12/12/2004 4:01 :00 1.233 1853.259 11.151 12/12/2004 4:02:00 1.250 1856.543 11.148 12/12/2004 4:03:00 1.267 1860.682 11.135 12/12/2004 4:04:00 1.283 1864.703 11.138 12/12/2004 4:05:00 1.300 1868.774 11.143 12/12/2004 4:06:00 1.317 1871.534 11.159 12/12/2004 4:07:00 1.333 1874.425 11.148 12/12/2004 4:08:00 1.350 1876.443 11.143 12/12/2004 4:09:00 1.367 1879.759 11.138 12/12/2004 4:10:00 1.383 1882.328 . 11.132 12/12/2004 4:11:00 1.400 1883.994 11.121 12/12/2004 4:12:00 1.417 1887.420 11.073 12/12/2004 4:13:00 1.433 1889.754 289.241 12/1212004 4:14:00 1.450 1891.813 290.177 12/12/2004 4:15:00 1.467 1892.618 291.048 12/12/2004 4:16:00 1.483 1893.646 291.850 12/12/2004 4:17:00 1.500 1895.223 292.666 12/12/2004 4:18:00 1.517 1897.107 293.522 12/12/2004 4:19:00 1.533 1898.050 294.349 12/12/2004 4:20:00 1.550 1900.051 295.193 12/12/2004 4:21 :00 1.567 1900.780 295.992 12/12/2004 4:22:00 1.583 1901.317 296.789 12/12/2004 4:23:00 1.600 1904.343 297.672 12/12/2004 4:24:00 1.617 1906.671 298.496 12/12/2004 4:25:00 1.633 1908.276 299.336 12/12/2004 4:26:00 1.650 1913.513 300.271 12/12/2004 4:27:00 1.667 1917.039 301.108 12/12/2004 4:28:00 1.683 1922.477 302.037 12/12/2004 4:29:00 1.700 1924.780 302.873 12/12/2004 4:30:00 1.717 1929.846 303.750 12/12/2004 4:31 :00 1.733 1931.751 304.562 12/12/2004 4:32:00 1.750 1936.236 305.394 12/12/2004 4:33:00 1.767 1937.049 306.148 12/12/2004 4:34:00 1.783 1936.709 306.806 12/12/2004 4:35:00 1.800 1934.096 307.441 12/12/2004 4:36:00 1.817 1932.685 308.124 12/12/2004 4:37:00 1.833 1934.226 308.791 12/12/2004 4:38:00 1.850 1936.203 309.544 12/12/2004 4:39:00 1.867 1939.594 310.328 12/12/2004 4:40:00 1.883 1942.391 311.160 12/12/2004 4:41 :00 1.900 1944.523 311.912 Edited Data Start Time Perforations Location : :12/12/2004 2:47:00 10,371-10,383 MD WFU # 2 Data Units MM/DDIYYY 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 Clock Time Hours 4:42:00 4:43:00 4:44:00 4:45:00 4:46:00 4:47:00 4:48:00 4:49:00 4:50:00 4:51:00 4:52:00 4:53:00 4:54:00 4:55:00 4:56:00 4:57:00 4:58:00 4:59:00 5:00:00 5:01 :00 5:02:00 5:03:00 5:04:00 5:05:00 5:06:00 5:07:00 5:08:00 5:09:00 5:10:00 5:11 :00 5:12:00 5: 13:00 5:14:00 5:15:00 5:16:00 5:17:00 5: 18:00 5: 19:00 5:20:00 5:21 :00 5:22:00 5:23:00 5:24:00 5:25:00 5:26:00 5:27:00 5:28:00 5:29:00 5:30:00 5:31 :00 5:32:00 5:33:00 5:34:00 5:35:00 5:36:00 5:37:00 5:38:00 ~ 5.493 MMSCF/D 2.671 MMSCF 11.67 Hours Horner Time Tubing PSIA Casing PSIA Delta Time Delta Press (T + dT)/dT 1.917 1.933 1.950 1.967 1.983 2.000 2.017 2.033 2.050 2.067 2.083 2.100 2.117 2.133 2.150 2.167 2.183 2.200 2.217 2.233 2.250 2.267 2.283 2.300 2.317 2.333 2.350 2.367 2.383 2.400 2.417 2.433 2.450 2.467 2.483 2.500 2.517 2.533 2.550 2.567 2.583 2.600 2.617 2.633 2.650 2.667 2.683 2.700 2.717 2.733 2.750 2.767 2.783 2.800 2.817 2.833 2.850 1946.181 1949.729 1953.118 1951.416 1956.458 1960.168 1962.662 1963.912 1966.101 1964.581 1963.844 1968.298 1971.894 1968.706 1968.952 1967.987 1967.338 1960.845 1953.002 1947.995 1948.857 1943.590 1938.523 1934.747 1935.416 1938.495 1937.497 1933.056 1933.091 1931.906 1934.499 1937.396 1936.803 1937.219 1947.333 1949.716 1946.027 1946.040 1950.314 1953.722 1956.517 1959.357 1953.264 1945.938 1938.983 1934.529 1932.713 1937.628 1938.782 1950.639 1961.224 1967.529 1975.623 1982.546 1987.314 1989.777 1983.789 312.650 313.432 314.213 314.918 315.645 316.347 317.129 317.848 318.538 319.150 319.770 320.441 321.187 321.760 322.331 322.914 323.424 324.045 324.484 325.029 325.551 326.153 326.734 327.271 327.955 328.697 329.426 330.135 330.861 331.598 332.359 333.221 334.003 334.833 335.766 336.733 337.434 338.169 338.940 339.707 340.561 341.393 342.037 342.644 343.282 343.888 344.597 345.449 346.348 347.375 348.459 349.469 350.416 351.326 352.125 352.877 353.487 Final Rate Cum Rec T Plot Horner Time Horner Slope (PSIICyde) Edited Data Start Time Perforations Location : :12/12/2004 2:47:00 10,371-10,383 MD WFU # 2 Data Units MM/DDIYYY 12/12/2004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12/1212004 12/1212004 12/1212004 12/1212004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 . 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 Clock Time Hours 5:39:00 5:40:00 5:41 :00 5:42:00 5:43:00 5:44:00 5:45:00 5:46:00 5:47:00 5:48:00 5:49:00 5:50:00 5:51 :00 5:52:00 5:53:00 5:54:00 5:55:00 5:56:00 5:57:00 5:58:00 5:59:00 6:00:00 6:01 :00 6:02:00 6:03:00 6:04:00 6:05:00 6:06:00 6:07:00 6:08:00 6:09:00 6:10:00 6:11:00 6:12:00 6:13:00 6:14:00 6: 15:00 6: 16:00 6:17:00 6:18:00 6:19:00 6:20:00 6:21 :00 6:22:00 6:23:00 6:24:00 6:25:00 6:26:00 6:27:00 6:28:00 6:29:00 6:30:00 6:31:00 6:32:00 6:33:00 6:34:00 6:35:00 ~ Final Rate Cum Ree T 5.493 MMSCF/D 2.671 MMSCF 11.67 Hours Homer Time Tubing PSIA Casing PSIA Delta Time Delta Press (T + dT)/dT 1970.950 353.911 1962.758 354.254 1955.934 354.736 1951.968 355.257 1956.647 355.964 1965.552 356.866 1973.321 357.847 1982.427 358.835 1984.353 359.709 1976.540 360.369 1970.807 360.816 1965.138 361.413 1962.096 361.983 1961.052 362.620 1960.342 363.374 1964.261 364.157 1972.132 365.079 1980.480 366.040 1986.310 367.004 1991.154 367.901 1929.100 367.516 1900.691 367.226 1868.920 367.175 1844.865 367.316 1825.837 367.754 1811.473 368.439 1800.020 369.249 1791.269 370.152 1783.773 371.182 1779.141 372.201 1776.408 373.390 1774.619 374.548 1774.651 375.791 1777.172 377.030 1781.305 378.322 1787.116 379.642 1790.194 380.871 1794.485 382.185 1793.303 383.291 1791.675 384.334 1789.244 385.259 1787.898 386.260 1787.491 387.329 1788.390 388.426 1789.825 389.599 1791.369 390.644 1795.549 391.797 1814.000 393.299 2005.265 398.262 2113.761 402.992 2202.036 406.370 2240.265 408.375 2223.472 409.436 2216.862 409.605 2210.875 409.191 2208.252 408.275 2206.756 407.047 2.867 2.883 2.900 2.917 2.933 2.950 2.967 2.983 3.000 3.017 3.033 3.050 3.067 3.083 3.100 3.117 3.133 3.150 3.167 3.183 3.200 3.217 3.233 3.250 3.267 3.283 3.300 3.317 3.333 3.350 3.367 3.383 3.400 3.417 3.433 3.450 3.467 3.483 3.500 3.517 3.533 3.550 3.567 3.583 3.600 3.617 3.633 3.650 3.667 3.683 3.700 3.717 3.733 3.750 3.767 3.783 3.800 Plot Homer Time Homer Slope (PSI/Cycle) Edited Data Start Time Perforations Location : :12/12/2004 2:47:00 10,371-10,383 MD WFU # 2 Data Units MM/DDIYYY 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 Clock Time Hours 6:36:00 6:37:00 6:38:00 6:39:00 6:40:00 6:41 :00 6:42:00 6:43:00 6:44:00 6:45:00 6:46:00 6:47:00 6:48:00 6:49:00 6:50:00 6:51:00 6:52:00 6:53:00 6:54:00 6:55:00 6:56:00 6:57:00 6:58:00 6:59:00 7:00:00 7:01 :00 7:02:00 7:03:00 7:04:00 7:05:00 7:06:00 7:07:00 7:08:00 7:09:00 7:10:00 7:11:00 7:12:00 7: 13:00 7:14:00 7:15:00 7:16:00 7:17:00 7:18:00 7:19:00 7:20:00 7:21 :00 7:22:00 7:23:00 7:24:00 7:25:00 7:26:00 7:27:00 7:28:00 7:29:00 7:30:00 7:31:00 7:32:00 ~'~' Final Rate Cum Ree T 5.493 MMSCF/D 2.671 MMSCF 11.67 Hours Horner Time Tubing PSIA Casing PSIA Delta Time Delta Press (T + dT)/dT 2202.903 405.636 2199.343 404.164 2195.175 402.587 2191.005 400.996 2186.432 399.386 2182.818 397.818 2178.694 396.237 2174.701 394.681 2171.261 393.151 2167.708 391.640 2164.260 390.154 2160.553 388.686 2157.068 387.240 2153.958 385.827 2151.777 384.494 2149.854 383.179 2148.717 381.914 2147.798 380.628 2146.583 379.428 2145.526 378.261 2144.995 377.188 2143.921 376.037 2143.326 375.006 2143.162 373.920 2143.210 372.817 2143.541 371.787 2143.523 370.737 2143.702 369.716 2143.609 368.760 2143.619 367.776 2143.969 366.854 2143.907 365.901 2143.426 364.909 2142.832 363.867 2142.050 362.887 2141.473 361.869 2140.925 360.633 2140.295 359.360 2138.960 358.138 2138.000 356.945 2137.460 355.733 2136.503 354.546 2135.333 353.421 2134.849 352.305 2133.926 351.200 2133.045 350.158 2132.331 349.077 2131.160 348.034 2130.203 346.943 2128.935 345.958 2128.239 344.896 2127.131 343.954 2125.790 342.954 2124.818 342.013 2123.667 341.052 2122.243 340.114 2120.728 339.114 3.817 3.833 3.850 3.867 3.883 3.900 3.917 3.933 3.950 3.967 3.983 4.000 4.017 4.033 4.050 4.067 4.083 4.100 4.117 4.133 4.150 4.167 4.183 4.200 4.217 4.233 4.250 4.267 4.283 4.300 4.317 4.333 4.350 4.367 4.383 4.400 4.417 4.433 4.450 4.467 4.483 4.500 4.517 4.533 4.550 4.567 4.583 4.600 4.617 4.633 4.650 4.667 4.683 4.700 .4.717 4.733 4.750 Plot Horner Time Homer Slope (PSI/Cycle) Edited Data Start Time :12/12/2004 2:47:00 Final Rate 5.493 MMSCF/D Perforations 10,371-10,383 MD Cum Ree 2.671 MMSCF Location : WFU # 2 T 11.67 Hours Homer Plot Homer Data Units Clock Time Homer Slope MMlDDNYY Time Hours Tubing PSIA Casing PSIA Delta Time Delta Press (T + dT)/dT . Time (PSI/Cycle) 12/12/2004 7:33:00 4.767 2119.095 338.155 12/12/2004 7:34:00 4.783 2117.708 337.256 12/12/2004 7:35:00 4.800 2115.913 336.293 12/12/2004 7:36:00 4.817 2114.372 335.392 12/12/2004 7:37:00 4.833 2112.547 334.531 12/12/2004 7:38:00 4.850 2110.807 333.656 12/12/2004 7:39:00 4.867 2109.466 332.783 12/12/2004 7:40:00 4.883 2107.907 331.918 12/12/2004 7:41:00 4.900 2106.155 331.091 12/12/2004 7:42:00 4.917 2104.098 330.203 12/12/2004 7:43:00 4.933 2102.831 329.373 12/1212004 7:44:00 4.950 2100.579 328.544 12/12/2004 7:45:00 4.967 2098.251 327.699 12/12/2004 7:46:00 4.983 2096.249 326.875 12/12/2004 7:47:00 5.000 2093.747 326.040 12/12/2004 7:48:00 5.017 2091.008 325.210 12/1212004 7:49:00 5.033 2088.398 324.476 12/12/2004 7:50:00 5.050 2490.847 323.655 12/12/2004 7:51 :00 5.067 2473.278 322.339 12/12/2004 7:52:00 5.083 2235.330 315.988 12/12/2004 7:53:00 5.100 2116.355 311.769 12/12/2004 7:54:00 5.117 2038.563 309.719 12/12/2004 7:55:00 5.133 1976.590 309.060 12/12/2004 7:56:00 5.150 1935.365 309.311 12/12/2004 7:57:00 5.167 1904.873 310.344 12/12/2004 7:58:00 5.183 1882.805 311.776 12/12/2004 7:59:00 5.200 1865.473 313.441 12/12/2004 8:00:00 5.217 1853.670 315.163 12/12/2004 8:01 :00 5.233 1839.412 316.930 12/12/2004 8:02:00 5.250 1829.701 318.733 12/12/2004 8:03:00 5.267 1820.888 320.538 12/12/2004 8:04:00 5.283 1813.297 322.479 12/12/2004 8:05:00 5.300 1808.838 324.393 12/12/2004 8:06:00 5.317 1801.450 326.295 12/12/2004 8:07:00 5.333 1796.531 328.280 12/12/2004 8:08:00 5.350 1791.771 330.272 12/12/2004 8:09:00 5.367 1786.458 332.206 12/12/2004 8:10:00 5.383 1782.098 334.200 12/12/2004 8:11:00 5.400 1773.491 336.225 12/12/2004 8: 12:00 5.417 1769.554 338.240 12/12/2004 8:13:00 5.433 1765.196 340.339 12/12/2004 8:14:00 5.450 1763.277 342.426 12/12/2004 8: 15:00 5.467 1760.480 344.451 12/12/2004 8: 16:00 5.483 1758.058 346.488 12/12/2004 8:17:00 5.500 1755.764 348.481 12/12/2004 8:18:00 5.517 1757.953 350.411 12/12/2004 8:19:00 5.533 1756.580 352.265 12/12/2004 8:20:00 5.550 1754.581 354.113 12/12/2004 8:21 :00 5.567 1752.372 355.813 12/12/2004 8:22:00 5.583 1738.821 357.161 12/12/2004 8:23:00 5.600 1730.677 358.600 12/12/2004 8:24:00 5.617 1723.938 360.001 12/12/2004 8:25:00 5.633 1717.895 361.448 12/12/2004 8:26:00 5.650 1713.058 362.888 12/12/2004 8:27:00 5.667 1709.947 364.377 12/12/2004 8:28:00 5.683 1708.948 365.805 12/12/2004 8:29:00 5.700 1709.065 367.279 Edited Data Start Time Perforations location : "~. :1211212004 2:47:00 10.371-10.383 MD WFU#2 Data Units MM/DDIYYY 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/1212004 12/1212004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/1212004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/12/2004 12/12/2004 Clock Time Hours 8:30:00 8:31:00 8:32:00 8:33:00 8:34:00 8:35:00 8:36:00 8:37:00 8:38:00 8:39:00 8:40:00 8:41 :00 8:42:00 8:43:00 8:44:00 8:45:00 8:46:00 8:47:00 8:48:00 8:49:00 8:50:00 8:51:00 8:52:00 8:53:00 8:54:00 8:55:00 8:56:00 8:57:00 8:58:00 8:59:00 9:00:00 9:01 :00 9:02:00 9:03:00 9:04:00 9:05:00 9:06:00 9:07:00 9:08:00 9:09:00 9: 1 0:00 9:11 :00 9: 12:00 9: 13:00 9:14:00 9: 15:00 9:16:00 9:17:00 9: 18:00 9: 19:00 9:20:00 9:21 :00 9:22:00 9:23:00 9:24:00 9:25:00 9:26:00 ..~ 5.493 MMSCFIO 2.671 MMSCF 11.67 Hours Homer Time Tubing PSIA Casing PSIA Delta Time Delta Press (T + dT)/dT 1711.732 368.801 1718.005 370.342 1720.384 371.919 1723.601 373.445 1726.137 375.000 1729.046 376.422 1731.882 377.931 1734.880 379.323 1737.554 380.759 1740.017 382.146 1741.397 383.497 1741.941 384.848 1741.171 386.173 1741.965 387.443 1742.592 388.820 1741.878 390.147 1739.825 391.442 1737.113 392.750 1739.020 394.048 1739.005 395.387 1738.468 396.734 1741.673 398.025 1743.221 399.356 1744.178 400.686 1746.883 401.969 1750.195 403.287 1751.559 404.602 1754.731 405.932 1755.889 407.235 1756.006 408.546 1755.867 409.821 1756.114 411.073 1754.958 412.341 1754.160 413.592 1754.988 414.833 1755.127 416.069 1755.312 417.257 1755.173 418.499 1754.527 419.678 1754.776 420.895 1755.313 422.020 1756.547 423.251 1756.906 424.483 1756.938 425.688 1757.054 426.912 1757.150 428.059 1757.628 429.245 1758.534 430.502 1757.779 431.627 1758.088 432.712 1756.723 433.835 1757.309 434.943 1757.768 436.040 1759.165 437.173 1759.726 438.307 1760.692 439.420 1760.752 440.561 5.717 5.733 5.750 5.767 5.783 5.800 5.817 5.833 5.850 5.867 5.883 5.900 5.917 5.933 5.950 5.967 5.983 6.000 6.017 6.033 6.050 6.067 6.083 6.100 6.117 6.133 6.150 6.167 6.183 6.200 6.217 6.233 6.250 6.267 6.283 6.300 6.317 6.333 6.350 6.367 6.383 6.400 6.417 6.433 6.450 6.467 6.483 6.500 6.517 6.533 6.550 6.567 6.583 6.600 6.617 6.633 6.650 Final Rate Cum Ree T Plot Homer Time Homer Slope (PSI/Cycle) .--- .~ Edited Data Start Time : 1211212004 2:47:00 Final Rate 5.493 MMSCF/D Perforations 10,371-10,383 MD Cum Rec 2.671 MMSCF location : WFU # 2 T 11.67 Hours Horner Plot Horner Data Units Clock Time Horner Slope MMlDDIYYY Time Hours Tubing PSIA Casing PSIA Delta Time Delta Press (T + dT)ldT Time (PSI/Cycle) 1211212004 9:27:00 6.667 1760.716 441.693 1211212004 9:28:00 6.683 1760.774 442.760 1211212004 9:29:00 6.700 1761.134 443.915 12/12/2004 9:30:00 6.717 1759.434 444.993 12/12/2004 9:31:00 6.733 1759.110 446.082 12/12/2004 9:32:00 6.750 1759.838 447.166 12/12/2004 9:33:00 6.767 1759.381 448.270 12/12/2004 9:34:00 6.783 1759.636 449.331 12/12/2004 9:35:00 6.800 1759.543 450.441 12/12/2004 9:36:00 .6.817 1759.582 451.520 12/1212004 9:37:00 6.833 1760.885 452.668 12/1212004 9:38:00 6.850 1760.765 453.802 12/1212004 9:39:00 6.867 1761.210 454.908 12/1212004 9:40:00 6.883 1761.343 455.987 12/1212004 9:41:00 6.900 1761.533 457.014 12/1212004 9:42:00 6.917 1762.184 458.034 12/1212004 9:43:00 6.933 1762.193 459.120 12/1212004 9:44:00 6.950 1762.532 460.172 12/12/2004 9:45:00 6.967 1762.405 461.247 12/1212004 9:46:00 6.983 1762.878 462.248 12/1212004 9:47:00 7.000 1763.348 463.340 12/12/2004 9:48:00 7.017 1763.282 464.401 12/1212004 9:49:00 7.033 1763.222 465.419 12/12/2004 9:50:00 7.050 1763.000 466.469 12/1212004 9:51:00 7.067 1762.183 467.501 12/1212004 9:52:00 7.083 1762.302 468.574 12/12/2004 9:53:00 7.100 1762.376 469.579 12/12/2004 9:54:00 7.117 1762.434 470.577 12/12/2004 9:55:00 7.133 1761.800 471.643 12/1212004 9:56:00 7.150 1761.539 472.694 12/12/2004 9:57:00 7.167 1761.089 473.716 12/1212004 9:58:00 7.183 1760.728 474.690 12/1212004 9:59:00 7.200 1760.949 475.698 12/12/2004 10:00:00 7.217 1761.432 476.586 12112/2004 10:01 :00 7.233 1762.760 477.418 12/12/2004 10:02:00 7.250 1765.087 478.327 12112/2004 10:03:00 7.267 1766.459 479.151 12112/2004 10:04:00 7.283 1765.751 479.978 1211212004 10:05:00 7.300 1765.017 480.825 12/1212004 10:06:00 7.317 1764.260 481.642 1211212004 10:07:00 7.333 1764.256 482.505 12/12/2004 10:08:00 7.350 1764.173 483.319 1211212004 10:09:00 7.367 1764.061 484.214 12/12/2004 10:10:00 7.383 1763.393 485.077 12112/2004 10:11 :00 7.400 1763.659 485.992 12/1212004 10:12:00 7.417 1762.882 486.907 12/12/2004 10:13:00 7.433 1763.605 487.814 12/12/2004 10:14:00 7.450 1763.146 488.797 12/12/2004 10:15:00 7.467 1762.404 489.691 12/12/2004 10:16:00 7.483 1762.014 490.586 12112/2004 10:17:00 7.500 1761.697 491.481 12/1212004 10:18:00 7.517 1762.175 492.397 12112/2004 10:19:00 7.533 1762.276 493.349 12/12/2004 10:20:00 7.550 1762.597 494.281 12112/2004 10:21 :00 7.567 1762.479 495.178 1211212004 10:22:00 7.583 1762.205 496.103 12/1212004 10:23:00 7.600 1762.357 497.000 Edited Data Start Time Perforations Location : :12112/2004 2:47:00 10,371-10,383 MD WFU # 2 Data Units MMlDDIYYY 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 12112/2004 1211212004 1211212004 12112/2004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 1211212004 12112/2004 12/12/2004 1211212004 12/1212004 12112/2004 12/12/2004 12/12/2004 1211212004 1211212004 1211212004 1211212004 12/1212004 12/12/2004 12/1212004 12/1212004 12112/2004 12/12/2004 12/1212004 Clock Time Hours 10:24:00 10:25:00 10:26:00 10:27:00 10:28:00 10:29:00 10:30:00 10:31:00 10:32:00 10:33:00 10:34:00 10:35:00 10:36:00 10:37:00 10:38:00 10:39:00 10:40:00 10:41:00 10:42:00 10:43:00 10:44:00 10:45:00 10:46:00 10:47:00 10:48:00 10:49:00 10:50:00 10:51:00 10:52:00 10:53:00 10:54:00 10:55:00 10:56:00 10:57:00 10:58:00 10:59:00 11 :00:00 11:01:00 11 :02:00 11 :03:00 11 :04:00 11 :05:00 11 :06:00 11 :07:00 11 :08:00 11 :09:00 11:10:00 11:11:00 11:12:00 11:13:00 11:14:00 11 :15:00 11:16:00 11:17:00 11:18:00 11:19:00 11 :20:00 '~ 5.493 MMSCF/D 2.671 MMSCF 11.67 Hours Homer Time Tubing PSIA Casing PSIA Delta Time Delta Press (T + dT)/dT 1762.318 497.874 1762.359 498.789 1762.281 499.709 1762.637 500.598 1762.801 501.526 1763.186 502.388 1763.271 503.316 1763.754 504.199 1764.000 505.105 1763.903 506.011 1764.004 506.882 1764.045 507.741 1763.936 508.645 1763.904 509.514 1763.967 510.358 1764.428 511.263 1764.615 512.139 1764.940 512.971 1765.551 513.795 1765.948 514.643 1765.681 515.549 1766.463 516.368 1766.820 517.213 1768.985 518.075 1769.968 518.951 1770.696 519.757 1770.226 520.638 1770.172 521.394 1770.415 522.192 1770.077 523.004 1770.721 523.853 1771.096 524.596 1771.217 525.451 1771.348 526.269 1771.658 527.052 1691.569 526.460 1663.108 526.032 1643.904 526.170 1631.396 526.618 1622.934 527.411 1617.180 528.358 1612.745 529.369 1611.281 530.430 1609.756 531.456 1608.765 532.549 1607.001 533.583 1604.971 534.564 1601.968 535.566 1599.714 536.521 1597.814 537.479 1595.827 538.430 1594.127 539.391 1593.295 540.417 1592.637 541.445 1592.745 542.475 1593.062 543.543 1593.343 544.587 7.617 7.633 7.650 7.667 7.683 7.700 7.717 7.733 7.750 7.767 7.783 7.800 7.817 7.833 7.850 7.867 7.883 7.900 7.917 7.933 7.950 7.967 7.983 8.000 8.017 8.033 8.050 8.067 8.083 8.100 8.117 8.133 8.150 8.167 8.183 8.200 8.217 8.233 8.250 8.267 8.283 8.300 8.317 8.333 8.350 8.367 8.383 8.400 8.417 8.433 8.450 8.467 8.483 8.500 8.517 8.533 8.550 Final Rate Cum Rec T Plot Homer Time Homer Slope (PSIICyde) Edited Data Start Time Perforations Location : :12/12/2004 2:47:00 10,371-10,383 MD WFU # 2 Data Units MM/DDNYY 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 . 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 Clock Time Hours 11:21:00 11 :22:00 11 :23:00 11 :24:00 11 :25:00 11 :26:00 11 :27:00 11 :28:00 11 :29:00 11 :30:00 11:31:00 11:32:00 11 :33:00 11 :34:00 11 :35:00 11 :36:00 11 :37:00 11 :38:00 11 :39:00 11 :40:00 11:41:00 11 :42:00 11:43:00 11:44:00 11 :45:00 11:46:00 11 :47:00 11 :48:00 11 :49:00 11 :50:00 11:51:00 11 :52:00 11 :53:00 11 :54:00 11 :55:00 11 :56:00 11 :57:00 11 :58:00 11 :59:00 12:00:00 12:01 :00 12:02:00 12:03:00 12:04:00 12:05:00 12:06:00 12:07:00 12:08:00 12:09:00 12:10:00 12:11:00 12:12:00 12:13:00 12:14:00 12:15:00 12:16:00 12:17:00 ~ Final Rate Cum Ree T 5.493 MMSCF/D 2.671 MMSCF 11.67 Hours Homer Time Tubing PSIA Casing PSIA Delta Time Delta Press (T + dT)/dT 8.567 8.583 8.600 8.617 8.633 8.650 8.667 8.683 8.700 8.717 8.733 8.750 8.767 8.783 8.800 8.817 8.833 8.850 8.867 8.883 8.900 8.917 8.933 8.950 8.967 8.983 9.000 9.017 9.033 9.050 9.067 9.083 9.100 9.117 9.133 9.150 9.167 9.183 9.200 9.217 9.233 9.250 9.267 9.283 9.300 9.317 9.333 9.350 9.367 9.383 9.400 9.417 9.433 9.450 9.467 9.483 9.500 1594.883 1595.896 1596.508 1597.484 1597.943 1598.074 1593.686 18.545 13.542 13.581 13.572 13.578 13.577 13.583 13.600 13.597 13.607 13.624 13.606 13.631 13.602 13.616 13.608 13.601 13.604 13.608 13.611 13.620 13.604 13.602 13.589 13.605 13.589 13.590 13.581 13.600 13.593 13.568 13.584 13.557 13.546 13.573 13.581 13.573 13.547 13.557 13.591 13.562 13.561 13.625 1604.893 1605.168 1604.072 1603.998 1604.019 1603.653 1602.992 545.667 546.693 547.755 548.793 549.793 550.831 551.905 552.901 553.858 554.886 555.853 556.804 557.788 558.805 559.801 560.779 561.677 562.676 563.554 564.506 565.398 566.274 567.190 568.116 568.975 569.852 570.718 571.626 572.517 573.438 574.299 575.172 575.972 576.829 577.681 578.469 579.312 580.128 580.939 581.790 582.657 583.520 584.323 585.182 585.952 586.798 587.585 588.397 589.229 590.050 590.833 591.637 592.383 593.208 593.933 594.691 595.496 Plot Homer Time Homer Slope (PSI/Cycle) Edited Data Start Time Perforations Location : :12/12/2004 2:47:00 10,371-10,383 MD WFU # 2 Data Units MMlDDIYYY 12/1212004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/1212004 12/1212004 12/1212004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 Clock Time Hours 12:18:00 12:19:00 12:20:00 12:21:00 12:22:00 12:23:00 12:24:00 12:25:00 12:26:00 12:27:00 12:28:00 12:29:00 12:30:00 12:31 :00 12:32:00 12:33:00 12:34:00 12:35:00 12:36:00 12:37:00 12:38:00 12:39:00 12:40:00 12:41:00 12:42:00 12:43:00 12:44:00 12:45:00 12:46:00 12:47:00 12:48:00 12:49:00 12:50:00 12:51:00 12:52:00 12:53:00 12:54:00 12:55:00 12:56:00 12:57:00 12:58:00 12:59:00 13:00:00 13:01 :00 13:02:00 13:03:00 13:04:00 13:05:00 13:06:00 13:07:00 13:08:00 13:09:00 13:10:00 13:11:00 13:12:00 13:13:00 13:14:00 .~ Final Rate Cum Ree T 5.493 MMSCF/D 2.671 MMSCF 11.67 Hours Horner Time Tubing PSIA Casing PSIA Delta Time Delta Press (T + dT)/dT 1602.477 596.260 1602.478 597.006 1602.795 597.799 1602.822 598.576 1602.863 599.346 1602.792 600.124 1603.256 600.910 1603.957 601.708 1604.633 602.462 1605.747 603.246 1607.321 604.044 1608.760 604.783 1609.485 605.639 1610.488 606.419 1612.687 607.217 1613.027 607.969 1615.769 608.722 1616.269 609.450 1615.439 610.170 1613.641 610.862 1613.448 611.502 1612.617 612.250 1611.240 612.945 1609.513 613.614 1608.249 614.280 1605.709 614.978 1603.303 615.635 1599.664 616.302 1598.602 617.027 1598.591 617.744 1600.796 618.521 1602.745 619.267 1602.126 619.990 1599.225 620.639 1598.060 621.325 1597.994 622.007 1598.934 622.695 1596.775 623.367 1595.737 624.026 1594.757 624.674 1595.925 625.330 1593.961 625.996 1593.056 626.621 1592.796 627.296 1591.631 627.878 1590.877 628.552 1590.971 629.255 1589.657 629.874 1589.446 630.499 1588.550 631.184 1590.442 631.876 1590.346 632.550 1587.947 633.219 1586.478 633.862 1587.997 634.530 1589.377 635.191 1587.102 635.864 9.517 9.533 9.550 9.567 9.583 9.600 9.617 9.633 9.650 9.667 9.683 9.700 9.717 9.733 9.750 9.767 9.783 9.800 9.817 9.833 9.850 9.867 9.883 9.900 9.917 9.933 9.950 9.967 9.983 10.000 10.017 10.033 10.050 10.067 10.083 10.100 10.117 10.133 10.150 10.167 10.183 10.200 10.217 10.233 10.250 10.267 10.283 10.300 10.317 10.333 10.350 10.367 10.383 10.400 10.417 10.433 10.450 Plot Horner Time Horner Slope (PSI/Cycle) Edited Data Start Time Perforations location : Data Units MM/DDIYYY 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12112/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 5.493 MMSCF/D 2.671 MMSCF 11.67 Hours Horner Time Tubing PSIA Casing PSIA Delta Time Delta Press (T + dT)/dT 1585.203 636.506 1585.554 637.156 1584.509 637.875 1582.562 638.525 1580.985 639.194 1580.319 639.863 1579.322 640.540 1581.982 641.187 1587.634 641.953 1588.592 642.741 1588.426 643.352 1588.272 644.059 1588.207 644.712 1587.963 645.317 1588.277 645.939 1590.759 646.540 1592.294 647.213 1592.089 647.870 1593.429 648.505 1593.688 649.120 1593.873 649.790 1594.504 650.420 1594.423 651.051 1594.847 651.676 1594.023 652.158 1594.181 652.797 1595.725 653.416 1596.587 654.026 1598.388 654.619 1599.591 655.224 1601.643 655.803 1603.972 656.468 1605.460 657.114 1605.589 657.717 1607.557 658.259 1610.516 658.943 1612.312 659.531 1611.376 660.169 1612.639 660.725 1614.802 661.359 1614.741 661.963 1615.559 662.575 1617.244 663.191 1617.812 663.742 1545.443 663.344 1516.169 662.749 1496.538 662.472 1482.231 662.566 1471.951 662.844 1464.365 663.319 1458.760 663.852 1453.331 664.362 1450.549 664.949 1448.018 665.603 1447.250 666.342 1446.250 667.009 1445.429 667.699 '- :12/12/2004 2:47:00 10,371-10,383 MD WFU # 2 Clock Time Hours 13:15:00 10.467 13: 16:00 10.483 13:17:00 10.500 13:18:00 10.517 13: 19:00 10.533 13:20:00 10.550 13:21:00 10.567 13:22:00 10.583 13:23:00 10.600 13:24:00 10.617 13:25:00 10.633 13:26:00 10.650 13:27:00 10.667 13:28:00 10.683 13:29:00 10.700 13:30:00 10.717 13:31:00 10.733 13:32:00 10.750 13:33:00 10.767 13:34:00 10.783 13:35:00 10.800 13:36:00 10.817 13:37:00 10.833 13:38:00 10.850 13:39:00 10.867 13:40:00 10.883 13:41:00 10.900 13:42:00 10.917 13:43:00 10.933 13:44:00 10.950 13:45:00 10.967 13:46:00 10.983 13:47:00 11.000 13:48:00 11.017 13:49:00 11.033 13:50:00 11.050 13:51 :00 11.067 13:52:00 11.083 13:53:00 11.100 13:54:00 11.117 13:55:00 11.133 13:56:00 11.150 13:57:00 11.167 13:58:00 11.183 13:59:00 11.200 14:00:00 11.217 14:01:00 11.233 14:02:00 11.250 14:03:00 11.267 14:04:00 11.283 14:05:00 11.300 14:06:00 11.317 14:07:00 11.333 14:08:00 11.350 14:09:00 11.367 14:10:00 11.383 14:11 :00 11.400 .~ Final Rate Cum Ree T Plot Homer Time Horner Slope (PSI/Cycle) Edited Data Start Time Perforations location: Data Units MM/DDIYYY 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12112/2004 12112/2004 1211212004 1211212004 12112/2004 1211212004 12112/2004 12112/2004 12112/2004 1211212004 12112/2004 12112/2004 12112/2004 12112/2004 12112/2004 12112/2004 1211212004 12112/2004 12112/2004 1211212004 12/12/2004 1211212004 12/12/2004 12112/2004 12112/2004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 . 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 5.493 MMSCF/D 2.671 MMSCF 11.67 Hours Horner Time Tubing PSIA Casing PSIA Delta Time Delta Press (T + dT)/dT 1445.339 668.462 1444.274 669.206 1444.341 669.899 1444.172 670.651 1444.508 671.363 1444.508 672.081 1444.330 672.735 1443.932 673.425 1442.460 674.066 1441.926 674.732 1441.013 675.376 1439.995 676.053 1439.685 676.718 1438.942 677.357 1438.257 677.955 1437.843 678.587 1437.334 679.201 1436.835 679.814 1435.806 680.446 1435.301 681.070 1435.041 681.690 1435.217 682.378 1435.227 683.057 1435.564 683.768 1435.488 684.455 1435.459 685.116 1435.481 685.831 1434.922 686.516 1435.557 687.193 1437.406 687.860 1437.917 688.570 1436.012 689.197 1436.595 689.854 1436.570 690.509 1436.870 691.170 1438.229 691.860 1439.833 692.456 1440.423 693.085 1440.878 693.703 1440.312 694.300 1439.275 694.877 1440.224 695.501 1440.630 696.104 1441.608 696.735 1442.987 697.374 1443.396 697.917 1444.031 698.560 1444.387 699.207 1444.483 699.705 1444.506 700.378 1443.558 700.911 1443.410 701.489 1443.095 702.037 1442.957 702.654 1442.145 703.196 1442.437 703.783 1442.869 704.349 "'-/ :12/12/2004 2:47:00 10,371-10,383 MD WFU # 2 Clock Time Hours 14:12:00 11.417 14:13:00 11.433 14:14:00 11.450 14:15:00 11.467 14:16:00 11.483 14:17:00 11.500 14:18:00 11.517 14:19:00 11.533 14:20:00 11.550 14:21 :00 11.567 14:22:00 11.583 14:23:00 11.600 14:24:00 11.617 14:25:00 11.633 14:26:00 11.650 14:27:00 11.667 14:28:00 11.683 14:29:00 11.700 14:30:00 11.717 14:31:00 11.733 14:32:00 11.750 14:33:00 11.767 14:34:00 11.783 14:35:00 11.800 14:36:00 11.817 14:37:00 11.833 14:38:00 11.850 14:39:00 11.867 14:40:00 11.883 14:41:00 11.900 14:42:00 11.917 14:43:00 11.933 14:44:00 11.950 14:45:00 11.967 14:46:00 11.983 14:47:00 12.000 14:48:00 12.017 14:49:00 12.033 14:50:00 12.050 14:51:00 12.067 14:52:00 12.083 14:53:00 12.100 14:54:00 12.117 14:55:00 12.133 14:56:00 12.150 14:57:00 12.167 14:58:00 12.183 14:59:00 12.200 15:00:00 12.217 15:01:00 12.233 15:02:00 12.250 15:03:00 12.267 15:04:00 12.283 15:05:00 12.300 15:06:00 12.317 15:07:00 12.333 15:08:00 12.350 ~i Final Rate Cum Ree T Plot Horner Time Horner Slope (PSI/Cycle) Edited Data Start Time Perforations Location : Data Units MM/DDIYYY 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12/1212004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 5.493 MMSCF/D 2.671 MMSCF 11.67 Hours Homer Time Tubing PSIA Casing PSIA Delta Time Delta Press (T + dT)/dT 1442.136 704.886 1443.366 705.447 1444.441 706.034 1445.185 706.547 1446.584 707.179 1446.420 707.726 1447.162 708.209 1447.833 708.838 1448.041 709.351 1448.333 709.953 1449.131 710.533 1450.006 711.047 1450.284 711.650 1450.740 712.161 1451.817 712.740 1452.607 713.296 1453.298 713.873 1453.943 714.393 1454.213 714.911 1454.845 715.470 1455.134 716.027 1455.460 716.552 1455.842 717.063 1456.133 717.622 1456.393 718.188 1456.378 718.696 1456.212 719.190 1455.971 719.794 1452.778 720.225 1450.010 720.625 1447.715 721.129 1446.358 721.621 1445.190 722.073 1444.648 722.591 1443.713 723.067 1443.445 723.567 1442.750 724.126 1442.335 724.600 1442.521 725.157 1442.645 725.690 1442.450 726.262 1442.670 726.758 1442.505 727.269 1442.837 727.793 1442.839 728.336 1443.301 728.794 1443.227 729.412 1443.508 729.921 1444.641 730.457 1445.912 731.030 1446.344 731.584 1446.875 732.087 1447.505 732.610 1447.941 733.117 1448.247 733.644 1448.156 734.124 1448.372 734.651 ~ :12/12/2004 2:47:00 10,371-10,383 MD WFU#2 Clock Time Hours 15:09:00 12.367 15:10:00 12.383 15:11:00 12.400 15:12:00 12.417 15:13:00 12.433 15:14:00 12.450 15:15:00 12.467 15:16:00 12.483 15:17:00 12.500 15:18:00 12.517 15:19:00 12.533 15:20:00 12.550 15:21:00 12.567 15:22:00 12.583 15:23:00 12.600 15:24:00 12.617 15:25:00 12.633 15:26:00 12.650 15:27:00 12.667 15:28:00 12.683 15:29:00 12.700 15:30:00 12.717 15:31:00 12.733 15:32:00 12.750 15:33:00 12.767 15:34:00 12.783 15:35:00 12.800 15:36:00 12.817 15:37:00 12.833 15:38:00 12.850 15:39:00 12.867 15:40:00 12.883 15:41:00 12.900 15:42:00 12.917 15:43:00 12.933 15:44:00 12.950 15:45:00 12.967 15:46:00 12.983 15:47:00 13.000 15:48:00 13.017 15:49:00 13.033 15:50:00 13.050 15:51:00 13.067 15:52:00 13.083 15:53:00 13.100 15:54:00 13.117 15:55:00 13.133 15:56:00 13.150 15:57:00 13.167 15:58:00 13.183 15:59:00 13.200 16:00:00 13.217 16:01 :00 13.233 . 16:02:00 13.250 16:03:00 13.267 16:04:00 13.283 16:05:00 13.300 .~ Final Rate Cum Ree T Plot Homer Time Homer Slope (PSI/Cycle) <- -< Edited Data Start Time : 12/12/2004 2:47:00 Final Rate 5.493 MMSCF/D Perforations 10,371-10,383 MD Cum Ree 2.671 MMSCF Location : WFU#2 T 11.67 Hours Horner Plot Horner Data Units Clock Time Horner Slope MM/DDIYYY Time Hours Tubing PSIA Casing PSIA Delta Time Delta Press (T + dT)/dT Time (PSI/Cycle) 12/12/2004 16:06:00 13.317 1448.069 735.122 12112/2004 16:07:00 13.333 1447.381 735.628 1211212004 16:08:00 13.350 1448.119 736.089 12112/2004 16:09:00 13.367 1448.239 736.579 12112/2004 16:10:00 13.383 1448.355 737.142 12/12/2004 16:11:00 13.400 1449.510 737.606 1211212004 16:12:00 13.417 1450.133 738.095 12/12/2004 16:13:00 13.433 1450.100 738.618 12/12/2004 16:14:00 13.450 1449.354 739.049 12/12/2004 16:15:00 13.467 1449.832 739.494 12/12/2004 16:16:00 13.483 1450.232 739.946 12/1212004 16:17:00 13.500 1450.305 740.446 12/12/2004 16:18:00 13.517 1450.594 740.918 12/12/2004 16:19:00 13.533 1450.726 741.364 12/12/2004 16:20:00 13.550 1450.609 741.858 12/1212004 16:21 :00 13.567 1450.722 742.302 12/12/2004 16:22:00 13.583 1450.391 742.789 12/12/2004 16:23:00 13.600 1449.936 743.249 12/12/2004 16:24:00 13.617 1450.104 743.646 12/1212004 16:25:00 13.633 1450.236 744.171 12/12/2004 16:26:00 13.650 1449.129 744.562 12/12/2004 16:27:00 13.667 1448.634 745.013 12/12/2004 16:28:00 13.683 1448.541 745.492 12/12/2004 16:29:00 13.700 1448.580 745.913 12/12/2004 16:30:00 13.717 1448.196 746.368 12/12/2004 16:31:00 13.733 1447.930 746.789 12/12/2004 16:32:00 13.750 1447.734 747.198 12/12/2004 16:33:00 13.767 1447.281 747.623 12/12/2004 16:34:00 13.783 1447.091 748.085 12/12/2004 16:35:00 13.800 1447.178 748.519 12/1212004 16:36:00 13.817 1447.520 748.992 12/1212004 16:37:00 13.833 1447.347 749.413 12/12/2004 16:38:00 13.850 1447.268 749.904 12/12/2004 16:39:00 13.867 1447.081 750.348 12/12/2004 16:40:00 13.883 1447.249 750.726 12/12/2004 16:41:00 13..900 1446.367 751.195 12/12/2004 16:42:00 13.917 1446.040 751.659 12/12/2004 16:43:00 13.933 1445.135 752.118 12/12/2004 16:44:00 13.950 1444.313 752.521 12/12/2004 16:45:00 13.967 1442.862 752.907 12/12/2004 16:46:00 13.983 1442.020 753.290 12/12/2004 16:47:00 14.000 1441.211 753.687 12/12/2004 16:48:00 14.017 1440.945 754.133 12/12/2004 16:49:00 14.033 1440.958 754.547 12/12/2004 16:50:00 14.050 1440.918 754.969 12/12/2004 16:51:00 14.067 1440.776 755.392 12/12/2004 16:52:00 14.083 1441.171 755.857 12/12/2004 16:53:00 14.100 1441.207 756.239 12/12/2004 16:54:00 14.117 1440.883 756.680 12/12/2004 16:55:00 14.133 1440.885 757.063 12/12/2004 16:56:00 14.150 1440.877 757.481 12/12/2004 16:57:00 14.167 1441.150 757.846 12/12/2004 16:58:00 14.183 1382.130 757.618 12/12/2004 16:59:00 14.200 1353.452 756.950 12/12/2004 17:00:00 14.217 1337.835 756.579 12/12/2004 17:01:00 14.233 1326.516 756.452 12/12/2004 17:02:00 14.250 1318.483 756.579 .~ Edited Data Start Time : 12/12/2004 2:47:00 Final Rate 5.493 MMSCF/D Perforations 10,371-10,383 MD Cum Ree 2.671 MMSCF location : WFU # 2 T 11.67 Hours Homer Plot Horner Data Units Clock Time Homer Slope MMlDDNYY Time Hours Tubing PSIA Casing PSIA Delta Time Delta Press (T + dT)/dT Time (PSI/Cycle) 12/12/2004 17:03:00 14.267 1313.098 756.750 12/12/2004 17:04:00 14.283 1309.030 756.998 12/12/2004 17:05:00 14.300 1307.218 757.305 12/12/2004 17:06:00 14.317 ·1304.632 757.618 12/12/2004 17:07:00 14.333 1301.883 757.929 12/12/2004 17:08:00 14.350 1300.193 758.292 12/12/2004 17:09:00 14.367 1297.399 758.634 12/12/2004 17:10:00 14.383 1295.570 758.981 12/12/2004 17:11:00 14.400 1294.152 759.413 12/12/2004 17:12:00 14.417 1293.560 759.803 12/12/2004 17:13:00 14.433 1293.721 760.202 12/12/2004 17:14:00 14.450 1294.326 760.661 12/12/2004 17:15:00 14.467 1294.454 761.070 12/12/2004 17:16:00 14.483 1294.506 761.514 12/1212004 17:17:00 14.500 1294.478 761.995 12/12/2004 17:18:00 14.517 1293.904 762.437 12/12/2004 17:19:00 14.533 1293.369 762.852 12/12/2004 17:20:00 14.550 1292.785 763.296 12/12/2004 17:21:00 14.567 1291.770 763.716 12/12/2004 17:22:00 14.583 1291.596 764.132 12/1212004 17:23:00 14.600 1292.568 764.529 12/1212004 17:24:00 14.617 1292.653 764.853 12/1212004 17:25:00 14.633 1292.479 765.217 12/12/2004 17:26:00 14.650 1292.055 765.586 12/1212004 17:27:00 14.667 1290.962 765.862 12/12/2004 17:28:00 14.683 1289.053 766.132 12/12/2004 17:29:00 14.700 1287.729 766.428 12/12/2004 17:30:00 14.717 1286.571 766.741 12/12/2004 17:31:00 14.733 1285.470 767.010 12/12/2004 17:32:00 14.750 1284.902 767.347 12/12/2004 17:33:00 14.767 1284.213 767.715 12/12/2004 17:34:00 14.783 1283.829 768.043 12/12/2004 17:35:00 14.800 1283.509 768.425 12/12/2004 17:36:00 14.817 1283.425 768.800 12/12/2004 17:37:00 14.833 1283.639 769.218 12/12/2004 17:38:00 14.850 1284.037 769.599 12/12/2004 17:39:00 14.867 1283.896 769.986 12/12/2004 17:40:00 14.883 1283.724 770.376 12/12/2004 17:41:00 14.900 1282.898 770.790 12/1212004 17:42:00 14.917 1282.123 771.216 12/12/2004 17:43:00 14.933 1281.138 771.627 12/12/2004 17:44:00 14.950 1282.668 772.008 12/12/2004 17:45:00 14.967 1284.379 772.431 12/12/2004 17:46:00 14.983 1285.467 772.865 12/12/2004 17:47:00 15.000 1286.935 773.286 12/12/2004 17:48:00 15.017 1286.648 773.668 12/12/2004 17:49:00 15.033 1287.195 773.986 12/12/2004 17:50:00 15.050 1287.700 774.433 12/12/2004 17:51:00 15.067 1287.909 774.796 12/12/2004 17:52:00 15.083 1288.654 775.139 12/12/2004 17:53:00 15.100 1289.330 775.518 12/12/2004 17:54:00 15.117 1289.925 775.844 12/12/2004 17:55:00 15.133 1290.109 776.284 12/12/2004 17:56:00 15.150 1290.708 776.617 12/12/2004 17:57:00 15.167 1290.804 776.983 12/12/2004 17:58:00 15.183 1291.781 777.305 12/12/2004 17:59:00 15.200 1291.786 777.686 Edited Data Start Time Perforations Location : Data Units MMlDDIYYY 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004' 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 '- :12/12/2004 2:47:00 1.0,371-10,383 MD WFU # 2 Clock Time Hours 18:00:00 15.217 18:01:00 15.233 18:02:00 15.250 18:03:00 15.267 18:04:00 15.283 18:05:00 15.300 18:06:00 15.317 18:07:00 15.333 18:08:00 15.350 18:09:00 15.367 18:10:00 15.383 18:11:00 15.400 18:12:00 15.417 18:13:00 15.433 18:14:00 15.450 18: 15:00 15.467 18:16:00 15.483 18:17:00 15.500 18:18:00 15.517 18:19:00 15.533 18:20:00 15.550 18:21:00 15.567 18:22:00 15.583 18:23:00 15.600 18:24:00 15.617 18:25:00 15.633 18:26:00 15.650 18:27:00 15.667 18:28:00 15.683 18:29:00 15.700 18:30:00 15.717 18:31:00 15.733 18:32:00 15.750 18:33:00 15.767 18:34:00 15.783 18:35:00 15.800 18:36:00 15.817 18:37:00 15.833 18:38:00 15.850 18:39:00 15.867 18:40:00 15.883 18:41:00 15.900 18:42:00 15.917 18:43:00 15.933 18:44:00 15.950 18:45:00 15.967 18:46:00 15.983 18:47:00 16.000 18:48:00 16.017 18:49:00 16.033 18:50:00 16.050 18:51:00 16.067 18:52:00 16.083 18:53:00 16.100 18:54:00 16.117 18:55:00 16.133 18:56:00 16.150 .~ 5.493 MMSCF/D 2.671 MMSCF 11.67 Hours Homer Time Tubing PSIA Casing PSIA Delta Time Delta Press (T + dT)/dT 1292.592 778.026 1292.983 778.395 1294.449 778.718 1295.488 779.110 1295.505 779.449 1295.840 779.848 1296.934 780.192 1298.108 780.580 1299.291 780.936 1300.859 781.273 1302.908 781.647 1304.033 782.076 1304.852 782.440 1305.684 782.808 1305.591 783.141 1305.849 783.498 1306.373 783.822 1306.783 784.241 1307.421 784.588 1307.991 784.974 1308.394 785.383 1309.139 785.737 1310.243 786.105 1311.123 786.498 1311.546 786.890 1311.877 787.255 1312.619 787.646 1313.390 788.069 1314.133 788.425 1314.263 788.765 1314.506 789.156 1314.010 789.496 1313.734 789.873 1313.474 790.231 1313.776 790.616 1313.852 790.983 1314.345 791.352 1314.704 791.785 1315.411 792.153 1315.662 792.520 1316.142 792.887 1316.211 793.284 1316.126 793.613 1315.885 793.989 1315.875 794.373 1316.078 794.741 1316.029 795.145 1316.428 795.547 1316.687 795.897 1316.724 796.245 1316.707 796.593 1316.877 796.999 1317.056 797.329 1317.297 797.706 1317.490 798.083 1318.120 798.446 1318.263 798.816 Final Rate Cum Rec T Plot HomerˆTime Horner Slope (PSI/Cycle) Edited Data Start Time Peñorations location : Data Units MM/DDNVY 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/1212004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 , 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 12/12/2004 5.493 MMSCF/D 2.671 MMSCF 11.67 Hours Horner Time Tubing PSIA Casing PSIA Delta Time Delta Press (T + dT)/dT 1318.640 799.233 1318.977 799.602 1319.550 799.996 1319.969 800.397 1320.256 800.724 1320.870 801.144 1320.746 801.487 1321.243 801.873 1321.541 802.328 1321.625 802.671 1321.905 803.022 1321.993 803.438 1322.221 803.755 1321.956 804.177 1322.357 804.510 1322.371 804.873 1322.359 805.218 1322.436 805.633 1322.247 805.986 1322.018 806.366 1322.045 806.743 1322.286 807.113 1323.094 807.486 1323.481 807.863 1323.968 808.222 1324.271 808.564 1324.704 808.918 1324.850 809.257 1324.997 809.615 1325.112 810.004 1325.569 810.337 1325.687 810.656 1325.754 811.049 1325.715 811.336 1325.691 811.644 1325.748 812.071 1325.693 812.388 1325.440 812.709 1325.019 813.060 1325.168 813.385 1325.003 813.689 1325.087 814.096 1325.376 814.383 1325.568 814.709 1326.064 815.020 1326.191 815.338 1326.531 815.663 1326.722 815.991 1326.641 816.312 1326.594 816.590 1326.698 816.919 1326.656 817.193 1326.801 817.540 1326.992 817.857 1326.949 818.181 1327.162 818.494 1326.942 818.801 :12/12/2004 2:47:00 10,371-10,383 MD WFU # 2 Clock Time Hours 18:57:00 16.167 18:58:00 16.183 18:59:00 16.200 19:00:00 16.217 19:01:00 16.233 19:02:00 16.250 19:03:00 16.267 19:04:00 16.283 19:05:00 16.300 19:06:00 16.317 19:07:00 16.333 19:08:00 16.350 19:09:00 16.367 19:10:00 16.383 19:11:00 16.400 19:12:00 16.417 19:13:00 16.433 19:14:00 16.450 19:15:00 16.467 19:16:00 16.483 19:17:00 16.500 19:18:00 16.517 19:19:00 16.533 19:20:00 16.550 19:21:00 16.567 19:22:00 16.583 19:23:00 16.600 19:24:00 16.617 19:25:00 16.633 19:26:00 16.650 19:27:00 16.667 19:28:00 16.683 19:29:00 16.700 19:30:00 16.717 19:31:00 16.733 19:32:00 16.750 19:33:00 16.767 19:34:00 16.783 19:35:00 16.800 19:36:00 16.817 19:37:00 16.833 19:38:00 16.850 19:39:00 16.867 19:40:00 16.883 19:41:00 16.900 19:42:00 16.917 19:43:00 16.933 19:44:00 16.950 19:45:00 16.967 19:46:00 16.983 19:47:00 17.000 19:48:00 17.017 19:49:00 17.033 19:50:00 17.050 19:51:00 17.067 19:52:00 17.083 19:53:00 17.100 .~ Final Rate Cum Ree T Plot Horner Time Horner Slope (PSI/Cycle) ,"-/ Edited Data Start Time : 12/12/2004 2:47:00 Final Rate 5.493 MMSCFJD Perforations 10,371-10,383 MD Cum Rec 2.671 MMSCF Location : WFU # 2 T 11.67 Hours Homer Plot Homer Data Units Clock Time Homer Slope MMlDDIYYY Time Hours Tubing PSIA Casing PSIA Delta Time Delta Press (T + dT)/dT Time (PSI/Cycle) 12/12/2004 19:54:00 17.117 1327.010 819.132 12/12/2004 19:55:00 17.133 1327.026 819.439 12/12/2004 19:56:00 17.150 1326.652 819.752 12/12/2004 19:57:00 17.167 1326.745 820.049 12/12/2004 19:58:00 17.183 1327.098 820.334 12/12/2004 19:59:00 17.200 1327.214 820.642 12/12/2004 19:59:30 17.208 1327.884 820.815 Well Shut-In. Beginning of Build Up. 12/12/2004 19:59:35 17.210 1359.726 820.987 0.00139 31.842 8402.9 12/1212004 19:59:40 17.211 1461.792 821.560 0.00278 133.908 4202.0 5942.1 147.28 12/12/2004 19:59:45 17.213 1506.858 822.244 0.00417 178.974 2801.6 3431.1 111.18 12/12/2004 19:59:50 17.214 1542.237 823.105 0.00556 214.353 2101.5 2426.4 123.03 12/12/2004 19:59:55 17.215 1572.191 823.817 0.00695 244.307 1681.4 1879.7 134.31 12/12/2004 20:00:00 17.217 1598.455 824.518 0.00833 270.571 1401.3 1535.0 144.15 12/1212004 20:00:05 17.218 1622.137 825.521 0.00972 294.253 1201.3 1297.5 153.75 12/12/2004 20:00:20 17.222 1682.801 827.537 0.01389 354.917 841.3 1005.3 170.29 12/12/2004 20:00:25 17.224 1701.007 828.191 0.01528 373.123 764.9 802.2 191.24 12/12/2004 20:00:30 17.225 1718.620 828.973 0.01667 390.736 701.2 732.3 202.69 12/12/2004 20:00:35 17.226 1735.670 829.744 0.01806 407.786 647.3 673.7 213.32 12/12/2004 20:00:45 17.229 1768.574 830.986 0.02083 440.690 561.2 602.7 230.31 12/12/2004 20:00:55 17.232 1799.905 832.348 0.02361 472.021 495.3 527.2 250.87 12/12/2004 20:01 :05 17.235 1830.044 833.547 0.02639 502.160 443.2 468.5 271.53 12/1212004 20:01:15 17.238 1858.895 834.687 0.02917 531.011 401.1 421.7 288.93 12/12/2004 20:01 :25 17.240 1886.585 835.821 0.03195 558.701 366.3 383.3 305.16 12/12/2004 20:01 :40 17.244 1925.813 837.306 0.03611 597.929 324.2 344.6 320.95 12/12/2004 20:01 :55 17.249 1962.661 838.696 0.04028 634.777 290.7 307.0 338.51 12/12/2004 20:02:15 17.254 2007.939 840.205 0.04583 680.055 255.6 272.6 351.68 12/12/2004 20:02:35 17.260 2049.117 841.555 0.05139 721.233 228.1 241.5 361.45 12/12/2004 20:02:55 17.265 2086.428 842.644 0.05694 758.544 205.9 216.7 365.12 12/12/2004 20:03:20 17.272 2127.781 843.674 0.06389 799.897 183.7 194.5 361.26 12/12/2004 20:03:45 17.279 2163.892 844.361 0.07083 836.008 165.8 174.5 351.96 12/12/2004 20:04:20 17.289 2206.413 844.803 0.08056 878.529 145.9 155.5 332.75 12/12/2004 20:04:55 17.299 2240.823 844.875 0.09028 912.939 130.3 137.9 304.21 12/12/2004 20:05:30 17.308 2268.402 844.492 0.1??oo 940.518 117.7 123.8 271.85 12/12/2004 20:06:15 17.321 2295.863 843.471 0.11250 967.979 104.7 111.0 235.27 12/12/2004 20:07:05 17.335 2318.315 841.952 0.12639 990.431 93.3 98.9 194.84 12/12/2004 20:08:00 17.350 2336.061 839.769 0.14167 1008.177 83.4 88.2 157.29 12/12/2004 20:09:05 17.368 2350.790 837.010 0.15972 1022.906 74.1 78.6 124.36 12/12/2004 20:10:15 17.388 2362.050 833.738 0.17917 1034.166 66.1 70.0 99.44 12/12/2004 20:11 :30 17.408 2370.749 830.259 0.20000 1042.865 59.4 62.7 80.37 12/12/2004 20:13:00 17.433 2378.589 825.959 0.22500 1050.705 52.9 56.0 67.77 12/12/2004 20:14:35 17.460 2384.926 821.481 0.25139 1057.042 47.4 50.1 58.31 12/12/2004 20:16:25 17.490 2390.819 816.334 0.28195 1062.935 42.4 44.8 52.55 12/12/2004 20:18:30 17.525 2396.250 810.529 0.31667 1068.366 37.9 40.1 47.96 12/12/2004 20:20:50 17.564 2401.278 804.210 0.35556 1073.394 33.8 35.8 44.66 12/12/2004 20:23:25 17.607 2405.973 797.440 0.39861 1078.089 30.3 32.0 42.40 12/12/2004 20:26:20 17.656 2410.463 790.022 0.44722 1082.579 27.1 28.6 40.43 12/12/2004 20:29:35 17.710 2414.701 781.967 0.50139 1086.817 24.3 25.6 38.57 12/12/2004 20:33:15 17.771 2418.898 773.226 0.56250 1091.014 21.7 23.0 38.15 12/12/2004 20:37:25 17.840 2422.960 763.677 0.63195 1095.076 19.5 20.6 36.68 12/12/2004 20:42:00 17.917 2426.836 753.448 0.70833 1098.952 17.5 18.4 35.91 12/12/2004 20:47:10 18.003 2430.675 742.437 0.79445 1102.791 15.7 16.6 35.61 12/12/2004 20:53:00 18.100 2434.491 730.460 0.89167 1106.607 14.1 14.9 35.44 12/12/2004 20:59:30 18.208 2438.129 717.744 1.00000 1110.245 12.7 13.4 34.30 12/12/2004 21 :06:50 18.331 2441.722 704.027 1.12222 1113.838 11.4 12.0 33.99 12/12/2004 21 :15:05 18.468 2445.240 689.430 1.25972 1117.356 10.3 10.8 33.54 12/12/2004 21 :24:20 18.622 2448.678 673.894 1.41389 1120.794 9.3 9.7 33.19 12/12/2004 21 :34:40 18.794 2452.021 657.534 1.58611 1124.137 8.4 8.8 32.82 ,,-. ~ Edited Data Start Time : 12/12/2004 2:47:00 Final Rate 5.493 MM5CF/D Perforations 10,371-10,383 MD Cum Ree 2.671 MMSCF Location : WFU # 2 T 11.67 Hours Homer Plot Homer Data Units Clock Time Homer Slope MM/DDIYYY Time Hours Tubing PSIA Casing PSIA Delta Time Delta Press (T + dT)/dT Time (PSI/Cycle) 12/1212004 21:46:15 18.988 2455.360 640.309 1.77917 1127.476 7.6 7.9 33.26 12/1212004 21:59:15 19.204 2458.527 622.245 1.99583 1130.643 6.8 7.2 32.01 12/1212004 22:13:50 19.447 2461.611 603.418 2.23889 1133.727 6.2 6.5 31.70 12/1212004 22:30:15 19.721 2464.640 583.628 2.51250 1136.756 5.6 5.9 31.61 12/1212004 22:48:40 20.028 2467.840 563.289 2.81945 1139.956 5.1 5.4 34.10 12/12/2004 23:09:15 20.371 2470.728 542.376 3.16250 1142.844 4.7 4.9 31.59 12/1212004 23:32:25 20.757 2473.770 520.877 3.54861 1145.886 4.3 4.5 33.99 12/12/2004 23:58:25 21.190 2476.568 498.916 3.98195 1148.684 3.9 4.1 32.11 12/1312004 0:27:35 21.676 2479.131 476.590 4.46806 1151.247 3.6 3.8 30.30 12/13/2004 1:00:15 22.221 2481.490 453.919 5.01250 1153.606 3.3 3.5 28.84 12/1312004 1 :36:55 22.832 2484.157 431.362 5.62361 1156.273 3.1 3.2 33.73 12/1312004 2: 18:05 23.518 2486.032 408.650 6.30972 1158.148 2.8 3.0 24.60 12113/2004 3:04:20 24.289 2487.698 386.072 7.08056 1159.814 2.6 2.7 22.73 12/13/2004 3:56:10 25.153 2489.646 363.833 7.94445 1161.762 2.5 2.6 27.80 12/1312004 4:54:20 26.122 2491.363 342.096 8.91389 1163.479 2.3 2.4 25.67 12/13/2004 5:59:30 27.208 2492.730 320.929 10.00000 1164.846 2.2 2.2 21.51 12/13/2004 6:52:40 28.094 2493.806 305.720 10.88611 1165.922 2.1 2.1 24.00 ~ .~ ~ Laboratory Analysis Report 200 W. Potter Drive Anchorage, AK 99518-1605 Tel: (907) 562-2343 Fax: (907) 561-5301 Web: http://www.sgsenvironmental.com David Hall Forest Oil CorDoration 310 K S1. #700 Anchorage. AK 99501 Work Order: 1047832 West Forland #2 Forest Oil Corporation December 20, 2004 Client: Report Date: Enclosed are the analytical results associated with the above workorder. As required by the state of Alaska and the USEP A, a formal Quality Assurance/Quality Control Program is maintained by SOS. A copy of our Quality Control Manual that outlines this program is available at your request. The laboratory ADEC certification numbers are AK08-03 (DW), UST-005 (CS) and AK00971 (Micro). Except as specifically noted, all statements and data in this report are in conformance to the provisions set forth by the SGS Quality Assurance Program Plan and the National Environmental Laboratory Accreditation Conference. If you have any questions regarding this report or if we can be of any other assistance, please call your SGS Project Manager a (907) 562-2343. The following descriptors may be found on your report which will serve to further qualify the data. PQL U F J B >I< GT D LT Q M JL E Practical Quantitation Limit (reporting limit). Indicates the analyte was analyzed for but not detected. Indicates an estimated value that falls below PQL, but is greater than the MDL. The quantitation is an estimation. Indicates the analyte is found in a blank associated with the sample. The analyte has exceeded allowable regulatory or control limits. Greater Than The analyte concentration is the result of a dilution. Less Than Surrogate out of control limits. QC parameter out of acceptance range. A matrix effect was present. The analyte was positively identified, but the quantitation is a low estimation. The analyte result is high outside of calibrated range. Note: Soil samples are reported on a dry weight basis unless otherwise specified SGS Environmental Services Inc. 1200 W. Potter Dr, Anchorage AK. 99518·1605 t (907) 562-2343 f (907) 561-5301 WWW.lIS.sgs.com ~i SGS Ref.# 1047832001 All Dates/Times are Alaska Standard Time Client Name Forest Oil Corporation Printed Date/Time 12/20/2004 13:24 Project Name/# West Forland #2 Collected Date/Time 11/28/2004 0:00 Client Sample [D SWAB WF#2 10725 Received Date/Time 12/03/2004 12:36 Matrix Water (Surface, Eff., Ground) Technical Director ~ Stephen C. Ede Released By "~ Sample Remarks: -, V) Resistivity, pH - sample was received after holding time had expired. \ Results PQL Units Method Container ID Allowable Prep Analysis Parameter Limits Date Date Init % Difference 7.1 % SM20 1030E A 12/17/04 KAL Routine Oilfield Water Analysis Alkalinity 600 10.0 mg/L SM20 2320B A 12/10/04 KP Chloride 30700 100 mg/L EPA 300.0 A 12/08/04 BJA C03 Alkalinity 10.0 U 10.0 mg/L SM20 2320B A 12110104 KP BC03 Alkalinity 600 10.0 mg/L SM20 2320B A 12/10/04 KP OH Alkalinity 10.0 U 10.0 mg/L SM20 2320B A 12/1 0104 KP pH 8.49 0.100 pH units EPA 150.1 A 12/09/04 KP Resistivity 0.100 0.0100 ohm-m SM192510A A 12/09/04 KAL Sulfate 39.4 5.00 mg/L EP A 300.0 A 12/08/04 BJA Metals Department Barium 2.84 0.100 mg/L EP200.7 Dissolved A 12/14/04 12/16/04 BAG Calcium 97.3 2.00 mg/L EP200.7 Dissolved A 12/14/04 12/16104 BAG Iron 0.400 U 0.400 mg/L EP200.7 Dissolved A 12/14/04 12/16/04 BAG Sodium 541 20.0 mg/L EP200.7 Dissolved A 12/14/04 12/16104 BAG Strontium 1.94 0.1 00 mg/L EP200.7 Dissolved A 12/14/04 12/16/04 BAG Magnesium 3.61 2.00 mg/L EP200.7 Dissolved A 12/14/04 12/16104 BAG Metals by ICP/MS Potassium 28700000 200000 ug/L EP200.8 Dissolved A 12/14/04 12/17/04 W A W ~ Routine Oil Field Water Analysis Report Operator Well Number Field County State Remarks and conclusions: Date Chem-Lab Ref. Number Approved By Location Sample From 104783209~ ~ \d-\\1\d\ ._, ." ,,"'''''''\ ~y "..",'-...._" '" _n.. ... y. Anions .!!!9lh MeQ.lL ...._-,------ -...,............ IV ""'""-,, , '1'1.'_ ,,,,,,,, - Cations "·.......,_._v.. __... '...."-..1.'..'_... .....____ ..----""-...,.,.,..... ........',... -'.".'-." mg/L MeQ./L Sodium. . . . . . . . . . . . . . . . . Potassium . . . . . . . . . . . . . . Calcium. . . . . . . . . . . . . . . . Magnesium. . . . . . . . . . . . . Iron. . . . . . . . . . . . . . . . . . . . 541 28700 97.3 3.61 0.0762 23.53 734.15 4.86 0.30 0.00 Sulfate. . . . . . . . . . .. 39.4 Chloride. . . . . . . . . . . 30700 Carbonate . . . . . . . . . . . . . . . Bicarbonate . . . . . . . . 600 Hydroxide. . . . . . . . . . . . . . . . 0.82 863.28 0.00 12.00 0.0 Total Anions. . . . . . .. 876.104 ,---------"-'--..-..------. ... ,.., .' ,_.,." ..__...'.1"- W .. Total Cations. . . . . . . . . . . . . 762.83 " __"',_______...".1'/. -'v ..' ., ..."'".... .. '.n .... ,.,. v,... ....., Total dissolved solids. . . . .. 60441 NaCI equivalent (chloride) 60222 Observed pH . . . . . . . . . . . . 8.49 --- Barium . . . . . . . . . . . . . . . . . . . . Strontium. . . . . . . . . . . . . . . . . . . . Total Iron . . . . . . . . . . . . . . . . . . . . . ......." 'v ....,^ . ,. ·n.\I' ....... ...,..---. , ,... mg/L mg/L Specific Resistance@ '680 F.: Observed. . . . . . . . . . . . 0.1 ohm-meters Calculated. . . . . . . . . . " 0.12 ohm-meters mg/L mg/L . mg/L Water Analysis Pattern Scale: Milligram equivalents per Unit b 0.:1.35 ,2,0 ~ I(,I~ I't.. to ß 1- : I I Na ('¡({~)n ! ! J ; , I i-+-j i ( '\ I I ! ! Ca 7\' J I ! i ; bl' I f--¡ i I Mg (ì<-IJ 6~! ¡ f~=--+ j I '\ R- i !- Fe(XI J 1:=-1-H- t.L5ifo a.3D X- c., '-f ~ I 2 'i lR ~ 10 12.. ,<{ lip 16.:1.1:> ! i (X/lib) CI ~_k3 j I ~)«(,HC03 Jd. D / I i ! i ! !.....J ! IÔ(I)'S04_~ß~ I ¡ I ì -L[ i I n r'<~03ß (Na value in above graphs includes Sodium, Potassium and L 1) NOTE: mg/L = Milligrams per liter, Meq.lL = Milligram equivalent per liter. Soldium Chloride equivalent = by Dunlap & Hawthorne calculation from components. ----.--.......------ ~ SGS Ref.# 1047832002 All Oates/Times are Alaska Standard Time Client Name Forest Oil Corporation Printed DatelTime 12/20/2004 13:24 Project Name/# West Forland #2 Collected Date/Time 11128/2004 0:00 Client Sample 10 Spl 1 WF#2 10725 Received DatelTime 12/03/2004 12:36 Matrix Water (Surface, Eff., Ground) Technical Direct~. Stephen C. Ede Released By ~ Sample Remarks: \ U Resistivity, pH - sample was received after holding time had expired. Results PQL Units Method Container ID Allowable Prep Analysis Parameter Limits Date Date lnit % Difference 1.0 % SM20 1030E A 12/17/04 KAL Routine Oilfield Water Analysis Alkalinity 500 10.0 mglL SM20 2320B A 12/1 0/04 KP Chloride 8280 20.0 mglL EPA 300.0 A 12/09/04 BJA C03 Alkalinity 10.0 U 10.0 mgIL SM20 2320B A 12/1 0/04 KP HC03 Alkalinity 500 10.0 mglL SM20 2320B A 12/10/04 KP OH Alkalinity 10.0 U 10.0 mgIL SM20 2320B A 12/1 0/04 KP pH 9.19 0.100 pH units EPA 150.1 A 12/09/04 KP Resistivity 1.25 0.0100 ohm-m SM192510A A 12/09/04 KAL Sulfate 29.2 5.00 mglL EPA 300.0 A 12/08/04 BJA Metals Department Barium 7.71 0.100 mglL EP200.7 Dissolved A 12/14/04 12/16/04 BAG Calcium 402 2.00 mglL EP200.7 Dissolved A 12/14/04 12/16104 BAG Iron 3.04 0.400 mglL EP200.7 Dissolved A 12/14/04 12/16104 BAG Sodium 4160 200 mglL EP200.7 Dissolved A 12/14/04 12/16/04 BAG Strontium 22.3 0.100 mglL EP200.7 Dissolved A 12/14/04 12/16104 BAG Magnesium 19.4 2.00 mglL EP200.7 Dissolved A 12/14/04 12/16/04 BAG Metals by ICP/MS Potassium 1430000 200000 uglL EP200.8 Dissolved A 12/14/04 12/17/04 WAW ~ Routine Oil Field Water Analysis Report Operator Well Number Field County State ----. Remarks and conclusions: -- ____"'I,...'" . ... . ~' ....._. ~_..v,...,..._,__"'-______ "1 Cations moIL 4158.6 1430 401.58 19.374 3.0368 Sodium. . . . . . . . . . . . . . . . . Potassium. . . . . . . . . . . . . . Calcium . . . . . . . . . . . . . . . . Magnesium. . . . . . . . . . . . . Iron. . . . . . . . . . . . . . . . . . . . Date Chem-Lab Ref. Number Approved By Location Sample From 1047832002__ ~ ~1 ,Q)ll '\.. \\ 1 1> \þ ... ....1/ ._" Y...._w . .." _'" ..._m, .' "'.,_. . ~ .-'.. .."_."\\,f'",. ....y/--_....-. ., '~.N·· .>...._ ,,v."... Meo.lL 180.90 36.58 20.04 1.59 0.11 Anions moIL MeQ .IL 0.61 232.83 0.00 10.00 0.0 Sulfate. . . . . . . . . . .. 29.2 Ch{oride . . . . . . . . . .. 8280 Carbonate . . . . . . . . . . . . . . . Bicarbonate . . . . . . . . 500 Hydroxide. . . . . . . . . . . . . . . . Total Anions. . . . . . ., 243.442 ----- .. ". "'__'V 1.'_',.. _Y. .....,w·w. -"/'" ~._....._, . ",.. Total Cations. . . . . . . . . . . . . 239.22 NV . I Total dissolved solids. . . . .. 14619 -- NaCI equivalent (chloride) 14438 Observed pH . . . . . . . . . . . . 9.19 II v·..·",,"... . "'1'" .. \l. .'" .....-..... , ,- ... .. ,......-. mg/L mg/L Specific Resistance@ 68° F.: Observed. . .. . . . . . . . . Calculated. . . . . . . . . . . . 1.25 ohm-meters 0.49 ohm-meters Barium. . . . . . . . . . . . . . . . . . . . mg/L Strontium. . . . . . . . . . . . . . . . . . . . mg/L Total Iron . . . . . . . . . . . . . . . . . . . . mg/L Water Analysis Pattern Scale: Milligram equivalents per Unit .).0 I~ I C, {If 11- (0 'is lø 'f :¡. V .;). t.f iP ß' 10 2.fc.( lIP (ß ~ ¡ I ! I ¡: I ¡ Na 6~/00 i i ¡ i ! i -j{X lOb) CI ~~.3 i j T ¡ Ii' -- ! ! ! Ca (YJO) =--j~ i -' ~X!b~C03 _L.() ò ! I ¡ ! I MglKI) ~ I ! I i i Fe (tt) Ii: L_~j ~.()D I~ Q.dl ,\ I I .. (XI )504~~( J (x., JC03 X (Na value in above graphs includes Sodium. Potassium and L 1 ) NOTE: mg/L = Milligrams per liter. Meq.lL = Milligram equivalent per liter. Soldium Chloride equivalent = by Dunlap & Hawthorne calculation from components. . _._.~~-_.__...--_.....---- ~ '--- SGS Ref.# 1047832003 All Dates/Times are Alaska Standard Time Client Name Forest Oi I Corporation Printed Date/Time 12/20/2004 13:24 Project Name/# West Forland #2 Collected Date/Time 11/28/2004 0:00 Client Sample ID Spl 2 WF#2 10725 Received Dateffi~ 12/0312004 12:36 Matrix Water (Surface, Eff., Ground) Technical Directo Stephen C. Ede Released By ',~ Sample Remarks: \J Resistivity, pH - sample was received after holding time had expired. Results PQL Units Method Container ID Allowable Prep Analysis Parameter Limits Date Date Init % Difference 6.5 % SM20 1030E A 12/17/04 KAL Routine Oilfield Water Analysis Alkalinity 2200 10.0 mgIL SM20 2320B A 12/10/04 KP Chloride 8200 100 mgIL EP A 300.0 A 12/15/04 BJA C03 Alkalinity 10.0 U 10.0 mgIL SM202320B A 12/10/04 KP HC03 Alkalinity 2200 10.0 mgIL SM20 2320B A 12/1 0/04 KP OH Alkalinity 10.0 U 10.0 mglL SM20 2320B A 12/10104 KP pH 7.65 0.100 pH units EPA 150.1 A 12/09/04 KP Resistivity 0.370 0.01 00 ohm-m SM192510A A 12/09/04 KAL Sulfate 27.7 5.00 mglL EP A 300.0 A 12/08/04 BJA Metals Department Barium 14.3 0.100 mglL EP200.7 Dissolved A 12/14/04 12/16/04 BAG Calcium 267 2.00 mglL EP200.7 Dissolved A 12/14/04 12116/04 BAG Iron 1.70 0.400 mglL EP200.7 Dissolved A 12/14/04 12/16104 BAG Sodium 4720 200 mglL EP200.7 Dissolved A 12/14/04 12/16/04 BAG Strontium 23.5 0.100. mglL EP200.7 Dissolved A 12/14/04 12/16/04 BAG Magnesium 32.1 2.00 mglL EP200.7 Dissolved A 12/14/04 12/16/04 BAG Metals by ICP!MS Potassium 818000 200000 ug/L EP200.8 Dissolved A 12/14/04 12/17/04 WAW __ _ _.._._·__·.m._______·___·_·'·. -----~...-._----~~----,_. .~ Routine Oil Field Water Analysis Report Operator Well Number Field County State Remarks and conclusions: Date Chem-Lab Ref. Number Approved By Location Sample From 1047832001~\ \\'Î \ ,\ \ð Cations .....--.^ ..''''N~~W_W v__.... ......." . ,··W.... ..... ......,,,,,, ".. '''''' mQ/L , .. Sodium . . . . . . . . . . . . . . . . . Potassium . . . . . . . . . . . . . . Calcium. . . . . . . . . . . . . . . . Magnesium . . . . . . . . . . . . . Iron. . . . . . . . . . . . . . . . . . . . moIL 4722.9 818 267.18 32.077 1.7015 '..^','.' .-~·..I_^ ,...., o ,_-.____.. . .......,.. J' ^ '" 'of ...."'."..... I~' " ..... -_v...... .....----..----. Meq.lL 205.45 20.92 13.33 2.64 0.06 Anions Meq .IL 0.58 230.58 0.00 44.00 -- 0.0 Sulfate. . . . . . . . . . .. 27.7 Chloride. . . . . . . . . .. 8200 Carbonate . . . . . . . . . . . . . . . Bicarbonate. . . . . . .. 2200 Hydroxide. . . . . . . . . . . . . . . . Total Cations. . . . . . . . . . . . . 242.40 Total Anions. . . . . . .. 275.161 ........ ....-....~.....--...._------., ". .... .,..^.. ·,.__...,''''''''.·._·^·...____HH_'..._~_~^'w".___,.^...._,...y.."...................___ ___"..___,_.... .'1.,_,' ~"". ,··'__...-__NOHNIOW""v____.N-<_ ......., ...... _. , ____"''''~'___,HN<tN'''_''''No___....._.,_..,¿_N'___~'_.,._w<.,,,..."''w_.W.'''''N'''. Total dissolved solids. . . . .. 15388 NaCI equivalent (chloride) 14667 Observed pH . . . . . . . . . . . . 7.65 mg/L mg/L Specific Resistance @ 68° F.: Observed . . . . . . . . . . . . Calculated. . . . . . . . . . . . 0.37 ohm-meters 0.48 ohm-meters Barium. . . . . . . . . . . . . . . . . . . . mg/L Strontium. . . . . . . . . . . . . . . . . . . . mg/L Total Iron . . . . . . . . . . . . . . . . . . . . mg/L Water Analysis Pattern Scale: Milligram equivalents per Unit .,20 15 Ifd It.(- 10 ß " t.f J,. 0 J. Lf {¿, 5 II) 12.. 'f 1ft? 16 ;2:.D H , ;! i: (I<II>Ò) CI__~~_3 \ ¡l)(~ ).JC03~~ð ¡ --+-- ! Mg (XI) ¡ i ! \ ~-H .1 ;. (I, Fe ('(( ') b~---H !! I ~._~,{LC;- 1~.3J ~!t.d D->-é1c - I ,(XI) 804 -º-~.~ : ¡ ¡ I ! -¡----t---T"---! ( ) CO 3 7Y' ; ! I ¡ Xf --.p- (Na value in above graphs includes Sodium, Potassium and L 1) NOTE: mg/L = Milligrams per liter, Meq.lL = Milligram equivalent per liter. Soldium Chloride equivalent = by Dunlap & Hawthorne calculation from components. '---' SGS Ref.# Client Name Project Name/# Client Sample [0 Matrix 1047832004 Forest Oil Corporation West Forland #2 Spl3 WF#2 10725 Water (Surface, Eff., Ground) All Dates/Times are Alaska Standard Time Printed Date/Time 12/20/2004 13 :24 Collected Date/Time 11128/2004 0:00 Received Date/Time 12/03/2004 12:36 Technical Directo~. SteP.h.en. c.... Ede Released By ..f!~-', ~__,_. ¡ (I" ~ f j \ Sample Remarks: Resistivity, pH - sample was received after holding time had expired. Parameter Results PQL Units Method Allowable Container ID Limits Prep Date Analysis Date lnit % Difference 9.8 % SM20 1030E A 12/17/04 KAL Routine Oilfield Water Analysis Alkalinity Chloride C03 Alkalinity RC03 Alkalinity OR Alkalinity pR Resistivity Sulfate 700 10.0 mgIL SM20 2320B A ] 2/1 0104 KP 23900 100 mglL EPA 300.0 A ]2/08/04 BJA ]00 10.0 mgIL SM20 2320B A 12/]0/04 KP 600 10.0 mglL SM20 2320B A 12/l 0/04 KP ]0.0 U 10.0 mgIL SM20 2320B A 12/10/04 KP 8.95 0.100 pH units EPA 150.1 A ] 2/09/04 KP 0.125 0.0100 ohm-m SM192510A A 12/09/04 KAL 90.0 5.00 mglL EPA 300.0 A 12/08/04 BJA Metals Department Barium Calcium Iron Sodium Strontium Magnesium 1.01 0.100 mglL EP200.7 Dissolved A 12/14/04 12/16/04 BAG 77.0 2.00 mglL EP200.7 Dissolved A 12/14/04 12/16/04 BAG 00400 U 0.400 mglL EP200.7 Dissolved A 12/14/04 12/16/04 BAG 463 20.0 mgIL EP200.7 Dissolved A 12/14/04 12/l6/04 BAG 0.986 0.100 mglL EP200.7 Dissolved A 12/14/04 12/16/04 BAG 6.57 2.00 mglL EP200.7 Dissolved A 12/14/04 12/16/04 BAG Metals by ICP/MS Potassium 21200000 200000 uglL EP200.8 Dissolved A 12/14/04 12/l7/04 W A W "----.-----.--..- . c~ Routine Oil Field Water Analysis Report Operator Well Number Field County State Remarks and conclusions: ._._-~-- --- '_(_"'_"'~__'_"_H_______"___ ""'-___N....· . ~,... ... ~...... .w...__.\ v, Cations mQ/L 462.77 21200 76.952 6.5676 0.0502 Sodium. . . . . . . . . . . . . . . . . Potassium. . . . . . . . . . . . . . Calcium. . . . . . . . . . . . . . . . Magnesium. . . . . . . . . . . . . Iron. . . . . . . . . . . . . . . . . . . . Date Chem-Lab Ref. Number Approved By Location Sample From 1047832004) J~ '-i".2{ \11l>~ \ ')¡\ ... . _........--·____~,,~___"".¡"''oNNwMW....d·...... .."J"vw...., ., ..._ ...__ .... _.."""'___ .....-, ." V··~"'.. ___ ·..··v,_.....-.. -.... '-'''A MeQ./L Anions MeQ./L mQ/L 20.13 542.30 3.84 0.54 0.00 Sulfate. . . . . . . . . . .. 89.95 Chloride. . . . . . . . . . . 23899 Carbonate . . . . . . . . . 100 Bicarbonate . . . . . . . . 600 Hydroxide. . . . . . . . . . . . . . . . 1.87 672.04 2.00 12.00 0.0 Total Anions. . . . . . .. 687.913 Total Cations. . . . . . . . . . . . . 566.81 . . . .., . ____H__.-'· . , . . ._----=.~-:-----::--:--"':"-"',.---::'...... Total dissolved solids. . . . .. 46095 NaCI equivalent (chloride) 45981 Observed pH . . . . . . . . . . . . 8.95 mg/L mg/L Specific Resistance @'68° F.: Observed. . . . . . . . . . .. 0.125 ohm-meters Calculated. . . . . . . . . . .. 0.16 ohm-meters Barium. . . . . . . . . . . . . . . . . . . . mg/L Strontium. . . . . . . . . . . . . . . . . . . . mg/L T otall ron . . . . . . . . . . . . . . . . . . . . mg/L Water Analysis Pattern Scale: Milligram equivalents per Unit ¿ If, lip 14 ,2.. 10 5 (, 'I .). 0 ;¿ &of (p $ ,0 ,¿ ,t.J '(p Iß ~þ F·J : :: I Ii: ¡: ¡: j Na(X/JJn-+-1_: ¡ , ! ¡ '!;! !(X'lbb) CI_{P~7~ rl----j I j WI ¡Ii !. : I I I . ¡----)I I .. l Ca (X/O) r-f- i .! I' (x/~)HC03 __Ld 0 _I I Q.~2Q1 O~;3~t D,S~ Mg(X/) d- !---I ~ : I I I Fe (X ì)W-i ~ i 1{~(I) 504 _Lß7 ! , I I ----1-~ ¡ ¡ ¡ 'XI) C03 ~ I -¡--¡~ _& _Dv (Na value in above graphs includes Sodium, Potassium and L1) NOTE: mg/L = Milligrams per liter, Meq.lL = Milligram .equivalent per liter. Soldium Chloride equivalent = by Dunlap & Hawthorne calculation from components. ~ ,-". ..~ SGS Ref.# 1047832005 All Dates/Times are Alaska Standard Time Client Name Forest Oil Corporation Printed Date/Time 12/20/2004 13:24 Project Name/# West Forland #2 Collected DatelTime 11/28/2004 0:00 Client Sample ID Sp14 WF#4 10725 Received DatelTi~. 12103/2004 12:36 Matrix Water (Surface, Eff., Ground) Technical Directo Stephen C. Ede ßiJð Released By ¡r¡)1; Sample Remarks: \ Resistivity, pH - sample was received after holding time had expired. Results PQL Units Method Container ID Allowable Prep Analysis Parameter Limits Date Date Init % Difference 6.2 % SM20 1030E A 12/17/04 KAL Routine Oilfield Water Analysis Alkalinity 2300 10.0 mgIL SM202320B A 12/1 0104 KP Chloride 8320 20.0 mglL EPA 300.0 A 12/09/04 BJA C03 Alkalinity 10.0 U 10.0 mglL SM20 2320B A 12/10/04 KP HC03 Alkalinity 2300 10.0 mglL SM20 2320B A 12/1 0/04 KP OH Alkalinity to.O U to.O mglL SM20 2320B A 12/10104 KP pH 7.62 0.100 pH units EPA 150.1 A 12/09/04 KP Resistivity 0.370 0.0100 ohm-m SM192510A A 12/09/04 KAL Sulfate 27.5 5.00 mglL EP A 300.0 A 12/08/04 BJA Metals Department Barium 20.3 0.100 mglL EP200.7 Dissolved A 12/14/04 12/16/04 BAG Calcium 357 2.00 mgIL EP200.7 Dissolved A 12/14/04 12/16/04 BAG Iron 2.34 0.400 mglL EP200.7 Dissolved A 12/14/04 12/16/04 BAG Sodium 4770 200 mglL EP200.7 Dissolved A 12/14/04 12/16/04 BAG Strontium 30.8 0.100 mglL EP200.7 Dissolved A 12/14/04 12/16/04 BAG Magnesium 40.1 2.00 mglL EP200.7 Dissolved A 12/14/04 12/16/04 BAG Metals by ICP/MS Potassium 773000 200000 uglL EP200.8 Dissolved A 12/14/04 12/17/04 W A W '~ '-' Routine Oil Field Water Analysis Report Operator Well Number Field County State ---- Remarks and conclusions: .__.~--.- ---..........-..----,.,"'-......._....'_.1.··'_" ....__"H'''"'''".'''·__'''".,.,.,..__,_.._v_____...'''''''''__..,. Cations mq/L 4768.5 773 356.73 40.134 2.335 Sodium. . . . . . . . . . . . . . . . . Potassium . . . . . . . . . . . . . . Calcium. . . . . . . . . . . . . . . . Magnesium . . . . . . . . . . . . . Iron. . . . . . . . . . . . . . . . . . . . Date Chern-Lab Ref. Number Approved By Location Sample From 1 047832005 ^ )~. J -1. :.Y, 1 , D\ \1., \ . ";' ,,~. ._,'" ....._~. .··..·..v·__ . .. "'-"'~--'-""'^---~__~""""""'_IWW'_ WN__~""_",''''N__",,_,___. Meq./L 207.43 19.77 17.80 3.30 0.08 An ions Meq.lL 0.57 233.88 0.00 46.00 0.0 mQ/L Sulfate. . . . . . . . . . .. 27.45 Chloride. . . . . . . . . .. 8317 Carbonate. . . . . . . . . . . . . . . Bicarbonate. . . . . . .. 2300 Hydroxide. . . . . . . . . . . . . . . . ....""_"'...._.,. ";' I.·... ______._. __..",_..... ..··..;.V·\'I_,'''-I"" Total Cations. . . . . . . . . . . . . 248.39 . ·'v... Total dissolved solids. . . . .. 15663 NaCI.equivalent (chloride) 14913 Observed pH . . . . . . . . . . . . 7.62 Total Anions. . . . . . " 280.451 ......." ,.......--,,-___..._ ........., "W''¥·_.'_NW_ ..... ·,~..-"..I...._- mg/L mg/L Specific Resistance @ 68° F.: Observed. . . . . . . . . . . . Calculated . . . . . . . . . . . . 0.37 ohm-meters 0.47 ohm-meters Barium. . . . . . . . . . . . . . . . . . . . mg/L Strontium. . . . . . . . . . . . . . . . . . . . mg/L Total Iron . . . . . . . . . . . . . . . . . . . . mg/L Water Analysis Pattern Scale: Milligram equivalents per Unit .Jo 16 110 /2 1'0 ß (,p 4 ~ 0 r:2 " It:? g Jþ 11.. ,,, If; /'6 ~:t> I I 'I I' I I I ' ". ! '" I_.n ¡, I j I ¡ ! ¡ Na(X/cé)t1 .. i ¡ ¡ 1 i i i(~b6) CI_~~:3t ---¡--¡ j i ~-,--~7 1-:_25 ! : ~i I ("\1--,1 I Ca X/OJ 1__1 ¡ i ' [------j- I t=-- ! Mg(x/)r- i I I I I ! I Fe (,~I ) ¡ ! 3.3D O-LO ß I I (X/)C03 $ ~X/~HC03 ß..!-fo'D i I I I (XI) 504 ~S7 (Na value in above graphs includes Sodium, Potassium and L 1 ) NOTE: mg/L = Milligrams per liter, Meq.lL = Milligram equivalent per liter. Soldium Chloride equivalent = by Dunlap & Hawthorne calculation from components. ~t~ CHAIN OF CUSTODY RECORD CT&E Environmental Services Inc. Laboratory Division r .....'ll/If. -- - "....-illllf.. ßIíY.. JilU6Ø.IIJY.,...... iWII 1IlØ".,..,...ØII, - . No. SAMPLE Preservatives Used TYPE C 0 C= N COMP T A G= I GRAB N , E R MATRIX S Œ CUENT: Fo(~v- ¡J (. CONTACT: ß;e,tp /f}e{{(;- PHONE NO: <16? ) l6! -2(3£ PROJECT: (;t.1JJ.ì Fa /2(:(',fJ-'~ #- 2... PWSID#: I REPORTS TO: 6itJ IJttjl~ ~/'" r¿;elif/'T" VI L ~/v /<.f ì S1t17F ?c).> '. ~ y tit .At , 1'1 ~ , FAX NO: <'to? ) :t- f)~ -K 60 J INVOICE TO: ]/0 Ie. .£ u ( í"lr ? I) ~ QUOTE# A J-'4of /J--r , C¡'1~ ) P.O. NUMBER: CT&E Reference: (2) LAB NO. SAMPLE IDENTIFICATION DATE TIME _~A '[~ ,@~ j~1) ß Lufd Z I~ l.;' If ItYd/ ::;.1 J fÞf #- L I ~11..)- fll2f1I)"J . ~t?~ (;...;('2-.1/.2.. (Q'7 ¿T II /2tI t7) ~I #1 (,v rfi? (f,)1'l.s- <t!<f1<:l7 _'}-t tf:« lvf4f14: / <:/7'L.)- (f!LKIfJ'? ~ . r Collected/Relinquished By: (1) /3t.4/d j:Á k~ Relinquis~ By: (2) Date Received By: ~ R~ ~--- Relinquished By: (3) ~ . Received By: I' RennqulshedB~_ tÿv ;;~ ~e~ . (fl.';. ~\¿~ 200 W. Potter Drive Anchorage, AK 99518 Tel: (907) 562-2343 ax: 1) 5~301 3180 peger Road Fairbanks, AK 99701 Tel: (907) 474-865 . 07) 4~9685 Time I¿"j t·, '-.51 " /:Þ,~ Time Date 1047832 PAGE OF 1 'A ~ rj., ~ 1"4" - '-.;.,/ Shipping Carrier: Shipping Ticket No: Data Deliverables: REMARKS ] ( I Temperature C: Levell Levell! Levellll EDD Type: Chain of Custody Seal: (Circle) INTACT BROKEN ABSENT Requested Turnaround Time and Special Instructions: White· Retained by Lab (Project File) Yellow ~ Returned with Report No NA .....c::::: _ Are samples RUSH, priority, or wIn 72 hrs. of hold time? Due Date: /2..- 14--0 'f _ -Llf yes have you done e-mail notification? Received Date: 12 -?- c'"}<{ ~ _ Are samples within 24 hrs. of hold time or due date? Received Time: (2.. 'J '=. .. \ ,,- If yes, have you spoken with Supervisor? . Is date/time conversion necessary? {'\J = ""'-Archiving bottles- if req., are they properly marked? # of hours to AK Locallimef " - /' Are there any problems? PM Notified? Thermometer ID: Ic.t~ I.. t.."-~ . _--C:.. Were samples preserved correctly and pH verified? Cooler 10 Temp Blank Cooler Temp .______ °C °C ______ °C °C _______ 0C °C ~ °C °C ______oC -....... . -Temperature readings include thermometer ~~ .factors Delivery method (circle all that applyt: ~ Alert Courier I UPS I fedEx I USPS I AA Goldstreak I NAC I ERA I PenAir I Carlile Lynden I SGS I Other: Airbill # Additional Sample Remarks: (..J if applicable) Extra Sample Volume? Limited Sample Volume? Field preserved for volatiles? . _uEield~.filtered..fo.Ldissolved? Lab-filtered for dissolved? Ref Lab requked? Foreign Soil? I ~~~ SAMPLE RECEIPT FORM· Yes _ ~If this is for PWS, provide PWSID. --C... _ Will courier charges apply? Method of payment? -.:::: _ Data packag~ required? (Level: 1 I ~ I 3 I 4) Notes: ~ _ Is this a 000 project? (USACE, Navy, AFGEE) Th1s;.s~Ctio,;.:iiì~~t.béfÙJed·~ut:forDOLJÎJroj~cÙr(.ilSÅeE,'.l!åf;y~ÅFCEE),' Yes,<:~' NQ. ," ' '.. . ' . ~ :'I~;'fete'iv~ª.teojpe..at\1re4:±2~¢? '" > >'ÉÌ\ê,~pïio~,:; ..... " 'saW~liiSf~~~S;Äffecte¡(: .::/,.,;.,.; , , .' ,---- -.:.' ,~:d·'$êr~~~(,pe.tfò~êg?"".· 'W';'~e~;1~ÌÎl>iil1' ...... . ,{lfpie¡f'~~!¡":l¥rw;,~""iúinñi< . ,. ...W;c,O~ler'S~aJ~ð~iWC~~Y~S?': . .... . .. .. , ..,," " . -::-.:" .~..." :\¥ere.,co!'fect,contáÙJeI'.ï~ampte sjZes;s*biµitted?>. ,"': Issample:èoIlditi°Il&OOö?'··,".':' ' ""'",, ," »:" ;Was':c()pY:.;ofG~;:SlU1;'~~·Çpst94y:s~ål$?giY:e~::~?;~~..~J~1'·;'j: -. .--:..:.- ..>.", ~.-:.: ...,_"'¡_..~._:"_i· ,-' ,.......;......, Notes: (print): performed ,by: 1047832 '-' SGS WO#: -"'.. ,:~ ,. ." "." '"' .... :: .' ~. .;,::. . -..-".. . . This sectió-"'mùstbefilledifDroblems arelound. ". Y~L~lIiYl#.fIi~?triotlfieð:'OfP,fObl~mS? .... ".'~"- ~ ." ,;. 'Jri4i\iiêJÎ1á);"c~þt~~t~~: ..... ." 'Yia: .. ',ehºµ¢JF~>tEi11ai1 "Ð~eJTjffiêL" ,.: .:,"" ." .:Re8s.()nfqt,c()µ~ct:··:u '. (circle'one) .' ~. " .,",._.1.'-:- . :.. ...., , '. , " .",. .'~ - ,",::, :~ . :,' ',-. . !:"': '~:.. ". . '~7 ~lv~ Fonn# FOO4r14: 05/17/04 ~( # Q - ~ u .5 .e § u l-? A SAMPLE RECEIPT FORM (page 2) Container Volume U ~ ..J ~ ~ ..J ...J ...J ~ ~ Other 0 0 (y e e e e e '< u 0 0 II') 0 0 0 VI 0 VI ~ \0 'I:t In M VI N t!- - "-' N N 0 0 00 'I:t ? .~ ~ ~ Test b (ZD F w Bottle Totals 7 r \ \petra \public\DOCUMENT\FORMS\approved\SRF ...F004r 14.doc Container Ty-,e r,¡; U u:.:::.e Other Q.c 5 :E 0 c.. §~8u~ z ,Y: 1047832 SGS WON: Preservative ~ ü ÔÒ::r: Ô::r: o:I:æCf.)O NO Z NUCf.) ~ ::r: :E £ Z Z ¡c. ( '1 _.."...- c::> Y Date: t:7" r Form # F004r14 : 05/17/04 Other ( ..,/ "-' EG&G Ch~ndler Engineering Model 292 BTU Analyzer Test time: Dec.14 04 16:28 Test #:3 Methane Ethane Propane i-Butane ( C6+ ) Moisture Nitrogen ( C02 ) ___ Standard/Dry Analysis Mole% BTU* R.Den.* GPM** 93.524 946.80 0.5181 0.400'7.09 0.0042 0.112 2.81 0.0017 0.020 0.65 0.0004 0.015 0.77 0.0005 0.000 0.00 0.0000 5.398 0.00 0.0522 0.531 0.00 0.0081 0.1069 0.0308 0.0065 0.0065 "-'" Calibratíon #: 1 Location NO. :9200 Saturated/Wet Analysis Mole~ BTU* R.Den.* 91.896 930.33 0.5090 0.393 6.97 0.0041 0.110 2.77 0.0017 0.020 0.64 0.0004 0.015 0.76 0.0005 1.740 0.88 0.0108 5.304 0.00 0.0513 0.522 0.00 0.0079 Total 100.00 958.1 0.5851 0.1508 100.00 * . Uncorrected for compressibility at 60.0F & 14.730PSIA. **: Liquid Volume reported at GO. OF. Standard/Dry Analysis Molar Mass = 16.945 Relative Density = 0.5860 Compressibility Factor 0.9981 Heating Value 21408. Btu/lb Heating Value = 960.0 Btu/CF Absolute Gas Density = 44.8423 Ibm/1000CF Wobbe Index ~ 1233.54 Unnorrnalized Total 101.654 Last Calibrated with Calgas of C6+ Last Update: GPA 2261-90. C6+ BTU/CF 5065.8, C6+ Ibm/Gal 5.64250, and C6+ Mol.Wt. 1057.2 Btu/CF FOREST OIL West Forelands #2 9200 Pressure: Sample Date: 12/13/04 Run Date: 12114/04 Sample #1 RUN 1 942.3 0.5857 Saturated/Wet Analysis 16.964 0.5867 0.9980 21032. Btu/lb 944.2 Btu/CF 44.8962 Ibm/1000CF Dec.15 03 07:26 92.00. '~ EG&G Chandler Engineering Model 292 BTU Analyzer Test time: Dec.14 04 16:41 Test. #:4 Methane Ethane' Propane i-Butane ( C6+ ) Mo,isture Nitrogen ( C02 ) ___ Standard/Dry Analysis Mole% BTU* R.Den.* GPM** 93.518 946..,74 0.5180 0.389 ·'6.90 0.0040 0.108 2.73 0.0017 0.020 0.67 0.0004 0.015 0.74 0.0005 0.000 0.00 0.0000 5.426 0.00 0.0525 0.524 0.00 0.0080 0.1041 0.0299 0.0067 0.0063 ..~ Calibration #: 1 Location No. :9200 Saturated/Wet Analysis Mole% BTU* R.Den.* 91.891 930.27 0.5090 0.382 6.78 0.0040 0.106 2.69 0.0016 0.020 0.65 0.0004 0.014 0.73 0.0005 1.740 0.88 0.0108 5.331 0.00 0.0516 0.515 0.00 0.0078 Total 100.00 957.8 0.5850 0.1469 100.00 * : Uncorrected for compressibility at 60.0F & 14.730PSIA. **: Liquid Volume reported at 60.0F. Standard/Dry Analysis Molar Mass = 16.944 Relative Density = 0.5859 Compressìbility Factor = 0.9981 Heating Value ~ 21402. Btu/lb Heating Value 959.6 Btu/CF Absolute Gas Density ~ 44.8384 Ibm/1000CF Wobbe Index ~ 1233.14 Unnormalized Total: 101.472 Last Calibrated with Calgas of C6+ Last. Update: GPA 2261-90. C6+ BTU/CF 5065.8, C6+ lbm/Gal 5.64250, and C6+ Mol.Wt. 1057.2 Btu/CF FOREST OIL West Forelands #2 9200 Pressure: Sample Date: 12/13/04 Run Date: 12/14/04 Sample #1 RUN2 942.0 0.5857 Saturated/Wet Analysis 16.962 0.5866 0.9980 2l026. Btu/lb 943.9 Btu/CF 44.8924 Ibm/1000CF Dec.15 03 07:26 92.00. Clear/Default Data for: EG&G BTU Analyzer - EG&G Chandler Engineering Model 292 BTU Analyzer Test time: Dec.14 04 14:25 Test #:1 Methane Ethane Propane i-Butane ( C6+ ) Moisture Nitrogen ( C02 ) ___ Standard/Dry Analysis Mole% BTU* R.Den.* GPM** 93.468 946.24 0.5177 0.403 7.l5 0.0042 0.112 2.81 0.0017 0.022 0.71 0.0004 0.009 0.46 0.0003 0.000 0.00 0.0000 5.451 0.00 0.0527 0.536 0.00 0.0081 0_l078 0.0307 0.0071 0.0039 -..-J Calibration #: 1 Location No. :9200 Saturated/Wet Analysis Mole% BTU* R.Den.* 91.842 929.77 0.5087 0.396 7.03 0.0041 0.110 2.76 0.0017 0.021 0.69 0.0004 0.009 0.45 0.0003 1.740 0.88 0.0108 5.356 0.00 0.0518 0.526 0.00 0.0080 941.6 0.5858 Total 100.00 957.4 0.5852 0.1495 100.00 * : Uncorrected for compressibility at 60-0F & 14.730PSIA. **: Liquid Volume reported at 60.0F. Standard/Dry Analysis Molar Mass = 16.949 Relative Density 0_5861 Compressibility Factor 0.9981 Heating Value 21386. Btu/lb Heating Value 959.2 BtujCF Absolute Gas Density ~ 44.8527 lbm/l000CF Wobbe Index 1232.40 Unnormalized Total: 99.581 Last Calibrated with Calgas of C6+ Last Update: GPA 2261-90. C6+ BTU/CF 5065.8, C6+ Ibm/Gal 5.64250, and C6+ Mol.Wt. 1057.2 Btu/CF -"'-"- '--'" FOREST OIL West Forelands #2 Lower 9200 Pressure: Sample Date: 12/12/04 Run Date: 12/14/04 Sample #2 RUN 1 Saturated/Wet Analysis 16.968 0.5868 0.9980 21010. Btu/lb 943.5 BtujCF 44.9065 Ibm/lOOOCF Dec.:L5 03 07:26 92.00. "-~./ EG&G Chandler Engineering Model 292 BTU Analyzer Test time: Dec.14 04 14:50 Test #:2 Methane Ethane Propane i~Butane ( C6+ ) Moisture Nitrogen ( C02 ) ___ Standard/Dry Analysis Mole% BTU* R.Den.* GPM** 93.597 947.54 0.5185 0.399 7.07 0.0041 0.110 2.78 0.0017 0.021 0.69 0.0004 0.009 0.46 0.0003 0.000 0.00 0.0000 5.341 0.00 0.0517 0.523 0.00 0.0079 0.1066 0.0304 0.0069 0.0039 Calibration #: l Location No. :9200 Saturated/Wet Analysis Mole~ BTU* R.Den.* 91.968 931.05 0.5094 0.392 6.95 0.0041 0.108 2.73 0.0016 0.021 0.67 0.0004 0.009 0.46 0.0003 1.740 0.88 0.0108 5.248 0.00 0.0508 0.514 0.00 0.0078 942.7 0.5852 Total 100.00 958.5 0.5846 0.1478 100.00 * . Uncorrected for compressibility at 60.0F & 14.730PSIA. **: Liquid Volume reported at 60.0F. Standard/Dry Analysìs Molar Mass ~ 16.931 Relative Density ~ 0.5855 Compressibility Factor ~ 0.9981 Heating Value 21434. Btu/lb Heating Value 960.4 Btu/CF Absolute Gas Density = 44.8057 Ibm/1000CF Wobbe Index = 1234.57 Unnorrnalized Total 99.859 Last Calibrated with Calgas of C6+ Last Update: GPA 2261-90. C6+ BTU/CF 5065.8/ C6+ Ibm/Gal 5.64250r and C6+ Mol.Wt. 1057.2 Btu/CF FOREST OIL West Forelands #2 Lower 9200 Pressure: Sample Date: 12/12/04 Run Date: 12/14/04 Sample #2 RUN2 Saturated/Wet Analysis 16.950 0.5862 0.9980 21058. Btu/Ib 944·.6 Btu/CF 44.8603 lbm/1000CF Dec.15 03 07:26 92.00. \, ~ EG&G Chandler Engineering Model 292 BTU Analyzer Test time: Dec.14 04 15:08 Test #:1 Methane Ethane Propane i-Butane ( C6+ ) Moisture Nitrogen ( C02 ) ___ Standard/Dry Analysis Mole% BTU* R.Den.* GPM** 94.241 954.06 0.5220 0.355 6.30 0.0037 0.124 3.13 0.0019 0.021 0.70 0.0004 0.013 0.67 0.0004 0.000 0.00 0.0000 4.696 0.00 0.0454 0.549 0.00 0.0083 0.0950 0.0342 0.0070 0.0057 ~ CONFIDENTIAL Calibration #: 1 Location No. :8500 Saturated/Wet Analysis Mole% BTU* R.Den.* 92.601 937.46 0.5129 0.349 6.19 0.0036 0.122 3.08 0.0019 0.021 0.68 0.0004 0.013 0.66 0.0004 1.740 0.88 0.0108 4.615 0.00 0.0446 0.539 0.00 0.0082 Total 100.00 964.9 0.5822 0.1418 100.00 * ; Uncorrected for compressibility at 60.0F & 14.730PSIA. **: Liquid Volume reported at 60.0F. Standard/Dry Analysis Molar Mass 16.862 Relative Density 0.5831 Compressibility Factor 0.9981 Heating Value 21664. Btu/lb Heating Value 966.7 Btu/CF Absolute Gas Density ~ 44.6236 lbm/l000CF Wobbe Index ; 1245.24 Unnormalized Total: 100.534 Last Calibrated wìth Calgas of C6+ Last Update: GPA 2261-90. C6+ BTU/CF 5065.8, C6+ lbm/Gal 5.64250, and C6+ Mol.Wt. 1057.2 Btu/CF FOREST OIL West Forelands #2 8500 Pressure: Sample Date: 12/13/04 Run Date: 12/14/04 Sample #4 RUN 1 948.9 0.5829 Saturated/Wet Analysis 16.882 0.5839 0.9980 21281. Btu/lb 950.9 Btu/CF 44.6814 lbm/1000CF Dec.15 03 07:26 92.00. IØ . .. .... '-- EG&G Chandler Engineering Model 292 BTU Analyzer Tèst time: DeC.l4 04 15:28 Test #:2 Methane Ethane Propane i-Butane ( C6+ ) Moisture Nitrogen ( C02 ) ___ Standard/Dry Analysis Mole% BTU* R.Den.* GPM** 94.221 953.86 0.5219 0.359 6.36 0.0037 0.128 3.23 0.0020 0.023 0.76 0.0005 0.017 0.88 0.0006 0.000 0.00 0.0000 4.705 0.00 0.0455 0.546 0.00 0_0083 0.0960 0.0353 0.0076 0.0075 ~ Calibration #: 1 Location No. :8500 Saturated/Wet Analysis Mole% BTU* R.Den.* 92.582 937.26 0.5128 0.353 6.25 0.0037 0.126 3.17 0.0019 0.023 0.74 0.0005 0.017 0.87 0.0005 1.740 0.88 0.0108 4.623 0.00 0.0447 0.537 0.00 0.0082 949.2 0.5831 Total 100.00 965.1 0.5824 0.1463 100.00 * : Uncorrected for compressibility at 60.0F & 14.730PSIA. **: Liquid Volume reported at 60.0F. Standard/Dry Analysis Molar Mass 16.868 Relative Density 0.5833 Compressibility Factor 0.9981 Heating Value 21662. Btu/lb Heating Value 967.0 Btu/CF Absolute Gas Density 44.6394 Ibm/1000CF Wobbe Index ~ 1245.33 Unnormalized Total: 99.637 Last Calibrated with Calgas of C6+ Last Update: GPA 2261-90. C6+ BTU/CF 5065.8/ C6+ Ibm/Gal 5.64250, and C6+ Mol.Wt. 1057.2 Btu/CF , ,-.. -- .--- FOREST OIL ·West Forelands #2 8500 Pressure: Sample Date: 12/13/04 Run Date: 12/14/04 Sample #4 RUN2 Saturated/Wet Analysis 16.888 o . 5841 0.9980 21279. Btu/lb 951.1 Btu/CF 44.6969 Ibm/1000CF Dec.15 03 07:26 92.00. ~ EG&G Chandler Engineering Model 292 BTU Analyzer Test time: Dec.14 04 15:52 Test #:3 Methane Ethane Propane i-Butane ( C6+ ) Moisture Nitrogen ( C02 ) ___ Standard/Dry Analysis___ Mole% BTU* R.Den.* GPM** 93.907 950.68 0.5202 0.346 6.14 0.0036 0.114 2.86 0.0017 0.016 0.54 0.0003 0.007 0.35 0.0002 0.000 0.00 0.0000 5.083 0.00 0.0492 0.527 0.00 0.0080 0.0925 0.0313 0.0054 0.0029 '"'-" Calibration #: 1 Location No. :8500 Saturated/Wet Analysis Mole% BTU* R.Den.* 92.273 934.14 0.5111 0.340 6.03 0.0035 0.112 2.81 0.0017 O.Ol6 0.53 0.0003 0.007 0.34 0.0002 1.740 0.88 0.0108 4.994 0.00 0.0483 0.518 0.00 0.0079 Total 100_00 960.6 0.5832 0.1321 100.00 * : Uncorrected for compressibility at 60.0F & 14.730PSIA. **: Liquid Volume reported at 60.0F. Standard/Dry Analysis Molar Mass 16.891 Relative Density 0.5841 Compressibility Factor = 0.9981 Heating Value 21530. Btu/lb Heating Value 962.4 Btu/CF Absolute Gas Density = 44.7003 lbm/1000CF Wobbe Index 1238.63 Unnormalized Total: 101.003 Last Calibrated with Calgas of C6+ Last Update: GPA 2261-90. C6+ BTU/CF 5065.8, C6+ Ibm/Gal 5.64250, and C6+ Mol.Wt. 1057 .2 Btu/CF -----_.. ..-.-. ._--~._. ..-. . FOREST OIL West Forelands #2 8500 Pressure: Sample Date: 12/13/04 Run Date: 12/14/04 Sample #3 RUN 1 944.7 0.5839 Saturated/Wet Analysis 16.911 0.5848 0.9980 2115l. Btu/lb 946.6 Btu/CF 44.7567 lbm/1000CF Dee.iS 03 07:26 92.00. '"-",, EG&G Chandler Engineering Model 292 BTU Analyzer Test time: DeC.14 Q4 16:09 Test #:4 Methane Ethane Propane i-Butane ( C6+ ) Moisture Nitrogen ( C02 ) ___ Standard/Dry Analysis Mole% BTU* R.Den.* GPM** 94.242 954.07 0.5220 0.349 6.20 0.0036 0.115 2.90 0.0017 0.018 0.58 0.0004 0.006 0.32 0.0002 0.000 0.00 0.0000 4.736 0.00 0.0458 0.534 0.00 0.0081 0.0934 0.0317 0.0059 0.0027 Calibration #: 1 Location No. :8500 Saturated/Wet Analysis Mole% BTU* R.Den.* 92.602 937.47 0.5129 0.343 6.09 0.0036 0.113 2.85 0.0017 0.018 0.57 0.0004 0.006 0.32 0.0002 1.740 0.88 0.0108 4.653 0.00 0.0450 0.524 0.00 0.0080 948.2 0.5826 Total 100.00 964.1 0.5819 0.1337 100.00 * : Uncorrected for compressibility at GO.OF & 14.730PSIA. **: Liquid Volume reported at 60.0F. Standard/Dry Analysis Molar Mass 16.853 Relative Density ~ 0.5828 Compressibility Factor ~ 0.9981 Heating Value 21659. Btu/lb Heating Value = 965.9 Btu/CF Absolute Gas Density = 44.5983 lbm/lOOOCF Wobbe Index 1244.58 Unnormalized Total: 100.769 Last Calibrated with Calgas of C6+ Last Update: GPA 2261-90. C6+ BTU/CF 5065.8, C6+ Ibm/Gal 5.64250, and C6+ Mol.Wt. 1057.2 Btu/CF -.. .-. FOREST OIL West Forelands #2 8500 Pressure: Sample Date: 12/13/04 Run Date: 12/14/04 Samp\e #3 RUN2 Saturated/wet Analysis 16.873 0.5835 0.9980 21276. Btu/lb 950.1 Btu/CF 44.6565 Ibm/lOOOCF DeC.1S 03 07:26 92.00. STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COMr\lr-ðION GAS WELL OPEN FLOW POTENTIAL TEST REPORT 1 a. Test: ~ Initial U Annual U Special 1 b. Type Test: U Stabilized Four Point Absolute Open Flow Test--WF#2 Upper D Constant Time D Isochronal 2. Operator Name: 5. Date Completed: Forest Oil Corporation December 14, 2004 3. Address: 6. Date TD Reached: 310 K Street, Suite 700, Anchorage, AK 99501 November 14,2004 4a. Location of Well (Governmental Section): 7. KB Elevation (ft): Surface: 886'FSL;571'FWL; Sec. 21-8N-14W Seward Meridian 128 Top of Productive Horizon: 8. Plug Back Depth(MD+ TVD): 8494 MD 10,646' MD (9,414.6 TVD) Total Depth: 9. Total Depth (MD + TVD): 11387' 11,387' MD (9,853.1 TVD) 4b. Location of Well (State Base Plane Coordinates): 10. Land Use Permit: Surface: x- 190452.37 y- 2475581.62 Zone- Salamatof Native Association TPI: x- 190160.69 y- 2477051.04 Zone- 16. Type of Completion (Describe): Total Depth: x- 189967.08 y- 2479229.02 Zone- Dual Gas Producer-Short String 17. Casing Size Weight perfoot, lb. I.D. in inches Set at ft. 19. Perforations: From 7" 29 6.184" 11,380 (WF#2-8500'MD) 8494'-8529' MD 18. Tubing Size Weight per foot, lb. I.D. in inches Set at ft. 2 3/811 4.7 1.995 8,302.46 20. Packer set at ft: 21. GOR cf/bbl: 22. API Liquid Hydrocardbons: 8283.04 NIA Salamatof Native Assoc. 24a. Producing through: o Tubing D Casing 25. Length of Flow Channel (L): 8,494 24c. Reservoir Pressure: 3,558 psia @ Datum Gg: % CO2: 0.5841 0.00527 7,900' TVDSS % N2: % H2S: 5.083 0 24b. Reservoir Temp: 162 FO Vertical Depth (H): 7,975 U Non Stabilized D Other 11. Permit to Drill Number: Gd Multipoint 204-143 12. API Number: 50- 1332054200 13. Well Name and Number: West Foreland #2-Short String 14. Field/Pool(s): West ForelandIWF#2-8500MD 15. Property Designation: FED: A-035017; AK: ADL-359122 To 23. Specific Gravity Flowing Fluid (G): 0.5841 24d. Barometric Pressure (Pa): Prover: 14.65 psia Taps: Meter Run: 26. FLOW DATA TUBING DATA CASING DATA Prover Choke Pressure Ditt. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. Line X Orifice psig Hw FO psig FO psig FO Hr. Size (in.) Size (in.) 1. 3.826 X 2.25 450 35 101 2,731.8 71 653 3 2. 3.826 X 2.25 450 102 79 2,506.3 74 936 3 3. 3.826 X 2.25 450 136 73 2,390.0 78 589 3 4. 3.826 X 2.25 455 169 73 2,265.7 74 681 3 5. X Basic Coefficient Pressure Flow Temp. Gravity Factor Super Compo Rate of Flow No. (24-Hour) -J hwPm Pm Factor Fg Factor Q1 Mcfd Fb or Fp Ft Fpv 1. 4,273 2. 7,726 3. 8,986 4. 9,992 5. Temperature for Separator for Flowing No. Pr T Tr z Gas Fluid Gg G 1. 2. 3. Critical Pressure 4. Critical Temperature 5. Form 10-421 Revised 1/2004 CONTINUED ON REVERSE SIDE Submit in Duplicate Pc 2982.997 Pc2 8898271.102 '- '~' 3555.5 pf 12641307.2 No. 1. 2. 3. 4. 5. pt 2746.45 2520.95 2404.65 2280.35 pf Pc2 -pf Pw Pvl PC2_p~ Ps 3365.8 3327.1 3311.0 3282.5 PS2 11328610 11069594 10962721 10774806 pf _PS2 1312698 1571713 1678586 1866501 AOF (Mcfd) 191,298 Remarks: See Attached Graph and Worksheet n 1.523925632 I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed &,,/4, ~ ¡jÁ,~ ~ ð, Title ReJ6«Þ()(,f ~ ""Sr,vp,¡( 7 IlK It) 7' 2.. Date 1/ '/-7DDfþ DEFINITIONS OF SYMBOLS AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia Fb Basic orifice factor Mcfdl ...¡ hwPm Fp Basic critical flow prover or positive choke factor Mcfd/psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor= -f1ïZ dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air=1.000), dimensionless Gg Specific gravity of separator gas (air=1.00), dimensionless GOR Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet (TVD) L Length of flow channel, feet (MD) n Exponent (slope) of back-pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut-in wellhead pressure, psia Pf Shut-in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back- Pressure Testing of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Fnrm 10-421 Revised 1/2004 Side 2 X:\ANC_WeILlnfo_lnProgress\WestForeland_#2\Gas Well Test\AOGCC 10-421 WF#2 Upper (WF#2-8500MD).xlsAttachments Chart 1 BWB 1/6/2005 1000 1 0 1 00 Gas Rate (MMSCF/D) :/ ." .,. "'~/"//" //,/,'/' "'..."/'-' FBHP = 0.0 PSIA 1 ////'// ~ / ".../",.".", ...."..."',;/ ____ I //' - - - - - - - - - - - - - --l:r'//'/ /......."....",1 - - - - - :, '/'/// I / Y = 409,966 x^0.6526 / - Theoretical Absolute Open Flow (AOF) = 191.3 MMSCF/D ///'/~' I" .. 1 1 1 1 1000000 ~ N < <C - UJ c.. .......... N 10000000 < tn c.. I N < ..... c.. 100000000 West Foreland #2 Upper (WF#2-8500'MD) 8,494-8,529 MD AOF PLOT Dee 13,2004 "-- .~. West Foreland #2 Lower (WF#2-8500MD) 8,494-8,529 MD AOF Dec-13-2004 BHFP BHSIP AOF = Q[Pf^2/(Pf^2-Ps^2)]^n Choke Rate Ps Pf Pf^2-Ps^2 AOF (1/64") (MMSCF/D) (PSIA) (PSIA) (PSIA^2) .!! (MMSCF/D) 12 4.273 3365.8 3555.5 1312698 1.53233 137.397 14 7.726 3327.1 3555.5 1571713 1.53233 188.520 16 8.986 3311 3555.5 1678586 1.53233 198.239 18 9.992 3282.5 3555.5 1866501 1.53233 187.352 Average 177.877 AOF 191.298 o 3555.5 12641307 From AOF Plot y=409,966*x^0.6526 (Pf^2-Ps^2) =409,966*Q^0.6526 (Pf^2) = 409,966*AOF^0.6526 AOF = [(Pf^2)/1409,966]^(1/0.6526) a = 409,966 b = 0.6526 X:\ANC_WeILlnfo_lnProgress\WestForeland_#2\Gas Well Test\AOGCC 10-421 WF#2 Upper (WF#2- 8500MD).xlsAttachments BWB 1/6/2005 STATE OF ALASKA ALAS)~(OIL AND GAS CONSERVATION COMM'ì--;'ION GAS WELL OPEN FLOW POTENTIAL TEST REPORT 1 a. Test: ~ Initial U Annual U Special 1 b. Type Test: U Stabilized Four Point Absolute Open Flow Test--WF#2 Lower 0 Constant Time 0 Isochronal 2. Operator Name: 5. Date Completed: Forest Oil Corporation December 13, 2004 3. Address: 6. Date TD Reached: 310 K Street, Suite 700, Anchorage, AK 99501 November 14, 2004 4a. Location of Well (Governmental Section): 7. KB Elevation (ft): Surface: 886'FSL;571'FWL; Sec. 21-8N-14W Seward Meridian 128 Top of Productive Horizon: 8. Plug Back Depth(MD+ TVD): 10371' MD 10,646' MD (9,414.6 TVD) Total Depth: 9. Total Depth (MD + TVD): 11,387' 11,387' MD (9,853.1 TVD) 4b. Location of Well (State Base Plane Coordinates): 10. Land Use Permit: Surface: x- 190452.37 y- 2475581.62 Zone- Salamatof Native Association TPI: x- 189996.41 y- 2478418.8 Zone- 16. Type of Completion (Describe): Total Depth: x- 189967.08 y- 2479229.02 Zone- Dual Gas Producer-Long String 17. Casing Size Weight per foot, lb. I.D. in inches Set at ft. 19. Perforations: From 7" 29 6.184" 11,380 (WF#1-9200'TVDSS) 10,371-383' MD 18. Tubing Size Weight per foot, lb. I.D. in inches Set at ft. 2 3/8" 4.7 1.995 10,304 20. Packer set at ft: 21. GOR cf/bbl: 22. API Liquid Hydrocardbons: 10304 NIA NONE 24a. Producing through: [21 Tubing D Casing 25. Length of Flow Channel (L): 10,371 24b. Reservoir Temp: 170 FO Vertical Depth (H): 9,241 24c. Reservoir Pressure: 3053 psia @ Datum Gg: % CO2: 0.586 0.00531 9200' TVDSS % N2: % H2S: 5.398 0 ß«...., U Non Stabilized o Other 11. Permit to Drill Number: ~ Multipoint 204-143 12. API Number: 50- 1332054200 13. Well Name and Number: West Foreland #2-Long String 14. Field/Pool(s): West ForelandIWF#1-9200TVDSS 15. Property Designation: FED: A-035017; AK: ADL-359122 To 23. Specific Gravity Flowing Fluid (G): 0.586 24d. Barometric Pressure (Pa): Prover: Meter Run: 14.65 psia Taps: 26. FLOW DATA TUBING DATA CASING DATA Prover Choke Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. Line X Orifice psig Hw FO psig FO psig FO Hr. Size (in.) Size (in.) 1. 3.826 X 2.25 450 28 115 1,756 72 509 3 2. 3.826 X 2.25 450 37 114 1,601 74 648 3 3. 3.826 X 2.25 450 48 109 1 ,427 74 743 3 4. 3.826 X 2.25 455 55 104 1,313 55 807 3 5. X Basic Coefficient Pressure Flow Temp. Gravity Factor Super Compo Rate of Flow No. (24-Hour) ..¡ hwPm Pm Factor fg Factor Q1 Mcfd Fb or Fp Ft Fpv 1. 3,842 2. 4,422 3. 5,071 4. 5,493 5. Temperature for Separator for Flowing No. Pr T Tr z Gas fluid Gg G 1. 2. 3. Critical Pressure 4. Critical Temperature 5. I=nrm 10-421 Revised 1/2004 CONTINUED ON REVERSE SIDE Submit in Duplicate Pc 2497.65 pc2 6238255.523 3054.2 pf 9328137.64 '----' No. 1. 2. 3. 4. 5. 25. pt 1770.65 1615.65 1441.65 1327.65 pe pc2 _pt2 Pw Pvl '''-'' PC2_p~ Ps 2314.2 2184.9 2060.7 1992.5 PS2 5355522 4773788 4246484 3970056 pf _PS2 3972616 4554350 5081653 5358081 AOF (Mcfd) 10,500 Remarks: See Attached Graph and Worksheet n 1.191895113 I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ø~~JU. &.$; I?¿. Title ¡(¿J7tdVt1t~ 1!"'5'~"'~¡( / A~.1/;)7'7 Date lis- /2...r DEFINITIONS OF SYMBOLS AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia Fb Basic orifice factor Mcfdl -J hwPm Fp Basic critical flow prover or positive choke factor Mcfd/psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor= -r:¡¡z-dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air=1.000), dimensionless Gg Specific gravity of separator gas (air=1.00), dimensionless GOR Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet (TVD) L Length of flow channel, feet (MD) n Exponent (slope) of back-pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut-in wellhead pressure, psia Pf Shut-in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back- Pressure Testing of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10-421 Revised 1/2004 Side 2 X:\ANC_Well_lnfo_lnProgress\WestForeland_#2\Gas Well Test\AOGCC 10-421 WF#2 Lower (WF#1-9200TVDSS).xlsAttachments Chart 1 BWB 1/6/2005 100 10 Gas Rate (MMSCF/D) Theoretical Absolute Open Flow (AOF) = 10.53 MMSCF 1 1000000 y = 1294340 x^0.839 ~ FBHP = 0.0 PSIA I ------------ West Foreland #2 Lower (WF#1-9200TVDSS) 10,371-10,383 MD AOF PLOT Dec-12-2004 10000000 N < tn fl- . N < .... fl- ............. N < <C - en fl- -........- · \ West Foreland #2 Lower (WF#1-9200TVDSS) 10,371-10,383 MD AOF Dec-12-2004 Choke (1/64") 12 14 16 18 Rate (MMSCF/D) 3.842 4.422 5.071 5.493 AOF 10.528 BHFP Ps (PSIA) 2314.2 2184.9 2060.7 1992.5 o From AOF Plot y=1,294,340*x^0.839 (Pf^2-Ps^2) =1,294,340*Q^0.893 (Pf^2) = 1,294,340*AOF^0.893 AOF = [(Pf^2)/1,294,340]^(1/0.839) a = 1,294,340 b = 0.893 BHSIP Pf (PSIA) 3054.2 3054.2 3054.2 3054.2 Pf^2-Ps^2 (PSIA^2) 3972616 4554350 5081653 5358081 3054.2 9328138 '........../ AOF = Q[Pf^2/(Pf^2-Ps^2)]^n AOF (MMSCF/D) 10.627 10.393 10.459 10.637 !! 1.1919 1.1919 1.1919 1.1919 Average 10.529 X:\ANC_WeIUnfo_lnProgress\WestForeland_#2\Gas Well Test\AOGCC 10-421 WF#2 Lower (WF#1- 9200TVDSS).xlsAttachments BWB 1/6/2005 '- Halliburton Global ""-/ Survey: Company: Tool: Field: COOK INLET Alaska USA Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: WEST FORELAND Site Position: From: Map Position Uncertainty: Ground Level: 2475695.37 ft 190335.56 ft Northing: Easting: 0.00 ft 0.00 ft Well: West Forelands Unit #2 Start Date: Engineer: Tied-to: Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Latitude: Longitude: North Reference: Grid Convergence: 60 45 54.648 N 151 43 54.804 W Grid -1.51 deg Slot Name: Well Position: +N/-S -113.74 ft Northing: 2475581.62 ft Latitude: +E/-W 116.81 ft Easting: 190452.37 ft Longitude: Position Uncertainty: 0.00 ft Wellpath: West Forelands Unit #2 Current Datum: Magnetic Data: Field Strength: Vertical Section: WF#2: 9/22/2004 55424 nT Depth From (TVD) ft 20.25 +N/-S ft 0.00 Height 111.10 ft Survey Program for Definitive Wellpath Date: 12/10/2004 Validated: Yes Actual From To Survey ft ft 100.00 2867.00 WF#2 GyroData (100.00-2867.00) 2956.18 11387.00 WF#2 MWD (2956.18-11387.00) Survey lncl døg 20.25 0.00 0.00 20.25 -90.85 100.00 1.11 16.67 100.00 -11.10 200.00 2.04 43.03 199.96 88.86 300.00 2.66 51.09 299.87 188.77 400.00 4.36 68.41 399.68 288.58 500.00 4.93 62.87 499.36 388.26 600.00 4.66 64.24 599.01 487.91 700.00 4.16 72.80 698.71 587.61 800.00 1.77 130.34 798.59 687.49 900.00 2.21 127.68 898.53 787.43 1000.00 2.17 116.73 998.45 887.35 1100.00 1.74 102.85 1098.40 987.30 1200.00 2.41 24.37 1198.35 1087.25 1300.00 2.14 347.19 1298.27 1187.17 1400.00 1.91 348.53 1398.21 1287.11 1500.00 1.79 356.98 1498.16 1387.06 1600.00 1.36 357.10 1598.12 1487.02 1700.00 1.13 7.12 1698.10 1587.00 -- ._--"---~--~-~ 60 45 53.559 N 151 43 52.393 W Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Well Ref. Point 20.25 ft Mean Sea Level 19.79 deg 73.49 deg Direction deg 352.42 Version: 4 Toolcode Tool Name GYD-CT -CMS MWD Gyrodata cont.casing m/s MWD - Standard 0.00 0.00 2475581.62 190452.37 TIE LINE 0.74 0.22 2475582.37 190452.59 GYD-CT -CMS 2.97 1.71 2475584.59 190454.08 GYD-CT-CMS 5.73 4.73 2475587.35 190457.10 GYD-CT-CMS 8.58 10.07 2475590.21 190462.44 GYD-CT -CMS 11.94 17.43 2475593.57 190469.80 GYD-CT -CMS 15.67 24.92 2475597.29 190477.29 GYD-CT -CMS 18.51 32.04 2475600.13 190484.41 GYD-CT -CMS 18.58 36.68 2475600.20 190489.05 GYD-CT -CMS 16.40 39.39 2475598.02 190491.76 GYD-CT -CMS 14.37 42.60 2475595.99 190494.97 GYD-CT -CMS 13.18 45.77 2475594.81 190498.14 GYD-CT-CMS 14.76 48.12 2475596.38 190500.49 GYD-CT -CMS 18.49 48.58 2475600.12 190500.95 GYD-CT-CMS 21.95 47.83 2475603.57 190500.20 GYD-CT-CMS 25.14 47.42 2475606.77 190499.79 GYD-CT -CMS 27.89 47.27 2475609.51 190499.65 GYD-CT -CMS 30.05 47.34 2475611.67 190499.71 GYD-CT-CMS Halliburton Glo bal Survey MD luel ft deg 1800.00 0.48 49.52 1798.09 1686.99 31.30 47.78 2475612.93 190500.15 GYD-CT -CMS 1900.00 1.18 83.26 1898.08 1786.98 31.69 49.12 2475613.32 190501.49 GYD-CT -CMS 2000.00 0.99 91.42 1998.06 1886.96 31.79 51.01 2475613.42 190503.38 GYD-CT -CMS 2100.00 0.99 11 .40 2098.05 1986.95 32.62 52.04 2475614.24 190504.41 GYD-CT -CMS 2200.00 1.39 4.50 2198.03 2086.93 34.67 52.31 2475616.30 190504.68 GYD-CT -CMS 2300.00 1.37 4.23 2298.00 2186.90 37.07 52.49 2475618.70 190504.86 GYD-CT -CMS 2400.00 0.99 15.00 2397.98 2286.88 39.10 52.80 2475620.73 190505.17 GYD-CT -CMS 2500.00 0.87 19.49 2497.96 2386.86 40.65 53.28 2475622.28 190505.65 GYD-CT -CMS 2600.00 1.24 36.03 2597.95 2486.85 42.24 54.17 2475623.87 190506.54 GYD-CT -CMS 2700.00 1.79 60,15 2697.91 2586.81 43.89 56.16 2475625.52 190508.53 GYD-CT -CMS 2800.00 1.97 69.89 2797.86 2686.76 45.26 59.13 2475626.89 190511.50 GYD-CT -CMS 2867.00 2.39 69.91 2864.81 2753.71 46.14 61.52 2475627.76 190513.89 GYD-CT -CMS 2956.18 1.93 70.35 2953.93 2842.83 47.28 64.68 2475628.91 190517.05 MWD 3044.88 2.09 70.83 3042.57 2931.47 48.32 67.62 2475629.94 190519.99 MWD 3106.43 2.20 71.15 3104.08 2992.98 49.07 69.79 2475630.69 190522.16 MWD 3162.06 1.54 72.63 3159.68 3048.58 49.63 71.52 2475631.26 190523.89 MWD 3219.73 0.41 136.68 3217.34 3106.24 49.72 72.40 2475631.34 190524.77 MWD 3281.36 0.81 221.82 3278.97 3167.87 49.23 72.26 2475630.86 190524.63 MWD 3362.57 1.88 242.81 3360.15 3249.05 48.19 70.69 2475629.82 190523.06 MWD 3404.57 1.86 243.24 3402.13 3291.03 47.57 69.47 2475629.20 190521.84 MWD 3485.81 1.84 241.94 3483.33 3372.23 46.37 67.14 2475627.99 190519.51 MWD 3527.82 1.91 239.94 3525.32 3414.22 45.70 65.94 2475627.32 190518.31 MWD 3608.90 1.73 244.31 3606.36 3495.26 44.49 63.67 2475626.12 190516.04 MWD 3650.95 1.79 247.02 3648.39 3537.29 43.96 62.49 2475625.58 190514.86 MWD 3712.64 1.80 249.96 3710.05 3598.95 43.25 60.69 2475624.88 190513.07 MWD 3774.29 1.58 254.89 3771.67 3660.57 42.70 58.96 2475624.32 190511.34 MWD 3835.98 1.55 256.66 3833.34 3722.24 42.28 57.33 2475623.91 190509.70 MWD 3897.72 1.52 249.76 3895.05 3783.95 41.81 55.75 2475623.43 190508.12 MWD 3959.37 1.51 255.45 3956.68 3845.58 41.32 54.20 2475622.95 190506.57 MWD 4021.03 1.52 254.51 4018.32 3907.22 40.90 52.62 2475622.52 190504.99 MWD 4082.70 1.41 245.87 4079.97 3968.87 40.37 51.14 2475621.99 190503.51 MWD 4144.29 1.46 253.58 4141.54 4030.44 39.84 49.70 2475621.46 190502.07 MWD 4205.80 0.99 248.79 4203.04 4091.94 39.42 48.45 2475621.05 190500.82 MWD 4267.51 1.18 251.00 4264.74 4153.64 39.02 47.35 2475620.65 190499.72 MWD 4329.20 1.19 244.38 4326.41 4215.31 38.54 46.18 2475620.17 190498.55 MWD 4390.85 1.34 247.37 4388.05 4276.95 37.99 44.93 2475619.61 190497.30 MWD 4452.50 1.18 258.40 4449.68 4338.58 37.58 43.65 2475619.21 190496.02 MWD 4514.01 1.02 252.04 4511.18 4400.08 37.28 42.50 2475618.91 190494.87 MWD 4575.72 0.91 262.04 4572.88 4461.78 37.05 41.50 2475618.67 190493.87 MWD 4637.25 1.08 260.53 4634.40 4523.30 36,88 40.44 2475618.51 190492.81 MWD 4698.83 0.99 255.24 4695.97 4584.87 36.65 39.35 2475618.28 190491.72 MWD 4760.46 0.99 266.49 4757.59 4646.49 36.48 38.31 2475618.11 190490.68 MWD 4822.05 0.96 267.88 4819.18 4708.08 36.43 37.26 2475618.06 190489.63 MWD 4883.57 1.05 264.50 4880.69 4769.59 36.36 36.18 2475617.99 190488.56 MWD 4944.92 0.91 265.68 4942.03 4830.93 36.27 35.14 2475617.89 190487.51 MWD 5012.07 0.88 267.62 5009.17 4898.07 36.21 34.09 2475617.83 190486.46 MWD 5073.69 0.77 278.96 5070.78 4959.68 36,25 33.21 2475617.88 190485.58 MWD 5135.15 0.50 285.03 5132.24 5021.14 36.39 32.54 2475618.01 190484.91 MWD 5196.72 0.62 271.26 5193.81 5082.71 36.46 31.95 2475618.09 190484.32 MWD 5258,36 1.01 274.26 5255.44 5144.34 36.51 31.08 2475618.14 190483.45 MWD 5319.85 1.03 325.09 5316.92 5205.82 37.00 30.22 2475618.63 190482.59 MWD 5381.29 2.18 342.13 5378.34 5267.24 38.57 29.54 2475620.20 190481.92 MWD Halliburton GIo baI '~ Survey MD Incl ft deg 5442.75 3.07 337.97 5439.73 5328.63 41.21 28.57 2475622.83 190480.94 MWD 5504.35 3.56 339.71 5501.23 5390.13 44.53 27.29 2475626.16 190479.66 MWD 5565.95 4.05 348.4 7 5562.69 5451.59 48.46 26.19 2475630.08 190478.56 MWD 5627.53 4.58 346.28 5624.10 5513.00 52.98 25.17 2475634.60 190477.54 MWD 5689.05 4.79 342.48 5685.41 5574.31 57.81 23.82 2475639.44 190476.19 MWD 5750.40 5.79 344.02 5746.50 5635.40 63.23 22.19 2475644.85 190474.56 MWD 5811.86 7.16 343.79 5807.57 5696.47 69.89 20.27 2475651.51 190472.64 MWD 5873.35 7.59 344.52 5868.55 5757.45 77 .48 18.12 2475659.11 190470.49 MWD 5934.76 8.25 346.53 5929.37 5818.27 85.67 16.01 2475667.30 190468.38 MWD 5996.38 9.32 351.20 5990.27 5879.17 94.90 14.21 2475676.53 190466.58 MWD 6057.95 10.48 352.98 6050.92 5939.82 105.39 12.77 2475687.02 190465.14 MWD 6119.47 11.04 350.57 6111.36 6000.26 116.75 11.12 2475698.38 190463.49 MWD 6181.04 13.02 347.00 6171.58 6060.48 129.33 8.59 2475710.95 190460.96 MWD 6242.54 15.64 344.88 6231 .16 6120.06 144.08 4.87 2475725.71 190457.24 MWD 6304.15 18.05 344.37 6290.12 6179.02 161.30 0.13 2475742.92 190452.50 MWD 6365.91 19.30 345.32 6348.63 6237.53 180.38 -5.03 2475762.01 190447.34 MWD 6427.53 20.17 345.38 6406.63 6295.53 200.51 -10.30 2475782.14 190442.07 MWD 6489.07 20.98 345.80 6464.24 6353.14 221.46 -15.68 2475803.09 190436.69 MWD 6550.56 22.57 345.84 6521.34 6410.24 243.58 -21.26 2475825.20 190431 . 11 MWD 6612.07 24.15 345.06 6577.81 6466.71 267.18 -27.40 2475848.81 190424.97 MWD 6673.60 25.55 344.67 6633.64 6522.54 292.14 -34.15 2475873.77 190418.22 MWD 6735.05 26.61 344.25 6688.83 6577.73 318.17 -41.39 2475899.79 190410.98 MWD 6796.55 28.31 345.06 6743.40 6632.30 345.51 -48.89 2475927.14 190403.48 MWD 6858.08 28.77 344.54 6797.45 6686.35 373.88 -56.60 2475955.51 190395.77 MWD 6919.58 29.88 345.68 6851.07 6739.97 402.99 -64.33 2475984.62 190388.04 MWD 6981.09 31.39 345.87 6904.00 6792.90 433.37 -72.03 2476015.00 190380.34 MWD 7042.25 32.97 346.31 6955.76 6844.66 464.99 -79.86 2476046.62 190372.51 MWD 7103.77 34.46 347.13 7006.93 6895.83 498.22 -87.70 2476079.85 190364.67 MWD 7165.15 35.52 347.62 7057.22 6946.12 532.57 -95.39 2476114.20 190356.98 MWD 7226.48 38.30 348.27 7106.25 6995.15 568.59 -103.07 2476150.22 190349.30 MWD 7287.85 39.86 347.30 7153.89 7042.79 606.40 -111.26 2476188.03 190341 .11 MWD 7349.22 41.31 347.07 7200.49 7089.39 645.33 -120.12 2476226.96 190332.25 MWD 7410.63 42.27 347.15 7246.28 7135.18 685.22 -129.25 2476266.85 190323.12 MWD 7472.07 44.72 347.31 7290.85 7179.75 726.46 -138.59 2476308.09 190313.77 MWD 7533.56 46.14 347.50 7334.00 7222.90 769.21 -148.15 2476350.84 190304.22 MWD 7595.05 46.71 347.82 7376.38 7265.28 812.73 -157.66 2476394.36 190294.70 MWD 7655.97 47.57 348.51 7417.82 7306.72 856.43 -166.82 2476438.07 190285.55 MWD 7717.40 47.27 348.84 7459.39 7348.29 900.78 -175.70 2476482.42 190276.66 MWD 7778.96 46.63 347.23 7501.41 7390.31 944.79 -185.03 2476526.42 190267.34 MWD 7840.38 47.72 346.69 7543.16 7432.06 988.67 -195.19 2476570.31 190257.18 MWD 7901.92 47.98 347.00 7584.46 7473.36 1033.10 -205.58 2476614.74 190246.79 MWD 7963.36 48.19 346.96 7625.50 7514.40 1077.65 -215.88 2476659.28 190236.49 MWD 8024.85 48.76 347.67 7666.27 7555.17 1122.56 -225.98 2476704.19 190226.38 MWD 8086.29 48.54 347.74 7706.86 7595.76 1167.62 -235.81 2476749.26 190216.56 MWD 8147.82 48.28 347.64 7747.70 7636.60 1212.58 -245.62 2476794.22 190206.75 MWD 8209.33 48.00 347.64 7788.75 7677.65 1257.33 -255.42 2476838.97 190196.95 MWD 8271.31 47.00 348.48 7830.62 7719.52 1302.04 -264.88 2476883.68 190187.49 MWD 8332.90 48.36 349.89 7872.09 7760.99 1346.77 -273.42 2476928.40 190178.95 MWD 8398.55 50.16 351.56 7914.93 7803.83 1395.86 -281.42 2476977.49 190170.94 MWD 8460.13 51.09 352.49 7954.00 7842.90 1443.00 -288.03 2477024.63 190164.34 MWD 8521.63 52.75 351.77 7991,93 7880.83 1490.95 -294.66 2477072.59 190157.71 MWD 8583.27 52.86 352.55 8029.19 7918.09 1539.59 -301.35 2477121.23 190151.01 MWD 8644.60 53.68 352.74 8065.87 7954.77 1588.34 -307.65 2477169.98 190144.72 MWD Halliburton Global '-'/ Survey MD loel ft deg 8706.09 51.74 352.64 8103.12 7992.02 1636.86 -313.87 2477218.50 190138.50 MWD 8767.65 49.43 351.40 8142.21 8031.11 1683.95 -320.46 2477265.59 190131.90 MWD 8829.05 48.28 350.56 8182.61 8071.51 1729.62 -327.71 2477311.26 190124.66 MWD 8890.61 46.60 352.38 8224.24 8113.14 1774.45 -334.44 2477356.09 190117.92 MWD 8952.07 44.96 351.83 8267.11 8156.01 1818.08 -340.49 2477399.72 190111.88 MWD 9013.66 44.76 351.61 8310.76 8199.66 1861.07 -346.75 2477442.71 190105.62 MWD 9075.29 41.58 350.29 8355.71 8244.61 1902.71 -353.36 2477484.35 190099.00 MWD 9136.84 41.79 350.63 8401.67 8290.57 1943.07 -360.15 2477524.72 190092.22 MWD 9198.43 42.30 350.83 8447.41 8336.31 1983.78 -366.79 2477565.42 190085.57 MWD 9259.98 40.97 351.37 8493.41 8382.31 2024.18 -373.12 2477605.82 190079.25 MWD 9321 .46 40.71 351.90 8539.92 8428.82 2063.96 -378.97 2477645.60 190073.40 MWD 9383.00 38.90 352.24 8587.20 8476.10 2102.97 -384.41 2477684.62 190067.96 MWD 9444.37 40.21 353.04 8634.51 8523.41 2141.73 -389.41 2477723.38 190062.96 MWD 9505.93 43.05 353.49 8680.52 8569.42 2182.34 -394.20 2477763.99 190058.17 MWD 9567.46 44.96 353.37 8724.78 8613.68 2224.81 -399.09 2477806.45 190053.27 MWD 9629.03 46.91 353.12 8767.60 8656.50 2268.74 -404.30 2477850.38 190048.07 MWD 9690.58 49.08 352.56 8808.78 8697.68 2314.11 -410.00 2477895.76 190042.36 MWD 9752.03 49.40 353.28 8848.90 8737.80 2360.30 -415.74 2477941.95 190036.63 MWD 9813.58 50.80 353.36 8888.38 8777 .28 2407.20 -421.23 2477988.85 190031.14 MWD 9875.03 50.53 354.35 8927.33 8816.23 2454.46 -426.32 2478036.10 190026.05 MWD 9936.61 50.51 355.47 8966.49 8855.39 2501.80 -430.54 2478083.45 190021.83 MWD 9998.11 50.97 355.14 9005.41 8894.31 2549.26 -434.43 2478130.90 190017.93 MWD 10059.66 51.06 355.35 9044.13 8933.03 2596.93 -438.40 2478178.58 190013.97 MWD 10121.17 50.91 355.26 9082.85 8971.75 2644.57 -442.31 2478226.22 190010.05 MWD 10182.65 51.03 356.00 9121.57 9010.47 2692.19 -445.95 2478273.83 190006.42 MWD 10243.73 50.46 356.05 9160.22 9049.12 2739.37 -449.23 2478321.02 190003.14 MWD 10305.21 50.39 356.20 9199.39 9088.29 2786.65 -452.43 2478368.30 189999.93 MWD 10366.82 50.22 355.81 9238.74 9127.64 2833.94 -455.73 2478415.59 189996.63 MWD 10428.26 50.51 356.18 9277.93 9166.83 2881.14 -459.04 2478462.79 189993.33 MWD 10489.71 50.44 357.44 9317.04 9205.94 2928.46 -461.68 2478510.11 189990.69 MWD 10551.07 50.60 358.23 9356.05 9244.95 2975.79 -463.46 2478557.44 189988.90 MWD 10612.62 52.32 359.06 9394.40 9283.30 3023.92 -464.60 2478605.57 189987.77 MWD 10657.63 53.33 359.03 9421.60 9310.50 3059.77 -465.20 2478641.43 189987.17 MWD 10704.04 53.55 358.83 9449.24 9338.14 3097.05 -465.89 2478678.70 189986.47 MWD 10765.61 53.76 358.89 9485.73 9374.63 3146.63 -466.88 2478728.28 189985.49 MWD 10827.10 54.40 358.51 9521.80 9410.70 3196.41 -468.01 2478778.07 189984.36 MWD 10888.70 54.54 358.19 9557.60 9446.50 3246.52 -469.45 2478828.18 189982.91 MWD 10950.22 52.36 358.94 9594.24 9483.14 3295.92 -470.70 2478877.58 189981.67 MWD 11011.79 53.44 357.71 9631.38 9520.28 3345.01 -472.13 2478926.66 189980.23 MWD 11073.36 53.59 357.91 9667.99 9556.89 3394.47 -474.03 2478976.13 189978.34 MWD 11135.04 52.96 358.27 9704.87 9593.77 3443.88 -475.67 2479025.54 189976.69 MWD 11196.55 53.16 358.24 9741.84 9630.74 3493.02 -477.17 2479074.68 189975.19 MWD 11224.23 53.15 357.90 9758.43 9647.33 3515.16 -477.92 2479096.82 189974.45 MWD 11257.93 53.74 357.64 9778.51 9667.41 3542.21 -478.97 2479123.87 189973.39 MWD 11319.53 55.01 356.23 9814.39 9703.29 3592.21 -481.65 2479173.87 189970.71 MWD 11387.00 55.01 356.23 9853.08 9741.98 3647.36 -485.29 2479229.02 189967.08 MWD 1/12/05 Vertical Scale (inches) Bottom Log Top Log Data From: LOG DATE Description Run # per 100') ! Interval (feet) Interval (feet) wlÍ:t,;>/M'#JW.ó';j(.-i"ÆW.øwM«<;;"",M#I#.>wø.wø.%'M~þ'»,>,,wA"'»;¡;1.'iWJw.&;"'!» Schlumberger 11/07/04 Modular Dynamic Tester, MDT (Large Diameter Probe) - GR I 2 5" 10,378 3,160 Schlumberger 11 /06/04 Spectral Gamma Ray Log, NGT I 2 5" 10,642 7,940 Schlumberger 11 /06/04 Spectral Gamma Ray Log, NGT, TVD Log 2 5" 9,412 7,62{ Schlumberger 11/06/04 Dipole Shear Sonic Tool, DSI-GR 2 5" 10,700 7,940 Schlumberger 11/06/04 Dipole Shear Sonic Tool, DSI-GR, TVD Log 2 5" 9,420 7,620 Schlumberger 11/19/04 Cement Bond Log, DSL T/GR/CCL 2 5" 5,140 11 ,099 Schlumberger 11/20/04 Packer Set Record, Halliburton Packer & TCP Guns 2 5" 5,110 10,790 Schlumberger 11 /06/04 Quad Combo, PEX-DSI-AIT, TVD Log 1,2 5" 9,440 3,003 Schlumberger 11 /06/04 Quad Combo, PEX-DSI-AIT 1,2 5" 10,690 3,003 WestForeland #2, API# 50-133-20542-00 Logs CONFIDENTIAL 5. L~ ..-. .. -~- ~ -~-.-..-..- ..-_u....O --"-"--".1 )..,.,.../ Subject: [Fwd: West Foreland #2 Morning Summary] From: James Regg <jim_regg@admin.state.ak.us> Date: Mon, 08 Nov 200409:05:21 -0900 To: "maunder» Tom Maunder" <tom_maunder@admin.state.ak.us> ';).,()l-\_ \ ~ ~ -------- Original Message -------- Subject: West Foreland #2 Morning Summary Date: Mon, 08 Nov 2004 07:56:19 -0700 From: WFCM <WFCM@ForestOil.com> To: Jim Reg·g-·..·~·JTm...'..regg@admin. state. ak. us>, AOGCC .:<:..~g.9.S?S?.....P..?.:.:~.?..þ..<2.~_1.?..~y.~..~.~~i-..!?:...~..~.!:.9.:!..~...:..~6_:.~~ POOH W/ MDT LOG TOOL. NO TOOL LEFT IN HOLE. R/D SCHLUMBERGER LOGGING EQUIP. R/U PULL WEAR BUSHING. R/U TEST BOP'S TO 250 LO TO 5000 HI, TEST HYDRIL TO 250 LO TO 3500 HI, ALL OTHERS TO 250 LO TO 5000 HI. ALL TESTS TO AOGCC AND FOREST OIL SPECS. INSTALL WEAR BUSHING. R/U AND P/U BHA. P/U 9 7/8 BULL NOSE HOLE OPENER, HWDP. TIH BREAKING CIRC EVERY 3000' TO 10,715'. HIT BRIDGE @ 10,715', WASH AND REAM THROUGH BRIDGE F/ 10,715' TO 10,850', WASH AND REAM THROUGH SAME 5 TO 6 TIMES TO CLEAN OUT BRIDGE. TIH TO 11,300'1 WASH AND REAM F/ 11,300' TO 11,387' WITH NO PROBLEMS. MAX GAS 262 UNITS @ 101850'. NOTE: SEE EMAIL FOR PRESSURES ON MDT LOGS DAILY LOSSES= 0 BBLS. CUMMULATIVE LOSSES= 1316 BBLS. Neal Simons Rig Clerk/Dispatcher West Foreland #2 Phone: 907-776-7186 Fax: 907-776-7187 1 of 1 11/8/2004 9: 16 AM L~ vvu. yy \.1':;>1. ~ VI ""IUIIU Tí.. .l~..I.V~I..1J..U.& UU.1~u..1.u...UJ J ~< Subject: [Fwd: West Foreland #2 Morning Summary] From: James Regg <jim _regg@admin.state.ak.us> Date: Mon, 08 Nov 2004 09:05:09 -0900 To: Tom Maunder <tom_maunder@admin.state.ak.us> è).o~~\~~ -------- Original Message -------- Subject: West Foreland #2 Morning Summary Date: Sun, 07 Nov 2004 08:26:28 -0700 From: WFCM <WFCM@ForestOil.com> To: Jim Regg·-'~·:rfm--·r·ë-ŠJ"g(~admTn~-·state. ak. us>, .:::..~g.9..~,~-2E~.g.þ'g.~_þ'_~y.~§_9.:!!!.~_~-.:...§..!:..§.~~~_.~~~~~..~ AOGCC FINISH POOH TO 1930'. POOH L/D DP AND HWDP AND MWD TOOLS. BIT WAS A 1/4-T7-B7. CLEAN RIG FLOOR. REMOVE BHA OFF CATWALK. R/U SCHLUMBERGER OPEN HOLE LOGGING. P/U SCHLUMBERGER PLATFORM EXPRESS. TIH W/ NO PROBLEMS TO 10,720'. SET DOWN, MADE SEVERAL ATTEMPTS TO WORK THROUGH SAME. OPEN/CLOSE CALIB COULDN'T GET THROUGH. POOH LOGGING F/ 10,720' TO 8952'. LOG CAIIB UP TO 8000'. L/D TOOLS. P/U MBT TOOL, TIH TAKING PSI SAMPLES TO 10,350', SEE LOG REPORT FOR GOOD SAMPLES, POOH TAKING PSI SAMPLES TO 6215'. FINISH TAKING PRESSURE SAMPLES. DAILY LOSSES= 18 BBLS CUMMULATIVE LOSSES= 1316 BBLS. Neal Simons Rig Clerk/Dispatcher West Foreland #2 Phone: 907-776-7186 Fax: 907-776-7187 1 of 1 11/8/2004 9: 15 AM L.A. ".'-4- .., ......U'-... '-'A........_JI..._ 1'- ..........-.................0 __.................A_AJJ ~ ,-,.. Subject: [Fwd: West Foreland #2 Morning Summary] From: James Regg <jim_regg@admin.state.ak.us> Date: Mon, 08 Nov 200408:58:10 -0900 To: Tom Maunder <tom _maunder@admin.state.ak.us> dÜ~'-- \ L,-~ -------- Original Message -------- Subject: West Foreland #2 Morning Summary Date: Sat, 06 Nov 2004 08:18:35 -0700 From: WFCM <WFCM@ForestOil.com> To: Jim Regg-·-·-~"ri"m-··_·r·e~g-g@adïnTrl:"state. ak. us>, .~..~.?g.S:...~_p":';:~.9..l.:!.?.~_J:?..~y.,~.~.ª~.~~_:...~!:9.:!:.~~__9.:È._:~~_.?.. AOGCC FINISH MAKING SHORT TRIP TO 9000' WITHOUT PUMP AND ROTARY ASST, @ 10,800', 10,600' AND 11,000' COULDN'T WORK THROUGH WITHOUT CIRC AND BACKREAMING. WHILE BACK REAMING WITH PUMP HOLE WOULD PACK OFF AT ANY GMP USED. NOTE:@ 10,800' AND 9000', SWEEP HOLE AND CIRC B/U ON SHORT TRIP. TIH F/ 9000' TO 11,387' @ 10,600' AND 10,800' HIT LEDGE. WIPE OUT SAME. CIRC AND SWEEP HOLE. AFTER FIRST SWEEP OUT OF HOLE, SWEEP HOLE W/ LO HI - HI VIS WEIGHED SWEEP. POOH TO LOG. WORK THROUGH TIGHT SPOT @ 10,600' AND 10,800'. NO PROBLEMS REST OF TRIP. NOTE: THROUGHOUT ALL CIRC HAD LARGE AMOUNT OF SMALL FINE ROUNDED CUTTINGS OVER SHAKERS. NOTE: @ 15:00 ON 11/05/04 LOU GRIMALDI WITH THE AOGCC GAVE VERBAL APPROVAL TO LOG BEFORE TESTING BOPS, BUT IF LOG WOULD NOT GO THEN WE MUST TEST BOP'S BEFORE GOING BACK INTO HOLE. DAILY LOSSES= 0 BBLS. CUMMULATIVE LOSSES= 1298 BBL. Neal Simons Rig Clerk/Dispatcher West Foreland #2 Phone: 907-776-7186 Fax: 907-776-7187 1 of 1 11/8/2004 9: 15 AM L~' vvu. yy ~;:)~ .lVl~lU.UY: IT'" lYIVIUU15 1J..UUUu....J J ~ "-" ' Subject: [Fwd: West Foreland #2 Morning Summary] From: James Regg <jim_regg@admin.state.ak.us> Date: Mon, 08 Nov 2004 08:53:58 -0900 To: Tom Maunder <tom_maunder@admin.state.ak.us> -------- Original Message -------- Subject: West Foreland #2 Morning Summary Date: Fri, 05 Nov 2004 07:50:47 -0700 From: WFCM <WFCM@ForestOil.com> To: Jim Regg··-"'~·Tim regg@-ã-dmin. s·tate. ak. us>, AOGCC .:,:..~g.g.~_S::-P...:t;\1:.9:.~.9..~_e..~Y~.~ª~.~_~_:__~.t ate . a~_..:..~?_:: doC) L\~ \ l-\~ TIH F/ 10,650' TO 10,680', WASH AND REAM F/ 10,680' TO 11,250'. CIRC AND COND OUT 455 UNITS OF BOTTOMS UP GAS, MUD CUT F/ 10.2 PPG TO 9.5 PPG. WASH AND REAM F/ 11,250' TO 11,284'. DRILL AND SLIDE w/ SPERRY SUN MWD F/ 11,284' TO 11,387'. AT 11,387' MR LARRY CASARTA SAID THIS WOULD BE TD. CIRC AND CONDo SWEEP HOLE W/ HI-VIS PILL. SHORT TRIP TO 10,100'. PUMP OUT OF HOLE ON SHORT TRIP @ 10,860', HOLE PACKING OFF. WASH AND REAM DUE TO TIGHT HOLE AND HOLE PACKING OFF. TIH. HIT LEDGE @ 10,680', 10,800' AND 11,000'. PUMP WAY THROUGH LEDGE. CIRC BOTTOMS UP, MAX GAS 69 UNITS. MAKE SHORT TRIP TO 9000' WITHOUT PUMPING OR BACK REAMING, SWEEPING HOLE W/ HI-VIS PILL EVERY 1000'. NOTE: WHILE BACK REAMING W/ PUMPS ON SHORT TRIP HOLE TAKING 2 BBL MUD ON EVERY STD. NO FLUID LOST TO HOLE WHILE NO PUMPING. DAILY LOSSES= 99 BBLS. CUMMULATIVE LOSSES= 1298 BBLS. Neal Simons Rig Clerk/Dispatcher West Foreland #2 Phone: 907-776-7186 Fax: 907-776-7187 1 of 1 11/8/20049:15 AM L.f'WU. VVv:)L C'VlvlallU IT"- IV.lVl111115 >JUllllllU'JJ "~ Subject: [Fwd: West Foreland #2 Morning Summary] From: James Regg <jim _regg@admin.state.ak.us> Date: Tue, 19 Oct 200408:26:43 -0800 To: Tom Maunder <tom_maunder@admin.state.ak.us> dO~--\l\ ) -------- Original Message -------- Subject: West Foreland #2 Morning Summary Date: Mon, 18 Oct 2004 07:44:02 -0600 From: WFCM <WFCM@ForestOil.com> To: Jim Regg·-"·;Tlttï--·reggc¡Yadmiri~-st·ate. ak. us>, AOGCC .:::..~.?,9.~.~-P..~~~9.-Q.<?~_~.~Y.~,9-..9..~.~..~_:..§..!:.~:t::_E?...:_. ak . us> , " Robe rt FIe ckens t e in (bob fleckenstein@admin.state.ak.us)" <bob fleckenstein@admin.state.ak.us> DRILL AND SLIDE F/ 8440' TO 8502'. STARTED GETTING BACK RUBBER OVER SHAKERS. PUMP PSI SPIKING TO 4000 PSI BLOWING POPOFF @ PUMP. CIRC OUT GAS, MAX GAS 1665 UNITS. MUD CUT F/ 9.9 PPG TO 9.3 PPG. BACKGROUND GAS RUNNING F/ 120 TO 160 AFTER CIRC GAS OUT. STOP PUMP FOR 5 MIN CHECK FLOW = OK. CIRC BOTTOM UP MAX GAS 245 UNITS, STILL GETTING RUBBER OVER SHAKERS. REPORT FROM MUD LOGGERS WAS NOT VERY GOOD AS TO WHERE GAS WAS COMING FROM, BUT WAS CALLED SHOW #1. DRILL AND SLIDE F/ 8502' TO 8548' W/ SPERRY SUN MWD. CIRC OUT GAS, MAX GAS 620 UNITS. DRILL AND SLIDE F/ 8548' TO 8677' WI SPERRY SUN MWD. GETTING BLACK RUBBER OVER SHAKERS, BLOWING POPOFF AT PUMP. AT 03:00 HRS ATTEMPTING TO DRILL W/ 3500 PSI @ 161 SPM. ( NORMAL PSI @ 230 SPM IS 3200 PSI) ROP DOWN TO 2 FPH. CIRC BOTTOMS UP, POOH TO CHANGE MOTORS. POOH. DAILY LOSSES=110 BBLS CUMMULATIVE LOSSES=597 BBLS Neal Simons Rig Clerk/Dispatcher West Foreland #2 Phone: 907-776-7186 Fax: 907-776-7187 1 of 1 11/8/2004 9: 15 AM ~O'f-/Lf3 '"",-" \~ Forest Oil C~~~oration RECEIVED Alaska DIvIsion 05 310 K Street, Suite 700 JAN 1 3 20 Anchorage, Alaska 99501 -4laska Oil & Gas Cons. Commission Phone: (907) 258-8600 Fax: (907) 258-86Ul Anchorage Date: DATA TRANSMITTAL To: January 12, 2005 I k;~1 \I\(b:\\IC/Howard Oakland AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 Phone: (907) 279-1433 From: Barbara Kruk Forest Oil Corporation 310 K Street, Suite 700 Anchorage, AK 99501 Phone: (907) 868 - 2113 FAX: (907) 258 - 8601 TRANSMITTAL DESCRIPTION Well data for WestForeland #2, API#50-133-20542-00 Item No. Qty Description I( 1 1 Well completion report (AOGCC form 10-407), with attachments J 2 1 Copy of daily drilling reports or a summary report of daily drilling. (9 pages) ~j! 3 1 List of formations and other geologic markers encountered, and their depths MD and TVD .' 4 1 List of depth and formation name for oil and gas shows j 5 1 Summary of production tests and formation tests. (4 pages) 16 J7 ",/a j 9 10 11 Copy of Drill Stem Tests and Production Test Data and Charts. Surface Well Testing Report (34 pages) Pressure Data (3 pages), Pressure Data (20 pages) 1 Copy of geochemical and formation fluid analyses and reports, if available. SGS - Laboratory Analysis Report ( 14 pages) EG&G Chandler Engineering Report - 9200 Sample #1 (2 pages) EG&G Chandler Engineering Report - 9200 Lower Sample #2 (2 pages) EG&G Chandler Engineering Report - 8500 Sample #3 (2 pages) EG&G Chandler Engineering Report - 8500 Sample #4 (2 pages) 1 Copy of all open flow potential test reports and report attachments, (AOGCC form 10-421) AOGCC from 10-421 for West Foreland #2 (WF#2-8500MD) (4 pages) AOGCC from 10-421 for West Foreland #2 (WF#1-9200TVDSS) (4 pages) 1 Paper and digital copies of all directional surveys 1 Paper and Sepia copy of final composite mud or lithology log and report. 1 Digital version of well logs in LAS format and digital version of directional surveys in ascii. ~ Transmittals_AOGCC.xlsIWF#2_011205 Date Modified:1/12/2005 bk \ ' ~ "-" Forest Oil Corporation Alaska Division 310 K Street, Suite 700 Anchorage, Alaska 99501 Phone: (907) 258-8600 Fax: (907) 258-8601 DATA TRANSMITTAL It~ No. Qty j 12 9 Date: January 12, 2005 10,378' 10,642' 9,412' 10,700' 9,420' 5,140' 5,110' 9,440' 10,690' 3,160' 7,940' 7,620' 7,940' 7,620' 11,099' 10,790' 3,003' 3,003' Description Well WestForeland #2, API#50-133-20542-00 Paper and Sepia copy of all Logs run (9 paper copies, 6 sepia's (denoted by sin qty column) Bottom Log Top Log Interval Interval Description Transmittals_AOGCC.xlsIWF#2_011205 s s s s s s Modular Dynamic Tester, MDT (Large Diameter Probe) - GR Spectral Gamma Ray Log, NGT Spectral Gamma Ray Log, NGT, TVD Log Dipole Shear Sonic Tool, DSI-GR Dipole Shear Sonic Tool, DSI-GR, TVD Log Cement Bond Log, DSL TIGRlCCL Packer Set Record, Halliburton Packer & TCP Guns Quad Combo, PEX-DSI-AIT, TVD Log Quad Combo, PEX-DSI-AIT Cutting Samples WF#2 - Depth: 6,180' - 10,500' MD Cutting Samples WF#2 - Depth: 10,500' - 11,387' MD 1 CD - Contains digital files for Item 10 (Mudlog & Well Report) File Listing for CD containing Item 10. (2 pages, cd_mudlog.list) 1 CD - Contains digital files for Items 2, 5, 6, 7, and 8 listed above File Listing for CD containing Items 2, 5, 6, 7, and 8. (1 page, cd1.list) CD - Contains digital files for Item 11 listed above File Listing for CD containing Item 11 (1 page, cd2.list) Log Date Run# 11/07/04 2 11/06/04 2 11/06/04 2 11/06/04 2 11/06/04 2 11/19/04 2 11/20/04 2 11/06/04 1, 2 11/06/04 1, 2 13 j 2boxes All Drill Cuttings Box1: Box2: CONFIDENTIAL DATA Please Si9~,. be~wto ' knowledge recZeiPt. Repewed By: . /J It ,,-----. / ~¡¿jA, c L¡:lMA £jA~ Returned to Forest Oil { Accepted By: Date>1 3 /; "J¡ /3; ~5~ Date Date Modified:1/12/2005 bk K~: w r ttL. ~L.V'+-l '+.J) \....V1IlPlCUVll r 1(111:> ~ ~ ,-,. Subject: Re: WF #2 (204-143) Completion Plans From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Thu, 02 Dec 2004 12:54:04 -0900 To: Chuck Wilson <CHWilson@forestoil.com> cc: Bill Penrose <bill@fairweather.com>, Paula Inman <prinman@forestoil.com>, Ted Kramer <tekramer@forestoil.com>, Steve Davies <steve_davies@admin.state.ak.us>, John D Hartz <j ack _ hartz@admin.state.ak.us> Chuck, et al: Thanks for the information regarding forward operations on WF #2. No further paperwork is necessary with regard to your forward plans. The possibility of a dual completion was mentioned in the original permit paperwork. I will place a copy of this message in the well file. Please note, that it does help if you put a title on your messages. Call or message with any questions. Tom Maunder, PE AOGCC Chuck Wilson wrote: Tom, This is correct, the Y block is the orienting device that allows us to perforate away from the long string. Chuck Wi Ison Forest Oil Corporation Sr. Drilling Engineer Office:(303) 812-1661 Fax:(303) 812-1712 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Thursday, December 02, 2004 1:19 PM To: Chuck Wilson Cc: Bill Penrose Subject: Re: Chuck, I presume that the guns below the Y block will be oriented so as not to shoot the long string?? Tom Maunder, PE AOGCC Chuck Wilson wrote: Tom, As per the email that Bill sent you and as per your request, I would like to follow up and add to what you have received. Forest Oil Corporation scope of working, going forward: lof2 12/2/2004 12:55 PM Ke: w t FfL. ~L.Uq-lq,j) L,omp1t~l1un naIlS ',,- '......-' Run in the hole and set a WD packer with TCP guns at a depth in order to perforate the interval from 10,371'-10,383' (9,200' sand). We will then pick a 2-3/8" tubing, space out with 2-3/8" tubing with a Y block and TCP guns (to perforate from 8,494'-8,529') below a dual packer, run the dual packer, a dual string of 2-3/8" tubing. We will land the dual strings in the hangers, RIH with a plug in the long string side, set the plug, pressure up and set the dual packer. Back pressure valves will be set in each string, the BOP's ND and the Dual Tree installed and then the back pressure valves retrieved. We will swab each string of tubing down in order to perforate under balanced. The long string will be a bar drop to perforate and the short string we will use N2 to pressure up and perforate. A down hole plug will be set in each string and a back pressure valve installed. The rig will be moved, well testers will be rigged up and each zone will be tested independently. The well test should occur somewhere around the 13th of December. Should you have any questions please contact me by either email or by telephone. Respectively, Chuck Wi Ison Forest Oi I Corporation Sr. Drilling Engineer Office:(303) 812-1661 Fax:(303) 812-1712 Email: chwilson@forestoil.com 2of2 12/2/2004 12:55 PM ~ Vl\"f~'" '-'J.J. ,., ""..,,, .1. VJ.'-IJ.,..&..I.J.'-& 11"'-. .J. ""'\01\...1.&.....0 ......."'_"'_u ~.. Subject: Forest Oil West Foreland #2 Testing Status From: BiB Penrose <bill@fairweather.eom> Date: Wed, 01 Dee 2004 10:41:28 -0900 To: tom _ maunder@admin.state.ak.us, Stan _ Porhola@ak.blm.gov ò{)L\- 'L-\ ::, Tom and Stan, This is to keep you up to date on the testing status at Forest Oil's West Foreland #2 well. After perforating and testing the interval 10,725' -10,760'MD, a bridge plug was set at 10,671' and 25' of cement was placed on top of it. Forest is now preparing to perforate and test the interval 1 0,371' - 10,383'MD. This is the "9,200' Sand" as seen in the WF#1 well, a gas sand which had an original reservoir pressure of 4,100 psi and now has a pressure of approximately 3,100 psi. Equipment is currently being arranged and the perforating/testing is expected to commence in 2 or 3 days. Testing and test results for this well will be reported in more detail on the post-well completion report. Regards, Bill 1 of 1 12/1/2004 10:56 AM Ll' VVU. VV l' Trk 1 ~;:)U115 UllU .1 IVUU",uvuJ µ'>'-f -, 7 ;J ~ ~. John, Dan: In the haze of late Friday night, I forgot to forward this to you all. At 4:40 PM on Friday, I got a call at home from Tom saying Forest needed immediate approval (the rig was waiting on orders) to test a sand interval that lies below the 9400-foot sand in the West Foreland 2 well. Forest emailed the logs for West Foreland 1 and West Foreland 2 to my house for purposes of discussion. I independently verified Forest's correlations and depth picks using the logs provided by Forest. The 9400-foot sand is not developed in West Foreland 2, but Forest saw potential for gas in the next sand lobe below the 9400-foot sand. As you recall, Forest owns 100% working interest in the state lease within which West Foreland 2 was drilled. According to BLM's land administration case files, Forest owns 100% interest in this stratigraphic interval in the adjacent Federal Lease A-035017 to the stratigraphic equivalent of 9,624' measured depth on the West Foreland 1 Induction Electric log. Below that depth, Forest owns 60% interest, and ConocoPhillps owns 400/0. The lowest perforation in Forest's potential West Foreland 2 test is 10,760' MD, which is 60 vertical feet above the base of Forest's 100% working and operating interest in the federal lease, and it will be separated and sealed from the base of their working interest in the federal lease by 25 vertical feet of mudstone and siltstone and 10 vertical feet of coal. ConocoPhillips correlative rights in the deeper portion of the federal lease will be protected. I gave Forest approval to test the zone. I also required Forest to notify ConocoPhillips of the well location prior to initiating regular production. My apologies for not forwarding this more quickly, Steve Davies -------- Original Message -------- Subject: WF #2 Testing and Production Date:Fri, 19 Nov 200420:41:16 -0900 From:Stephen Davies <akdavies5«~,hotmail.com> T 0 :.J.J.?Ar.Egg!º}~@it.QI~.?.J9.u.:,9.Q.~~ cc :t0111 maunder({,~admin .state.ak.us, LCGurule(d},forestoil.com, BWBrice(Zi?forestoì1.com, .P.Jy.!:WI~!~JQ.~.c4.).!º.r.~.~!-º.H:.~-º!p.:, .~.!~y.~..._º.ªY.:i~.~.cq1ªglJ.J.Ü~.:.~.!~!.~.:..ªb:~~.~ Jim, Based on information presented to me via email and telephone on the evening of November 19, 2004, I concur with Forest's opinion that the deepest desired test interval in the West Foreland #2 well ("WF #2"), from 10,725' to 10,760' measured depth (IIMD"), -9,354' to -9,374' true vertical feet subsea ("tvdss"), lies within the stratigraphic interval in which Forest has a 100% working and operating interest in adjacent Federal Lease A-035017. BLM's land administration case file for that lease states that Forest has 100% working and operating interest ownership from the surface to the stratigraphic equivalent of 9,624' MD on the Induction Electrical log ("IEL") from the West Foreland No.1 well (IIWF #1") . I also concur with Forest's opinion that 9,624' MD on the WF #1 IEL correlates with 10,862' MD (-9,434' tvdss) in WF #2. Forest's proposed bottom perforation at 10,760' MD in WF #2 will be 60 vertical feet above the base of Forest's 100% working and operating interest in adjacent Federal Lease A-035017. An interval of 25 vertical feet of mudstone and siltstone and 10 vertical feet of coal will lie between the 1 of3 11/23/20042: 1 0 PM LJ.- VfU. V¥.1. IT£.¡ .1. .......:>...UI5 UU.U .1 .lVU\..t."'\..lV,UJ bottom perforation and t~base of Forest's 100% working and ~rating interest. Forest may perforate and test the interval from 10,725' to 10,760' MD in WF #2. However, pursuant to the Commission's request sent to you via email approximately four days ago, Forest must also notify ConocoPhillips Alaska, Inc. of the location of the well prior to initiating regular production. Please call me at 349-1191 or 793-1224 if you have any questions. Sincerely, Steve Davies Petroleum Geologist Alaska Oil and Gas Conservation Commission > From: Jim Ar 1 i ng t on .~,:Tº~~.~..t..r.?:~;Lt:.?~.c~.~.9-E~_E.'..!=:9-.;h,~.~_C:;.'?.r.r.!:':, >To: II I akdavies5@)hotmail.com' II <akdaviesS@hotmail.com> >CC: ·ïï··ï..EoïTï··..rrïa\incte·ri~adÏÏïIÏi··:...s·ta"t·e. a}::-":"u"'s·-!"'·ïï--··~·EoiÏï"-·maï::i.nde-r(¡Ú;dmin . s ta te . ak. us > , :~~~~~·f·~~·~~~·~;'·:·~·~:ì~~:0~:~E~:~~:~~~~~~§.~¥~:l:±::~~.r.r.!:~·~:~I~~r~~·~-~-~~~:~-~~-;·~_·~·=·~:"~'·"'~·~-:~hen > Da:·vIë-s......:;··s..Eeve-····cta·v·i"e·fii@)ad:min . s tat e . a k . u s';...--·-·-·.....·-.....·.....·'....·..'· .--......-...- >Subj ec t ..;..···..·RE·..;......·WF·..·..#"·2.....·weiT·.....s'!:;·a:·c·Ing-··-e-xc·e·p"t'I on >Date: Fri, 19 Nov 2004 21:22:41 -0700 > >Steve, > >Pursuant to our discussions this evening, this email is sent to request >confirmation from the AOGCC that Forest is allowed to perforate, test and >produce a new zone of interest identified today in the cased hole logs >obtained in the WF #2 well. The new zone of interest for the proposed >perforations in the WF #2 well lies between: > > > > 10,725' to 10,760' MD (CBL 11-19-2004)¡ 9,462' to 9,482' tvd¡ -9,354' to -9,374' tvdss. > >The correlation of logs between the WF #1 well and the WF #2 well indicates >that this new zone of interest lies within the Shallow Rights in the >adjacent federal lease A-035017 in which Forest has a 100% working and >operating interest. The Shallow Rights in said lease are defined as the >working interest above the stratigraphic equivalent of the measured depth >of >9,624' as said depth is identified in the Induction-Electrical log for the >West Foreland No.1 Well. The 9,624' MD of the WF #1 well correlates to >10,862' MD (9,542' tvd¡ -9,434' tvdss). > >Our proposed bottom perforation in the WF #2 well will be 60 vertical feet >above our Shallow Rights in federal lease A-035017. There are five (5) >vertical feet of unperforated reservoir, twenty-five (25) vertical feet of >shale and ten (10) vertical feet of coal below our proposed bottom >perforation in the WF #2 well and the base of our correlated Shallow Rights >in the federal lease. > >Forest, in good faith, believes that it has the rights to perforate, test >and produce the sands in State of Alaska oil and gas lease ADL-359112 >located within the zone of interest defined above and respectfully requests >your concurrence. > >Sincerely, > >Jim Arlington >Land Manager > > >-----Original Message----- >From: Jim Arlington >Sent: Friday, November 19, 2004 4:50 PM >To: 'akdavies5@hotmail.com' >Cc: 't"orrï··lïïa:uiiëie·i:·(~~·a·c{mlï~"~·state. ak. us'; Leonard Gurule; Bradley Brice; Paul > Win s 1 ow...·-········...·...··..·······'..·····......·......··...·...··......·..···...................................-....-...... 2 of 3 11/23/2004 2: 1 0 PM ll' YVU. VV J.' IT£.. J. "-';:HJU5 UJJU J. J VUU"-'UVJJ J ~ >Subject: RE: WF #2 well spacing exception > >Attached is the log for the WF #1 well you requested. > >Jim > >-----Original Message----- >From: Jim Arlington >Sent: Friday, November 19, 2004 4:46 PM >To: 'akdavies5@hotmail.com' >Cc: 'Eom·..···:[11aundei~(0)a·dmIÏÏ..·:..s"ti;:te. ak. us' i Leonard Gurule i Bradley Brice ¡Paul > Win s 1 ow··..·-..··....·..··..·····....··..··........·..........·..··........·........................................................ >Subject: WF #2 well spacing exception > >For your immediate review to approve testing, as we discussed. > >Jim Arlington Express yourself instantly with MSN Messenger! Download today - it's FREE! b:.~..~:.P...:...!...!.~:f.I~§J?.~.1!:9..~..!....:...~.§!:?:...~..s-:.~..~.~!.:.=:..~~E~..:..g_~~l9..?.l..?.:0..!!.l.2..Q.~..2..º..~..?...J.:~y.~i d ire c t /...21.L 30f3 11/23/20042:10 PM South West Foreland 1 North 9,200- foot sd West Foreland 2 Correlation Cross-section SFD 11-19-2004 West Foreland 2 9,400- foot sd WF #2 Testing and Production . . Jim, Based on information presented to me via email and telephone on the evening of November 19, 2004, I concur with Forest's opinion that the deepest desired test interval in the West Foreland #2 well ("WF #2"), from 10,725' to 10,760' measured depth ("MD"), -9,354' to -9,374' true vertical feet subsea ("tvdss"), lies within the stratigraphic interval in which Forest has a 100% working and operating interest in adjacent Federal Lease A-035017. BLM's land administration case file for that lease states that Forest has 100% working and operating interest ownership from the surface to the stratigraphic equivalent of 9,624' MD on the Induction Electrical log ("IEL") from the West Foreland NO.1 well ("WF #1"). I also concur with Forest's opinion that 9,624' MD on the WF #1 IEL correlates with 10,862' MD (-9,434' tvdss) in WF #2. Forest's proposed bottom perforation at 10,760' MD in WF #2 will be 60 vertical feet above the base of Forest's 100% working and operating interest in adjacent Federal Lease A-035017. An interval of 25 vertical feet of mudstone and siltstone and 10 vertical feet of coal will lie between the bottom perforation and the base of Forest's 100% working and operating interest. Forest may perforate and test the interval from 10,725' to 10,760' MD in WF #2. However, pursuant to the Commission's request sent to you via email approximately four days ago, Forest must also notify ConocoPhillips Alaska, Inc. of the location of the well prior to initiating regular production. Please call me at 349-1191 or 793-1224 if you have any questions. Sincerely, Steve Davies Petroleum Geologist Alaska Oil and Gas Conservation Commission From: Jim Arlington <JDArlington@forestoil.com> To: "'akdavies5@hotmail,com'" <akdavies5@hotmail.com> CC: "'tom maunder@admin.state.ak.us'" <tom maundeníj!admin.state.ak.us>, Leonard Gurule <LCGurule@forestoil.coffi>, Bradley Brice <BWBrice@forestoil.coffi>, Paul Winslow <p¡v¡winslow@forestoil.com>, Stephen Davies <steve davies@admin.state.ak.us> Subject: RE: WF #2 well spacing exception Date: Fri, 19 Nov 2004 21:22:41 -0700 Steve, Pursuant to our discussions this evening, this email is sent to request confirmation from the AOGCC that Forest is allowed to perforate, test and produce a new zone of interest identified today in the cased hole logs obtained in the WF #2 well. The new zone of interest for the proposed perforations in the WF #2 well lies between: 10,725' to 10,760' MD (CBL 11-19-2004); 9,462' to 9,482' tvd; -9,354' to -9,374' tvdss. The correlation of logs between the WF #1 well and the WF #2 well indicates that this new zone of interest lies within the Shallow Rights in the adjacent federal lease A-035017 in which Forest has a 100% working and operating interest. The Shallow Rights in said lease are defined as the working interest above the stratigraphic equivalent of the measured depth of 9,624' as said depth is identified in the Induction-Electrical log for the West Foreland NO.1 Well. The 9,624' MD of the WF #1 well correlates to 10,862' MD (9,542' tvd; -9,434' tvdss). 10f2 11/23/2004 2:09 PM WF #2 Testing and Production . .. Our proposed bottom perforation in the WF #2 well will be 60 vertlcal feet above our Shallow Rights in federal lease A-035017. There are five (5) vertical feet of unperforated reservoir, twenty-five (25) vertical feet of shale and ten (10) vertical feet of coal below our proposed bottom perforation in the WF #2 well and the base of our correlated Shallow Rights in the federal lease. Forest, in good faith, believes that it has the rights to perforate, test and produce the sands in State of Alaska oil and gas lease ADL-359112 located within the zone of interest defined above and respectfully requests your concurrence. Sincerely, Jim Arlington Land Manager -----Original Message----- From: Jim Arlington Sent: Friday, November 19, 2004 4:50 PM To: 'akdavies5@hotmail.com' Cc: 'tom maunder@admin.state.ak.us'; Leonard Gurule; Bradley Brice; Paul Winslow Subject: RE: WF #2 well spacing exception Attached is the log for the WF #1 well you requested. Jim -----Original Message----- From: Jim Arlington Sent: Friday, November 19, 2004 4:46 PM To: 'akdavies5@hotmail.com' Cc: 'tom maunder@admin.state.ak.us'; Leonard Gurule; Bradley Brice; Paul Winslow Subject: WF #2 well spacing exception For your immediate review to approve testing, as we discussed. Jim Arlington Express yourself instantly with MSN Messenger! Download today - it's FREE! http://messenger.msn.click-url.com/go/onm00200471ave/direct/Ol/ 20f2 11/23/2004 2:09 PM FW: RE: WF #2 well spacing exception . . From: Jim Arlington <JDArlington@forestoil.com> To: '" akdaviesS@hot.maí.l . com '" <akdavies5@hotma.ì1.com> CC: '" tom maundei:@;a-j;n:Cn-:-,state.ak.us '" <tom mauYl2ier@a2imin. stat.e. ak. us>, Leonard Gurule <LCGurule@fores-:-tü:Cï:-:--cüÌÏ¡;-,--Bia-ëÜey Brice <BWBrlc-cciforest.:-oiT-:-com> , Paul Winslow ~-PMWins1ow@forestoil. com>, Stephen Davie¡:;im~steve davies@admin. state. ak. us> SubJect: RE: WF #2 well spacing exception Date: Fri, 19 Nov 2004 21:22:41 -0700 Steve, Pursuant to our discussions this evening, this email is sent to request confirmation from the AOGCC that Forest is allowed to perforate, test and produce a new zone of interest identified today in the cased hole logs obtained in the WF #2 well. The new zone of interest for the proposed perforations in the WF #2 well lies between: 10,725' to 10,760' MD (CBL 11-19-2004); 9,462' to 9,482' tvd; -9,354' to -9,374' tvdss. The correlation of logs between the WF #1 well and the WF #2 well indicates that this new zone of interest lies within the Shallow Rights in the adjacent federal lease A-035017 in which Forest has a 100% working and operating interest. The Shallow Rights in said lease are defined as the working interest above the stratigraphic equivalent of the measured depth of 9,624' as said depth is identified in the Induction-Electrical log for the West Foreland NO.1 Well. The 9,624' MD of the WF #1 well correlates to 10,862' MD (9,542' tvd; -9,434' tvdss). Our proposed bottom perforation in the WF #2 well will be 60 vertical feet above our Shallow Rights in federal lease A-035017. There are five (5) vertical feet of unperforated reservoir, twenty-five (25) vertical feet of shale and ten (10) vertical feet of coal below our proposed bottom perforation in the WF #2 well and the base of our correlated Shallow Rights in the federal lease. Forest, in good faith, believes that it has the rights to perforate, test and produce the sands in State of Alaska oil and gas lease ADL-359112 located within the zone of interest defined above and respectfully requests your concurrence. Sincerely, Jim Arlington Land Manager -----Original Message----- From: Jim Arlington Sent: Friday, November 19, 2004 4:50 PM To: I akdavies5@hotmail . com' Cc: 'tom maunder@a.dmin.state.ak.us'; Leonard Gurule; Bradley Brice; Paul Win s low:-mm----m------ Subject: RE: WF #2 well spacing exception Attached is the log for the WF #1 well you requested. Jim -----Original Message----- From: Jim Arlington Sent: Friday, November 19, 2004 4:46 PM To: 1 . com' 1 of2 11/23/20042: 10 PM FW: RE: WF #2 well spacing exception . Cc: '~?~~~~~gg~r@admin.st~te.ak,us'; Leonard Gurule; Winslow Subject: WF #2 well spacing exception .. Bradley Brlce; Paul Jim Arlington For your immediate review to approve testing, as we discussed. Express yourself instantly with MSN Messenger! Download today - it's FREE! http://mess~!:?:9er.msn . click··url . com/go/onm002004 7lave/di:r:~_<::~Lº:1:/. 20f2 11/23/2004 2: 1 0 PM FW: RE: WF #2 well spacing exception . . Fram: Jim Arlingtan::g-º!:\!:Li..!!g_t,:g,¡l~f(?E~J~_t:oi1. com> Ta: 'Stephen Davies' <akdavies5@hotmail.com> Subj ect: RE: WF #2 well spac:Cñg-exception-mmm Date: Fri, 19 Nav 2004 19:37:43 -0700 Steve, Here is the lag as a jpeg file. Jim -----Original Message----- Fram: Stephen Davies [mai1ta:akd~,:,::L,,:_?_?..~þatmail.cam] Sent: Friday, Navember 19, 2004 5:26 PM Ta: JDArlingtan@forestoil.com Subject: RE: WF #2 well spacing exceptian Jim, The WF 2 calar file .opened just fine. Far same reasan, I'm having a prablem in Acrabat parsing bath black and white image files. Cauld yau send the WF #1 lag as a jpg file? Thanks, Steve Davies >Fram: Jim Arlingtan <JDArlingl:::gn@forestail.com> >Ta: "'akdavies5@hotmail.cam'" <akdavies5@hotmail.com> >CC: II '·tom maDnder@admin.state.ãk.us' II <tom maunder@ã·cJ"min.state.ak.us>, >Leanard-Gurul e < LCGurul e@foreston::com;-;--Bradley Br i ce---m.mmm ><BWBrice@forestai1 . com> ;-PauT-wlnsYow---~PMì1inslow@farestoi 1. com> >Subj ect: RE: WF #2 well spacing exceptian ----- "".0.0.0.0_.....0,,_ >Date: Fri, 19 Nav 2004 19:17:32 -0700 > >1 have scanned the WF #1 lag again as a black & white bitmap in case yau >had >difficulty with the size .of the calar file. > >Jim Arlingtan > > >-----Original Message----- >Fram: Jim Arlingtan >Sent: Friday, Navember 19, 2004 4:50 PM >Ta: 'akdavies5@hotmail.com' ....-.--.--.-...-- ....................-.... >Cc: 'tam maunder@admin.state.ak,us'; Leanard Gurule; Bradley Brice; Paul >Winslüw---" .....0_......___ . >Subject: RE: WF #2 well spacing!exceptian > >Attached is the lag far the WF ~1 well yau requested. > >Jim > >-----Original Message----- >Fram: Jim Arlingtan >Sent: Friday, Navember 19, 200414:46 PM >Ta: 'akdavies5@hotmail.com' >Cc: 'tom maunder:~i;ãdmin. s ta te. ak .Ius'; Leanard Gurule; Bradley Brice; Paul >Winslow "-- '·....··..r····-..· >Subject: WF #2 well spacing exc1ptian > i >Far yaur immediate review ta apØrave testing, as we discussed. lof5 11/23/20042:09 PM FW: RE: WF #2 well spacing exception > >Jim Arlington > >« WF_Ilog_B_W_II-19-2004.pdf » - it's FREE! Express yourself instantly with MSN Express yourself instantly with MSN Messenger! Download today - it's FREE! hthttp://messenger.msn.click-url.com/go/onm0020047Iave/direct/Ol/ 20f5 11/23/2004 2:09 PM FW: RE: WF #2 well spacing exception 30f5 11/23/20042:09 PM FW: RE: WF #2 well spacing exception 40f5 11/23/20042:09 PM FW: RE: WF #2 well spacing exception Content-Type: image/jpeg Content-Encoding: base64 50f5 11/23/2004 2:09 PM Re: Forest Oil Company's Spacing Exception Application for the De... ~ ,,- 4 . . Jim, In retrospect, Forest should have provided notice via certified mail to ConocoPhillips Alaska, Inc. concerning the spacing exception approved in CO 532 because ConocoPhillips is also an owner of Federal Lease A-035017, which lies within 3000' of the West Foreland 2 well. Please consider the last sentence in my email of November 16, 2004 to be a request by the Commission in addition to the requirements of CO 532. Steve Davies Jim Arlington wrote: Steve, THANKS! I appreciate your prompt attention to Forest's request to clarifY the authorizations inherent in the two AOGCC approved Permit(s) to Drill tor the referenced well and Conservation Order (CO") No. 532. However, could you please clarify the last sentence in your email below and help me to understand how it is consistent with Part 1 of CO No. 532 which says: 1. Forest's application for a spacing exception to allow for drilling and initiating gas production from the WF #2 well from any interval not stratigraphically deeper than the 9400-foot sand is temporarily granted. This spacing exception expires 24 30 months after Forest completes WF #2, without prejudice to Forest's right to apply for an extension of this temporary spacing exception or for a permanent spacing exception. (Emphasis added.) Is your email to be considered by Forest as either an amendment to CO No. 532 or a separate order of the AOGCC? My understanding is that CO No. 532 already gives Forest permission to test and initiate regular production from the 9400-foot sand (i.e. the stratigraphic equivalent of the same sand in the WF # 1 well). I look forward to hearing from you soon. Jim Arlington -----Original Message----- From: Stephen Davies [mailto:steve davies@admin.state.ak.usl Sent: Tuesday, November 16, 2004 1:31 PM To: Jim Arlington Cc: John Norman; Daniel Seamount; Tom Maunder; John Hartz; Jody Colombie; Rob Mintz Subject: Forest Oil Company's Spacing Exception Application for the Deepened Portion of West Foreland 2 Mr. Arlington, This is in reference to Forest Oil Company's ("Forest") spacing exception application for the lof2 11/17/2004 8: 12 AM Re: Forest Oil Company's Spacing Exception Application for the De... (~, . . deepened portion of the West Foreland 2 well (that interval from 10,649' measured depth to the total depth of the West Foreland 2 well). The Commission will not require a spacing exception for the deepened portion of West Foreland 2 well for the following reasons: 1. the deepened interval in West Foreland 2 lies within 1500' of a property line, but lies entirely on Alaska State Lease ADL 359112, a lease owned 100% by Forest; 2. Forest has represented to us that only that portion of the deepened interval in West Foreland 2 from approximately 10,660' to 10,649' measured depth will be tested; and 3. testing of, or regular production from, West Foreland 2 to a measured depth of 10,660' will not violate Conservation Order 532, as that measured depth does not lie stratigraphically deeper than the 9400- foot sand as defined in Conservation Order 532. The Commission has determined the 9400-foot sand in West Foreland 2 may be tested, but may not be put on regular production until the Commission receives proof from Forest of notice sent via certified mail to ConocoPhillips Alaska, Inc. concerning the location of the well and Forest's intent to begin regular production from the 9400-foot sand. Sincerely, Steve Davies Petroleum Geologist Alaska Oil and Gas Conservation Commission 20f2 11/17/20048:12 AM ~:.. ::. :. Forest Oil Company's Spacing Exception Application for the De... .~. . . Steve, THANKS! I appreciate your prompt attention to Forest's request to clarifY the authorizations inherent in the two AOGCC approved Permit(s) to Drill for the referenced well and Conservation Order (CO") No. 532. However, could you please clarifY the last sentence in your email below and help me to understand how it is consistent with Part 1 of CO No. 532 which says: 1. Forest's application for a spacing exception to allow for drilline and initiatine eas production from the WF #2 well from any interval not stratieraphically deeper than the 9400-foot sand is temporarily granted. This spacing exception expires 24 30 months after Forest completes WF #2, without prejudice to Forest's right to apply for an extension of this temporary spacing exception or for a permanent spacing exception. (Emphasis added.) Is your email to be considered by Forest as either an amendment to CO No. 532 or a separate order of the AOGCC? My llilderstanding is that CO No. 532 already gives Forest permission to test and initiate regular production from the 9400-foot sand (i.e. the stmtigraphic equivalent of the same sand in the WF # 1 well). I look forward to hearing from you soon. Jim Arlington -----Original Message----- From: Stephen Davies [mailto:steve_davies@admin.state.ak.us] Sent: Tuesday, November 16, 2004 1:31 PM To: Jim Arlington Cc: John Norman; Daniel Seamount; Tom Maunder; John Hartz; Jody Colombie; Rob Mintz Subject: Forest Oil Company's Spacing Exception Application for the Deepened Portion of West Foreland 2 Mr. Arlington, This is in reference to Forest Oil Company's ("Forest") spacing exception application for the deepened portion of the West Foreland 2 well (that interval from 10,649' measured depth to the total depth of the West Foreland 2 well). The Commission will not require a spacing exception for the deepened portion of West Foreland 2 well for the following reasons: 1. the deepened interval in West Foreland 2 lies within 1500' of a property line, but lies entirely on Alaska State Lease ADL 359112, a lease owned 100% by Forest; 2. Forest has represented to us that only that portion ofthe deepened interval in West Foreland 2 from approximately 10,660' to 10,649' measured depth will be tested; and 3. testing of, or regular production from, West Foreland 2 to a measured depth of 10,660' lof2 11/17/20048:12 AM J 'E: Forest Oil Company's Spacing Exception Application for the De... , , . . will not violate Conservation Order 532, as that measured depth does not lie stratigraphically deeper than the 9400-foot sand as defined in Conservation Order 532. The Commission has determined the 9400- foot sand in West Foreland 2 may be tested, but may not be put on regular production until the Commission receives proof from Forest of notice sent via certified mail to ConocoPhillips Alaska, Inc. concerning the location of the well and Forest's intent to begin regular production from the 9400-foot sand. Sincerely, Steve Davies Petroleum Geologist Alaska Oil and Gas Conservation Commission 20f2 11/17/20048:12 AM Forest Oil Company's Spacing Exception .cation for the Deepen... . . I Mr. Arlington, This is in reference to Forest Oil Company's ("Forest") spacing exception application for the deepened portion of the West Foreland 2 well (that interval from 10,649' measured depth to the total depth of the West Foreland 2 well). The Commission will not require a spacing exception for the deepened portion of West Foreland 2 well for the following reasons: 1. the deepened interval in West Foreland 2 lies within 1500' of a property line, but lies entirely on Alaska State Lease ADL 359112, a lease owned 100% by Forest; 2. Forest has represented to us that only that portion of the deepened interval in West Foreland 2 from approximately 10,660' to 10,649' measured depth will be tested; and 3. testing of, or regular production from, West Foreland 2 to a measured depth of 10,660' will not violate Conservation Order 532, as that measured depth does not lie stratigraphically deeper than the 9400-foot sand as defined in Conservation Order 532. The Commission has determined the 9400- foot sand in West Foreland 2 may be tested, but may not be put on regular production until the Commission receives proof from Forest of notice sent via certified mail to ConocoPhillips Alaska, Inc. concerning the location of the well and Forest's intent to begin regular production from the 9400- foot sand. Sincerely, Steve Davies Petroleum Geologist Alaska Oil and Gas Conservation Commission 1 of I 11/16/20041:35 PM RE: [Fwd: West Foreland Well Locations] ;;..ó t./ - / ¿j '3 . . Steve, I haven't been able to get hold of the surveyor, but I've talked to enough people involved so I have the story. It's easier to answer your second question first. The correct location is on the application dated August 30. For the deepened well application I used my original July 28 application as a go-by, forgetting that the application of August 30 modified the location. As for the locations being on the same gridlines to the third decimal, it has to do with this being an as-staked survey. The surveyor set up on the control point (the WF#1 well) and directed the person driving the stakes to locations due east of that location the required number of feet and recorded them using his known location on the WF#1 well. No doubt, if he had taken his transit over to the stakes and run another survey from there, inherent equipment and human error margins might have moved the recorded locations by an inch or two, but there was no need to do that since they were already surveyed in from the original control point and shared its accuracy as recorded. I hope this hasn't been too confusing, Please let me know if I can provide additional information. Regards, Bill Penrose -----Original Message----- From: Stephen Davies (mailto:steve_davies@admin.state.ak.us] Sent: Tuesday, November 09,20049:14 AM To: Bill Penrose Cc: Tom Maunder Subject: [Fwd: West Foreland Well Locations] Bill, Did you get a chance to look into this? Thanks, Steve Davies -------- Original Message -------- Subject:West Foreland Well Locations Date:Wed, 03 Nov 2004 09:41:43 -0900 From:Stephen Davies <steve davies@admin.state.ak.us> Organization:State of Alaska To:Bill Penrose <bill@fairweather.com> CC:Tom Maunder <tom maunder@admin.state.ak.us> Bill, 10f2 11/9/20043:57 PM RE: [Fwd: West Foreland Well Locations] . . AOGCC needs to make sure we record the proper surface locations for Forest's West Foreland wells. On Aug. 31 st, you sent an email to Tom Maunder regarding the surface location of West Foreland 1. Attached to that email is a survey plat. The plat shows lat / long, and ASP grid coordinates for the West Foreland 1,2 and "2 ALT." locations, but it does not give surface coordinates in terms of footages from the section lines for any of these locations. Close inspection of the plat (see attached) shows that all three locations have the same "Grid N" coordinates to within 1/1,000th of a foot. Note also that the "Grid E" coordinates for each location all end in ".370", indicating that the locations were staked precisely 30 feet or 40 feet apart along the same grid line, respectively (again accuracy to the nearest 1/1000th of a foot). I'm not a land surveyor, but such precision of placement seems statistically unlikely. The surface locations provided on Forest's applications for Permit to Drill for the West Foreland 2 and the deepened West Foreland 2 don't agree. The West Foreland 2 Permit to Drill application submitted by Forest on August 30, 2004 lists the surface location at 886 FSL and 571 FEL of Section 21, T8N, RI4W, SM and ASP zone 4 coordinates of X = 190,452 and Y = 2,475,582, while the Permit to Drill application submitted by Forest on October 30,2004 for the deepening of this same well lists 880 FSL and 631 FEL of Section 21, T8N, R 14 W, SM with ASP zone 4 coordinates of X = 190,391 and Y = 2,475,578. I believe the application submitted August 30th gives the correct coordinates, but need confirmation from you. Questions: To ensure the accuracy of our files, 1. Could you tell us which location (2 or 2 ALT) is the actual location of the West Foreland 2 well? 2. Could you check to see if the Grid N and Grid E values are indeed correct? 3. Could you provide me a listing of the coordinates of the actual surface locations for West Foreland 1 and West Foreland 2 in terms of footages from section lines, ASP, and lat / long, so that I can ensure that the Commission's records are correct? Thanks, Steve Davies AOGCC 20f2 11/9/20043:57 PM ~ . . Forest Oil Corporation 310 K Street, Suite 700 Anchorage, Alaska 99501 (907) 258-8600 Fax: (907) 258-8601 November 5, 2004 Mr. Robert Crandall Alaska Oil and Gas Conservation Commission 333 W. 71h Avenue, Suite 100 Anchorage, Alaska 99501-3539 Hand-Delivered Re: Application for Well Spacing Exemption, West Foreland #2 ("WF #2") Well, deepening West Foreland Field; A-0350l9, ADL-359ll2 Dear Mr. Crandall: Forest Oil Corporation ("Forest") by this letter hereby submits this application for approval to the Alaska Oil and Gas Conservation Commission ("AOGCC"), and respectfully requests the AOGCC to issue an order, exempting the West Foreland #2 well ("WF #2") fÌ'om the drilling unit and spacing requirements of20 AAC 25.055 as they pertain to the gas pool within the West Foreland Field insofar as such is required for the deepening of the WF #2 beyond that authorized by Conservation Order No. 532. Forest hereby incorporates by reference the infonnation it provided in its application that resulted in the issuance of Conservation Order No. 532. This exception to the statewide spacing regulations is necessary to allow Forest to drill the WF #2 deeper than the depth presently permitted by the AOGCC in Conservation Order No. 532 (10649' md, 9445' tvd). When the WF #2 attained its initially-permitted total depth ("TD ") last week wireline logs were begun. It became apparent that it was possible that not all of the gas bearing and potentially gas bearing sands of the Tyonek interval had yet been penetrated. Forest requested the AOGCC by email to extend the TD of the WF #2 well to the anticipated top of the Hemlock Fonnation which coincides with the base of the Tyonek. The AOGCC granted Forest approval to continue drilling, subject to several conditions, one of which was to submit this application for a new spacing exception to extend the depth of the WF #2. Consequently, Forest respectfully requests that the AOGCC grant an exception to the provisions of20 AAC 25.055 for the deepening of the WF #2 with a proposed new TD for the WF #2 of 11,500'MD, 9,930'TVD. The well path for the deepening of the WF #2 is approximately described as follows: Feet From Feet From Feet From Target Depth MD TVDss X ASP4 Y ASP4 Sec 21 N/S Line Sec 21 E/W Line Lease line WF #2 surface 0 108' 190452 2475582 884' FSL 570' FEL 460' West WF #1 surface location from 1961 BLM log report 879.5' FSL 670.5' FEL WF #1 surface Surveyed 2004 0 90' 190412 2475582 884' FSL 610' FEL 420' West 7,400' sand 7,540' -7,218' 190285 2476400 1,020' FSL 758' FEL 216' West 9,200' Sand 10,083' -8,968' 190047 2478241 1,781' FNL 1,043' FEL 242' East 9,400' Sand 10,351' -9,150' 190022 2478435 1,588' FNL 1,074' FEL 293' East TD 11,418' -9,768' 189972 2479226 762' FNL 1,135' FEL 309' East Page 1 of2 . . 'This exception to the statewide spacing regulations is sought because the new proposed bottomhole location of the WF #2 may be either witlrin 1,500' of a property line with a different landowner (i.e. the federal lease ) or witlrin 3,000' of a well capable of producing trom the same pool (i.e. the WF #1). The proposed bottomhole location for the WF #2 will be updip trom the existing WF #1 and near the common lease line separating the State of Alaska and federal leases. The new proposed bottomhole location of the WF #2 will be in Section 21, T08N, R14W, Seward Meridian and east of the common lease b01111dary, as indicated on the enclosed maps. Pursuant to 20 AAC 25.055, enclosed is a revised plat showing the location of the WF #2, lease maps indicating well paths, where the proposed well is estimated to encounter productive intervals and all adjoining properties. In addition, a table is enclosed listing the parties entitled to receive notice of this application and an affidavit stating that the undersigned is familiar with the facts stated in this application and that the plat correctly portrays pertinent and required data. The parties listed in the enclosed table have also been mailed certified copies of this application, including all enclosures. If there are any questions or should you need additional information, please contact me at (907) 868-2112. Sincerely yours, FOREST OIL CORPORATION ,.- /7? .j'1___' c~¿!d:z2 Jim Arlington .<:...-- ) Land Manager Enclosures cc: COO BLM ADNR Page 2 of2 ... . . TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Alaska Oil and Gas Conservation Commission In the Matter of the Application of Forest Oil Corporation for a well spacing exemption And exception to the provisions pertaining to Drilling Units and Well Spacing pursuant to 20 AAC 25.055 ) ) ) ) ) ) ) VERIFICATION OF FACTS AND AFFIDAVIT OF JIM ARLINGTON Jim Arlington, being fIrst duly sworn, upon oath, deposes and states as follows: 1. My name is JIM ARLINGTON. I am over 21 years old and have personal knowledge of the matters set forth herein. 2. I am the Land Manager for the operator, Forest Oil Corporation (FOREST). 3. I am knowledgeable and fully informed concerning the facts associated with the application of Forest Oil Corporation for a well spacing exemption and exception to the provisions pertaining to drilling units and well spacing pursuant to 20 AAC 25.055 as they pertain to drilling the West Foreland #2 gas well deeper than previously authorized in Conservation Order No. 532. 4. I have assisted in preparing and have reviewed the completed application submitted by Forest requesting an exemption from the provisions of20 AAC 25.055 for the deepening ofthe West Foreland #2 well in the West Foreland Field and hereby assert that all the facts contained therein are true to the best of my knowledge. 5. I have reviewed the plat and maps enclosed with the application and assert that they correctly portray the pertinent and required data. 6. Forest is the only operator of any wells within 3,000 feet of the well for which the exception contained in the application is sought. 7. On or about November 5,2004, pursuant to 20 AAC 25.055(d), I mailed the required notice of Forest's application for an exemption from the provisions of 20 AAC 25.055 by sending a copy of the application by certifIed mail to the names of all owners, landowners and operators of all properties within 3,00 feet of the proposed well location and have attached this list as Exhibit "A" to this affIdavit. Subscribed and sworn to on November 5, 2004. ~~ Inn AIling'o STATE OF ALASKA ) ) ss. THIRD JUDICIAL DISTRICT ) On this ~ of November 2004, before me, the undersigned, a Notary Public duly commissioned and sworn, appeared Jim Arlington, personally known to me, to be the person whose name is subscribed to within the VerifIcation of Facts and AffIdavit. ~\\\\"UI"'III~ ~ carOle Â~ ~ .,.--.;~~~ § z~ ~ ,I ~Ot~ ~~ = ..0......... ~ ' = =-- ~..... - ~<A\.. ~L'A ~ ~~~, ~ ~$ 0'.....··· ~ ~ '7¡¡/Jlnl,""~~ W~~ Notary Pu~li~, State ~f Alas,R I ~ ~O" My ConnmsslOn ExpIres: "'1 (c:::1C-Jj \,.. ~ ~.c....·..... ".... .. ...... . . EXHIBIT "A" To VERIFICATION OF FACTS AND AFFIDAVIT OF JIM ARLINGTON In the Matter of the Application of Forest Oil Corporation for a well spacing exemption and exception to the provisions pertaining to drilling units and well spacing pursuant to 20 AAC 25.055. West Foreland #2 well deepening List of names of all owners, landowners and operators of all properties within 3,000 feet Name Attention Address City State Zip DNR, Division of Oil & Gas Chris Ruff 550 West 7th, Ste. 800 Anchorage AK 99501-3560 U. S. DOl, BLM Greg Noble 6881 Abbott Loop Rd. Anchorage AK 99507-2591 Cook Inlet Region, Inc. Kirk McGee 2525 C Street, Ste. 500 Anchorage AK 99509 Lease ap -- Suñace Location 1 Mil Shoreline & Lease Line 1 Mile Lease ap -- 7400'Sand -. Lease Map...... Target 1 'I<Y 1 Mile Lease ap...... nomaly A 1 Mile w Lease Map...... 9200' Sand 1 Mile v Lease ap -- 9200' Sand 1 Mile '!if Lease Map... TD location 1 Mile Shoreline & Lease Line BLM-Alaska ALIS Online Page 1 of8 ¿L~ ~4d bJ tr74J 1; 6z.¢ / Alaska Land Information System - ALrs Online ~ LV P ~ 1- - Case Abstract of AKA 035017 :>~~ ~ ¥ k US Department of the Interior Bureau of Land Management >,,_~~ _n' _. _. , . n' __ M~_~< ...."~~,,~... . "'M _mM~~ _ _ _,~ .~>~ ~M~ N__< ~ n~'~~<, n~ «~~n~_~mM _. L CASE DATA . ,-=~~_... ='~'^,'>_""'N'^"_'_"NNN,,"""NNNN~~_N~~~ '~.'~"'~~~-=-'-,~-~~...--=-~~'''-,,,,,-~,,,,,,,,,,,,, Serial Num: AKA 035017 IFRC Site Code: SEA ,__"~ ~~~_!yp~~~_~~lll 08r.G ~s~~_oncomp PU~~!I!!~"W~.^..'."^'.m.~._._.._..w__m__~w_.~_J lAcc~ssion ~!lm:_.w__,.~w.___.~__.J If_as~ Status: Auth~!!~~.d ___~_~_.__._...__,___w....____..~~_._J ~x Num: (of).__~~_J Status Actn: lease Issued 1º~!iP..º!!!!~:._......... ,.,,1 Status Date: 29-SEP-1958 l~~~~i~!1~~~~:m.mJ . Acres: 0 I~!!I!~!~: ....J 1~I!li~....~~.~.~.,.........,..._.w......................'_.' .."'._.w................w.......w............... ....ww.............www............. .., ,..._......w.." ..,'w...._w......w...1 L___...._.___.__. ~ustid: 0~0001555 Name: FOREST OIL CORP cust Address:** DATA SUPPRESSED -.-J IfE.st C!ty:*~ DATA SUPPRESSED ~LState:** DATA.~UPPRES~ED_.._._JI~ip co~e:**J?ATA~.~!PRES~~~_..J CUSTOMER DATA ~ ""'".~..~¥, I ~~ Rei: Co-Owner _. 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Lease Al!le~de.!:L.__~o.J IACR~S ADJ !º..8.:J.º.~C. ..~~J -- ~~~.. [~.º:~~~:!~!?~..J 1º~~_.I!~I!!~!.I!~!~.,º~!l~~t""........w,J 11!~~!.I?~.~.",~ª~ºL!.~~,I!,.~..........."""...w.J [=.....,.1 I~~~...J I~~~.J 1~~:~~!:!~!?ª..J 1~!?-ª.~~gl!~pe.~~~~.""..........,""""""....,J t~~~..~~~I!!Ç.~~L.I=.!~~w.....~......J 1:.:..,..1 t~~~J I~~~I lº~:~º~:!~!?~j 1~.º!!:.~~~~-'!Iel:'ldE!!!.......m"".m~_...J 1~~I!~!..~~!º.~.~?~£~.._ww~j t.:....._j SAF l!~:º.~m:!~!?~.J 1~~º.TIfº!.º!!_~!~~d..__m.~..,J T DIMOCK l:=--.__~J !~~!:J l!7-NOV-1966 11560 Trf Of Orr Filed ~IMARY PRYOR THOMAS ~I-- I S ~:~0~-1966 _J~O Trf O! Orr Filed IJAMES D MEDE.MA JI::=--...~1982 USAF l!8-MAY-1967 11560 Trf Of Orr Filec!. JIOIL INVESTMENT TRUST I~.--J ISAF IL_~.J [09-0CT-1967 1[560 Trf Of Orr FiledJIMARY T BROOKS Jl::..~1982 IISAF IL -- . I II II II llir-!I "_._~, . . http://www.ak.blm.gov/perl-bin/alis/abstractldo_abstract_full.pl 11/12/2004 BLM-AIaska ALIS Online Page 3 of8 lº!:~~:~~~z~~...ll~~.º!~.~!.º~~~.i.I~~......_...~.............! 1~~º.!.~~~!~~~~~~!,~~.I!_....~..j 1::__ .....1 1~~~.J I~~~.,J ~-OCT-1967 11560 Trf Of Orr Filed .~_.-J WHINES SAF IL~___J 1~:-º.~-196~.J[~~º"^!rf Of ºrr ~!I~~m._.w~_~.wJIWIL!:!AM ERVEN .~_..w~Jl::.~~ l!!:~~:.~.~67 J 1560 T~_~.!_Orr Filed _~~....~_~w_.~J 1~~~EN H~~~~...,..__~_~._~ l::~......J ~C,!-196!_J~60 Trf Of Orr Filed ",...__..JIDR W~.ERv:~~_~_____JI-- j ~:~OV-1967 ,J~o Trf Of Or':,File~..~,.___,.....,JILEO ~~REIEL~HEI~MER~.._....J[::....~.-J ~~-NºY-1967 11560 Trf Of Orr Filed.__..,..,_~_J~~C 8r. 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ASGN 250/~ EACH TO: PAN AMERICAN PETROLEUM CORP, SINCLAIR OIL & GAS CO, SKELL V OIL CO, AND PHILLIPS PETROLEUM CO l~.% ORR TO C<?TTIS & BEAULIEU. t:~---------------:--------------------------------- IIBI 802 ~CRES OF THE SUBSURFACE,~F THIS LEASE WASm"~~_,.._'__.m'..~~_~~_.__~_~mmm'"~_'~_J 1~~~º~~^~I:!.~I:~OI!!I:,~~~"I:I~ "!~~m~"I:~!'!fº~Y~!~!º..., "" ..,."""..,.""""....,......,,.............m.," ....,.,..,.......,.. .....".m'............_.~._.....,........,......,. ......,.: If!I!!P~!ºl~~L~~~~~~.~!JJ 2.ºº~!.!:~!!~,I!!..~f!~~.~.~...~.,',...".,",.,""',..,...,".'...m......,~... ......"..............."..'m'......'m..m".'...".._w.~.,.., 1~!~!J,!tml:'~~~.~.º~I!.I:f!~º-!º~º1.~CR,.I:~tfºI!~~.f!."....w.....m".m',...m_. .mm".m'mm'" 'mmW'^"m.~... m.m...~..m....m""._....~m~m .... 1º.!~~~~TI"º~P.~...I!º!~~~~~!~m~~.~!~Oª~C?~m!º.~!~.!......m.m...'.. mm"mm..w'...~.."^.....mw..^_m.'..............m_._..~mw......m....1 15.84970/0 TO THE UNITED STATES. ___...~.._J ¡U.S. RETAINS O&G OWNERSHIP ONL V AS TO USS lOWNE~I:I!!.º!4L V.AS TO USS 4522; USS 4523; .......m~.._..._..w......~._~..mm.m.~ Iuss 45~4, LOT 1; A~-º.. US~ 11865 ~(50~!..~"~CRES)'__~"_m.."~_~.~_~~.._"._...m_.~___.~m___....J ADMINISTRATION OF THE LEASE IS RETAINED BV THE ""'~,~~.~ .- _----1 N, =W~_'ff~'--=~.~'N~''''''''''= "'~~wvm_'",'__=w''' . http://www.ak.blm.gov/perl-bin/alis/abstractldo_abstract_full.pl 11/12/2004 BLM-Alaska ALIS Online Page 6 of 8 OF LAND MANAGEMENT. 1--- LEASE ~ESERVED FOR DURATION O~. LEASE T~.~M AND IANY ~E~EWALS T~EREOF TO THE US UNDER Al!!HORI'!y. ~~!HE ACT O!.~-14-60J~4 STAT 1025). 1---------------------------------------------------- RTI TRANSFERRED FROM PHILLIPS TO FORCENERGY ~FEÇTIVE JAN 1, 1999. COPYOF FORCENERGY'~~__._~._.~... 1~.~!!º~~!º~.~º~ºJ~!!º~~}!~~c:~~~t:!~.~~..... """",., ..,.""",........ ............ ...@.""'.._...........",'.".....,..""'..,......, """"..,. "".............",., ".,.""'.,...,..,,, ",,'. I::.------------=:-~-------------------------------- .., IFORCENERGY..THEN TRANSFERRED 40% º!,_~~TING RIGH'!~.............,._..__~___..~.~.._...~__.-.J 1~~~º~I~~...~.~!º~.~~I:!!Ç~~q~~~.~~.~!.º~..!~~,.~.~~~~~.~,º ....."".."'.,....",.'"'.....,."",.,,,,,....., ",.....",.'",.,...,.."""",......""""......, ,'..."""""", "" """"" ........",. """",.@............@ Iº~~~ OF.~,6~4..~,~~!.~~.~D PE~!I:!}S,',!,º.~,~,!!r!~º~!.!~L__...,. .,""',",.,.,""","",.,',"~.._ ".,"_...,~...___.._...~.__'._....... INDUCTION-ELECTRIC LOG FOR THE WEST FORELANDS I~º~!.~ELL ("DEEP RIGHTS") BACK TO PHILLIPS. ~-------------------~------------------------------- MERGER AND NAME CHANGE RECOGNIZED BY WYOMING STATE OFFICE; EFFECTIVE DECEMBER 7, 2000. ~~'~=""""'~"""""~ .^"=~,~.....~~,~",.^~"^""~~_"""'_~"",,....w ="........,'",...........-'''''''~,,'''''''~''''''''~'''''''''''''..........,~''''",'''',-,,~''''''' ""~'.,"'"......... "~-~ - ,.~'.'"--".'''~,~,~.~"'''~'^'.,.,.".,'',.,,'.'-._-,--''''''''''''--,~~-,~-~~". . 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Data displayed by the AUS-Online is refreshed Monday-Friday on an hourly basis from 7:00am to 9:00pm with data retrieved from the BLM-Alaska AUS Production database. No warranty is made by the Bureau of Land Management as to the accuracy, reliability, or completeness of these data. Refer to specific BLM case files for official land status information. For case data related information/help, contact the BLM Alaska Public Information Center at (907) 271-5960. . , __, _.. H~ "', n. "~ n~ ,~ , . ,~~.., ~~~wm_'~, _~~~~~ ~,~".~,_ =" H~n"· The AUS Online is maintained at the BLM Alaska State Office, Branch of Information Resources Management. Please send your suggestions and comments to our webmaster.. [Friday, November 12, 2004 at 12:55:44 (AKST)] http://www.ak.bIm.gov/perI-binlalis/abstract!do_abstract_full.pI 11/12/2004 . . 532 was imrpovidentley granted, bcasue in contrary to sworn testimony, they didn't notice CPAI, we should suspend the existing spacing until they provide concurrence form CPAI, non objection from CPAI no exception is needed proc uphoel is covered by 532 . ... .,.1; ~ @ November 5, 2004 . . Forest Oil Corporation 310 K Street, Suite 700 Anchorage, Alaska 99501 (907) 258-8600 Fax: (907) 258-8601 Mr. Robert Crandall Alaska Oil and Gas Conservation Conunission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 ~ø-~ RECEIVED NOV 0 5 2004 Alaska Oil & Gas Cons. Commission Hand-Delivered Re: Application for Well Spacing Exemption, West Foreland #2 ("WF #2") Wel~ deepening West Foreland Field; A-035019, ADL-359112 Dear Mr. Crandall: Forest Oil Corporation ("Forest") by this letter hereby submits this application for approval to the Alaska Oil and Gas Conservation Connnission ("AOGCC"), and respectfully requests the AOGCC to issue an order, exempting the West Foreland #2 well ("WF #2") from the drilling unit and spacing requirements of20 AAC 25.055 as they pertain to the gas pool within the West Foreland Field insofar as such is required for the deepening of the WF #2 beyond that authorized by Conservation Order No. 532. Forest hereby incorporates by reference the information it provided in its application that resulted in the issuance of Conservation Order No. 532. This exception to the statewide spacing regulations is necessary to allow Forest to drill the WF #2 deeper than the depth presently permitted by the AOGCC in Conservation Order No. 532 (10649' md, 9445' tvd). When the WF #2 attained its initially-permitted total depth ("TD ") last week wireline logs were begun. It became apparent that it was possible that not all of the gas bearing and potentially gas bearing sands of the Tyonek interval had yet been penetrated. Forest requested the AOGCC by email to extend the TD of the WF #2 well to the anticipated top of the HeITÙock Formation which coincides with the base of the Tyonek. The AOGCC granted Forest approval to continue drilling, subjectto several conditions, one of which was to submit this application for a new spacing exception to extend the depth of the WF #2. Consequently, Forest respectfully requests that the AOGCC grant an exception to the provisions of20 AAC 25.055 for the deepening of the WF #2 with a proposed new TD for the WF #2 of 11,500'MD, 9,930'TVD. The well path for the deepening of the WF #2 is approxùnately descn'bed as follows: WF #2 surface 0 108' 190452 2475582 WF #1 surface location from 1961 BLM log report WF #1 surface Surveyed 2004 7,400' sand Target Depth 9,200' Sand 9,400' Sand TD MD Feet From TVDss X ASP4 Y ASP4 Sec 21 N/S Line 884' FSL 879.5' FSL o 7,540' 90' -7,218' 190412 190285 2475582 2476400 884' FSL 1,020' FSL 10,083' -8,968' 190047 2478241 1,781' FNL 10,351' -9,150' 190022 2478435 1,588' FNL 11,418' -9,768' 189972 2479226 762' FNL ( 0 p y Page 1 of2 Feet From Sec 21 EIW Line Feet From Lease line 570' FEL 460' West 670.5' FEL 610' FEL 420' West 758' FEL 216' West 1,043' FEL 242' East 1,074' FEL 293' East 1,135' FEL 309' East .~.. ow . . This exception to the statewide spacing regulations is sought because the new proposed bottomhole location of the WF #2 may be either within 1,500' of a property line with a different landowner (i.e. the federal lease) or within 3,000' of a well capable of producing from the same pool (i.e. the WF #1). The proposed bottomhole location for the WF #2 will be updip from the existing WF #1 and near the common lease line separating the State of Alaska and federal leases. The new proposed bottomho1e location of the WF #2 will be in Section 21, T08N, R14W, Seward Meridian and east of the common lease boundary, as indicated on the enclosed maps. Pursuant to 20 AAC 25.055, enclosed is a revised plat showing the location of the WF #2, lease maps indicating well paths, where the proposed well is estimated to encounter productive intervals and all adjoining properties. In addition, a table is enclosed listing the parties entitled to receive notice of this application and an affidavit stating that the undersigned is familiar with the facts stated in this application and that the plat correctly portrays pertinent and required data. The parties listed in the enclosed table have also been mailed certified copies of this application, including all enclosures. If there are any questions or should you need additional infonnation, please contact me at (907) 868-2112. Sincerely yours, FOREST OIL CORPORATION (). ~';z< .'\,' . ~ Î/>-Þ""'--- . .'~' . 1/ . Jim Arlington . Land Manager Enclosures cc: CIRI BLM ADNR Page 2 of2 e..' , . '.", " '.>" "'. ".,J"'.. . . TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Alaska Oil and Gas Conservation Commission In the Matter of the Application of Forest Oil Corporation for a well spacing exemption And exception to the provisions pertaining to Drilling Units and Well Spacing pursuant to 20 AAC 25.055 ) ) ) ) ) ) ) VERIFICATION OF FACTS AND AFFIDAVIT OF JIM ARLINGTON Jim Arlington, being ftrst duly sworn, upon oath, deposes and states as follows: 1. My name is JIM ARLINGTON. I am over 21 years old and have personal knowledge of the matters set forth herein. 2. I am the Land Manager for the operator, Forest Oil Corporation (FOREST). 3. I am knowledgeable and fully informed concerning the facts associated with the application of Forest Oil Corporation for a well spacing exemption and exception to the provisions pertaining to drilling units and well spacing pursuant to 20 AAC 25.055 as they pertain to drilling the West Foreland #2 gas well deeper than previously authorized in Conservation Order No. 532. 4. I have assisted in preparing and have reviewed the completed application submitted by Forest requesting an exemption from the provisions of20 AAC 25.055 for the deepening of the West Foreland #2 well in the West Foreland Field and hereby assert that all the facts contained therein are true to the best of my knowledge. 5. I have reviewed the plat and maps enclosed with the application and assert that they correctly portray the pertinent and required data. 6. Forest is the only operator of any wells within 3,000 feet of the well for which the exception contained in the application is sought. 7. On or about November 5, 2004, pursuant to 20 AAC 25.055( d), I mailed the required notice of Forest's application for an exemption from the provisions of20 AAC 25.055 by sending a copy of the application by certifted mail to the names of all owners, landowners and operators of all properties within 3,00 feet of the proposed well location and have attached this list as Exhibit "A" to this affidavit. Subscribed and sworn to on November 5, 2004. 21~ Jnn Adingto STATE OF ALASKA ) ) ss. THIRD JUDICIAL DISTRICT ) On this ~ of November 2004, before me, the undersigned, a Notary Public duly commissioned and sworn, appeared Jim Arlington, personally known to me, to be the person whose name is subscribed to within the Veriftcation of Facts and Affidavit. ~\\\\"II"'III~ ~ carole ~ ~/~~ if ~o 1'-f... \"~ :!', ~ :: =~ .0., ~ - - ~ - ~CA ~~L'C È ~~ § ~~ ~~ ~JJ&nllf,\\\~ W~;;;óh~ Notary Pu~li~, State ~f AlasH I.-.G'\ fó.o- My COIDIDlsslOn ExpIres: '-1 (c:::7{.)/ '-' ð .'" " . :':..:.... .' . . EXHffiIT "A" To VERIFICATION OF FACTS AND AFFIDAVIT OF JIM ARLINGTON In the Matter of the Application of Forest Oil Corporation for a well spacing exemption and exception to the provisions pertaining to drilling units and well spacing pursuant to 20 AAC 25.055. West Foreland #2 well deepening List of names of all owners, landowners and operators of all properties within 3,000 feet Name Attention Address City State Zip DNR, Division of Oil & Gas CbrisRuff 550 West 7th, Ste. 800 Anchorage AK 99501-3560 U. S. DOl, BLM Greg Noble 6881 Abbott Loop Rd. Anchorage AK 99507-2591 Cook Inlet Region, Inc. Kirk McGee 2525 C Street, Ste. 500 Anchorage AK 99509 II I . -- 1 Mile " Lease Map - Surface Location ---- I I WF·2p "TO ~ __ Proj. 9400 SaÆt Q -9132 , proj. 9200 sand .,:. -æ6O .- 2,11 -- . . ~ Shoreline & Lease Line ,&... ...... - In 1 Mile -- " Lease Map -7400'Sand --- -- Wf'-2p \TD~_ Pro'J. 9400 Sand Q -9132 , Pro.I. 92'OCí 91d ~ -æoo - 21 W fO'' and ·1 ·N~1J4.00ßar·id .. -7.:061 . . -7'2-~J ~ .. ' Lease Map - Target 1 -+- WF-2p \o~_ Pro.!, 9400 sam Q ..,9132 , Proj. 9200 9'Id ö ~ 1 Mile 2~ I \IV FOffano -1 'N=1 74..)':( Sard ~ -7361 - - .... y -- . . Lease Map - Anomaly A -¡n \\ ~-. ,TD:_ . ~ .... proJ. 9400 Sand (") -9132 , ProJ. 9200 S1d 0') -æ6() .- -85SS 21 1 Mile . --- --- -----y- . ,1 Mile -- " Lease Map - 9200' Sand ---- --.--- ;t ¡ WF-2p \D~~ . Prol9400 Sar:Þ:I ~ -9132 , Pro. 9200 &and , I L .".... . .- , --,A 1 Mile ----- .,. Lease Map - 9200' Sand "----- 2. ··..1 . ~ --.---- WF-2p T\ID ~ ~ Proj,9«K1 Sa!1d , iProj. 9200 iand . . --------......-_- Lease Map - TD location \ \ M \m:~ Proj, 9400 Sand ; ~9m , Pro]. 9200 ~ .;;, ...fI96{1 -r -----~------~-------..._----_. . I I 2·· .~, . ., : \ 1 Mile , --......---... .. ----- -~ . . (~ Shoreline & Lease Line ------------- West Foreland #2 (PTD 2041430) Well Plugging Requirements Dear Mr. Wilson, We have received Forest's proposal via Bill Penrose concerning the casing setting depth on West Foreland #2. Forest proposes to set production casing approximately 500' off bottom. Forest's reasoning is that their are no zones of interest in the interval between 10,900' measured depth and TD. Setting the casing as proposed, Forest does not propose to place any cement below 10,900' measured depth to isolate that section of hole. Examination of the mud log provided by Forest shows indications of the presence of gas within that section of hole. Commission regulations require plugging of the uncased portion of a well bore be performed in a manner that ensures that all hydrocarbons are confined to their indigenous strata and are prevented from migrating into other strata or' to the surface. Forest's proposal does not meet the regulatory requirement. If it is Forest's intent to not case the well to TD, then an open hole plug must be set to properly abandon the interval below the casing shoe. If you have any questions, please contact Steve Davies (907-793-1224) or Tom Maunder (907-793-1250) . Sincerely, Steve Davies Petroleum Geologist AOGCC Tom Maunder, P.E. Senior Petroleum Engineer I of I 11/8/20044:16 PM F~ - '" l - "'- -- --1 -- --- E &P SERVICEflNè. TITLE ___ . BY DATE JOB # SHT# : ¡ . , . ; r :) .,:Ji .. ~~D ')4 , ~~J;¡/~. · ~. á'v'- ;~~¡": ....... ¡:/¡(g/~ t/ )... ....."... ...".."". i" ß+()~; : A:. e : " .. .. .. i .. ç.. 1/)1 ...m. ..... .. /..:> ,W.e ,ß ~ .A ~ ç ,t..-- '1 ..... T~ A;~~C'í J.. ~,<lo lJ c:. '#- 4. ...... "" . , . .. ,./, A.:Ie ~ o -r , /6) , ~LJ lk ~.J -...! ·j-;+z ~rfJ " 1l ,,__ c J. -1. .. -: .: £...., 0 -tT""m-¡-~' p ~-~!~Lr"m~ e.o..Þ'"' t:., . fJ A JI.... _ ¡. j:"=, AD a,~"· (L I i t~ ' ,Ill . , /J. i' ~ ~ ~ n~ 1.' ~~ £;, r ~ .1 If "io ../ ~ e~l. V~/(¡ ""/; / r~· i/ /0 16 (~.c '~~. ~ , I I .. .. ........ ........ c/Q II 1~ , .. ( ;). 2..L £,~~ ,/£ t .IL" 1_}.J. j,") ! "r~ ..... : ! 01/~ ,~l ,Ù.i;ZL4~ ~ , ~ ~~±=~t . , : , , , i , , "" , . "m . .. , , u. , , " . . ! .. . ! : . .. ."".. 715 L Street · Anchorage, Alaska 99501 · (907) 258-3446 · FAX (907) 258-5557 650 North Sam Houston Parkway East, Suite 505· Houston, Texas 77060· (281) 445-5711 · FAX (281) 445-3388 RE: West Foreland Well Locations . . Steve, Please give me a little time to look into this. I'll involve the surveyor, get some answers and get back to you on it. Regards, Bill -----Original Message----- From: Stephen Davies [mailto:steve_davies@admin.state.ak.us] Sent: Wednesday, November 03, 2004 9:42 AM To: Bill Penrose Cc: Tom Maunder Subject: West Foreland Well Locations Bill, AOGCC needs to make sure we record the proper surface locations for Forest's West Foreland wells. On Aug. 31 st, you sent an email to Torn Maunder regarding the surface location of West Foreland 1. Attached to that email is a survey plat. The plat shows lat / long, and ASP grid coordinates for the West Foreland 1,2 and "2 ALT." locations, but it does not give surface coordinates in terms of footages from the section lines for any of these locations. Close inspection of the plat (see attached) shows that all three locations have the same "Grid N" coordinates to within 1/1 ,000th of a foot. Note also that the "Grid E" coordinates for each location all end in ".370", indicating that the locations were staked precisely 30 feet or 40 feet apart along the same grid line, respectively (again accuracy to the nearest 1/1000th of a foot). I'm not a land surveyor, but such precision of placement seems statistically unlikely. The surface locations provided on Forest's applications for Permit to Drill for the West Foreland 2 and the deepened West Foreland 2 don't agree. The West Foreland 2 Permit to Drill application submitted by Forest on August 30, 2004 lists the surface location at 886 FSL and 571 FEL of Section 21, T8N, RI4W, SM and ASP zone 4 coordinates of X = 190,452 and Y = 2,475,582, while the Permit to Drill application submitted by Forest on October 30,2004 for the deepening ofthis same well lists 880 FSL and 631 FEL of Section 21, T8N, RI4W, SM with ASP zone 4 coordinates of X = 190,391 and Y = 2,475,578. I believe the application submitted August 30th gives the correct coordinates, but need confirmation from you. Questions: To ensure the accuracy of our files, 1. Could you tell us which location (2 or 2 AL T) is the actual location of the West Foreland 2 well? 2. Could you check to see if the Grid N and Grid E values are indeed correct? 3. Could you provide me a listing of the coordinates of the actual surface locations for lof2 11/9/2004 9: 14 AM RE: West Foreland Well Locations . . West Foreland 1 and West Foreland 2 in terms of footages from section lines, ASP, and lat / long, so that I can ensure that the Commission's records are correct? Thanks, Steve Davies AOGCC 20f2 1119/20049:14 AM ~~~Jt . f!)lç _,..' J % - fA\Céi? -.1 m lA ..c", ¡þ~ r:))J\\ ¡þ,j . / / l FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. OIL Al\ID GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Leonard Gurule Senior Vice President Forest Oil Corporation 310 K Street, Suite 700 Anchorage, Alaska 99501 Re: West Foreland #2 (revised) Forest Oil Corporation Pennit No: 204-143 Surface Location: 886' FSL, 571' FEL, SEC. 21, T8N, R14W, SM Bottomhole Location: 900' FNL, 1150' FEL, SEC. 21, T8N, R14W, SM Dear Mr. Gurule: Enclosed is the Hrvised approved application for pennit to drill the above referenced development well. This revision was necessary due to Forest's desire to increase the previously pennitted depth by more than 500' per 20 AAC 25.0l5(b)(l). The pennit is approved subject to full compliance with 20 AAC 25.055. Be advised that Conservation Order No. 532 (CO 532) does not apply to the additional wellbore section. Approval to perforate and test or produce any intervals in the additional wellbore section is contingent upon issuance of a conservation order approving a spacing exception for that wellbore section. forest Oil Corporation assumes the liability of any protest to the spacing exception that may occur. This pennit to drill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit 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 tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) ours notice for a representative of the Commission to witness any required test. Contact the Co mi sion' s petroleum field inspector at (907) 659-3607 (pager). BY ORDER OF THE COMMISSION DATED this Vday of November, 2004 cc: Department ofFish & Game, Habitat Section wlo enc!. Department of Environmental Conservation wlo enc!. @ e FOREST OIL e CORPORATION ,'110 QY-{Q9ÎJ<PÆ£:. ~b~e 700 Q9tnckJ!'allÆ~ QQŽ/a,Jka .9.9/i01 (207) 2.58-8000 · (.907) 258-/J'001 (Q'Paû:) October 29,2004 \~:"'\:.~i':-''''''; -~ ~- ':'-;¡-i, :<,~,f:'~- Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 ,," RE: Application for Permit to Drill: Deepening of West Foreland #2 Well Dear Commissioner Norman, By this Application for Permit to Drill, Forest Oil Corporation ("Forest") hereby requests authorization to proceed past the currently permitted total depth ("TD") for its West Foreland ("WF") #2 well. Drilling operations are presently underway on the WF #2 well as authorized by PTD No. 204-143. ../ The WF #2 has attained its initially-permitted TD and wire line logs are being run. It is apparent that not all of the gas bearing and potentially gas bearing sands of the Tyonek interval have yet been penetrated. Forest proposes to extend the TD of the WF #2 well to the anticipated top of the Hemlock Formation which coincides with the base of the Tyonek. The proposed new TD is 11,500'MD, 9,930'TVD. To achieve this depth, drilling will be continued along the wellbore's current trajectory to the new permitted TD, .' yielding the bottomhole location indicated on the attached Form 10-401. Enclosed please find a completed Form 10-401 and a check in the amount of $100.00 payable to the State of Alaska. If you have any questions or require additional information concerning this application, please contact Chuck Wilson at (303) 812-1661 or Bill Penrose at (907) 250-3113. Sincerely, FOREST OIL CORPORATION 'f}~ Jim Arlington .. Land Manager enclosure ORI~ ·fllL ~:, ~- - - ~; ;. ,", '. '\ ,I...; ¡\¿F~ . _ STATE OF ALASKA a "-KA Oil AND GAS CONSERVATION C~ISSION PERMIT TO DRILL 20 AAC 25.005 11 b. Current Well Class: Exploratory U Development Oil 0 Multiple Zone 0 Stratigraphic Test 0 Service D Development Gas 0 Single Zone 0 5. Bond: Blanket 0 Single Well 0 11. Well Name and Number: Bond No. RLB0001940 ($200,000) WF #2 6. Proposed Depth: 11,57:£:/ 7: 93ê/ 12. Field/Pool(s): MD: ,..1D1649' .,,¿,l> TVD: ~ 7. Property Designation: /1- I-.:><f - West Foreland A-035017 (surface) & ADL-359112 8. Land Use Permit: 13. Approximate Spud Date: Salamatof Native Association, Inc. Sept. 17, 2004 9. Acres in Property: 14. Distance to Nearest ADL-359112 = 2,155 acres Property: -293' @ 9,400' 10. KB Elevation 15. Distance to Nearest Well (Height above GL): 25 feet Within Pool: -2,SSO' @ 9,400' 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4,224 psi Surface: 3,311 psi Setting Depth Quantity of Cement c.f. or sacks 1a. Type of Work: Drill 0 Redrill U Re-entry D 2. Operator Name: Forest Oil Corporation 3. Address: 310 K Street, Suite 700, Anchorage, Alaska 99501 4a. Location of Well (Governmental Section): Surface: tjf,t.~FSL,~FEL, Sec. 21, TSN, R14~, SM Top of Productive Horizon: 57/1' )J> 1(' /.0'1 9,150' TVDss; 10,351' MD @ 9,400' Sand Total Depth: 900' FNL, 1150' FEL, Sec. 21, TSN, R14W, SM 4b. Location of Well (State Base Plane Coordinates): Surface:x- 190391 y- 2475578 Zone- 16. Deviated wells: Kickoff depth: 5,305 feet Maximum Hole Angle: 47 degrees 18. Casing Program: Size Casing Specifications Hole Grade Coupling Weight Length 9-7/S" 9-7/S" 7-5/S" 29.7# 29# P-110 N-SO Hydril521 LTC 2,975' S,500' 7" Æy) Top Bottom MD TVD (including stage data) MD TVD 25' 3,000' 3,000' 11,500 N/A 2,250 cu ft Class G 25' 3,000' 3000' 9,930' 19. Total Depth MD (ft): PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Filing Fee L:J ...~~,qk~tjfJ~,..~ogram U Property Plat 0 Diverter Sk,.tçh,~ Seabed Report 0 21. Verbal Approval: Commission Representative: 22, I hereby certify that the foregoing is true and correct to the best of my knowledge. Le.n~~ ¡f TIlle Senl., Vice President 8lg",lme ~~ ~ é /¡f~::~:use 0"" (907) 868-2150 Permit to Drill IAPI Number: . .1 Permit Approval Number: .:lC'St/~3 50- 133 -- .2DS'/z.-cc> Date: /1/';;"/0/ Conditions of approval: Samp s req ired Yes 0 No Hy gen s Ifide measures Yes 0 No Other: ~. .', . ~., . '~II to '-\. a.S?~\"'ð'V~\ Approve v: Form -401 R~1212003 Casing Structural Conductor Surface Intermediate Production Liner Length Size 120' 2,97S' 20" 13-3/S" \: ;. Perforation Depth MD (ft): 20. Attachments: Printed Name Cement Volume MD TVD Driven 761 sx G lead, 50S sx G tail 145' 3,003' 145' 3,000' Perforation Depth TVD (ft): Time v. Depth Plot U Shallow Hazard Analysis U Drilling Fluid Program 0 20 AAC 25.050 requirements 0 Date Contact Date /~9'/9Î I See cover letter for other requirements. œJ Mud log required ~ Directional survey required ~\\ \\ ~t>Þ \'-1 BY OI~.DER ~F JH~ fOt~ISf'0N Yes 'rgI No Yes ø No o o Date: #'f Submit inDuplicate L,...~ N .,\ T8N, R14W, e . Forest Oil Alaska Cook Inlet West Foreland #2 - Projection to 9930' 7:. 4 ctober, 2004 ,",~.'¡-<11, _~~-~:,\t'",,;i 75581.63 N, 190452.37 E (60045' 53.5587" N, 151043' 52.3930" W) d Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Structure: 30.63 N, 79.63 W (Grid) Kelly Bushing Elevation: 111.1Oft above Mean Sea Level Kelly Bushing Elevation: 111.1Oft above Structure ""'1 -r-"'''''''Y-5U'' DRILLING seAVlc:es A Halliburton Company Survey Ref: svy117 e e Forest Oil Survey Report for West Foreland #2 Rec Alaska Cook Inlet Measured Grid Vertical Closure Vertical Dogleg Depth Incl. Azim. Depth Northings Eastings Distance Direct'n Section Rate (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) Gyrodata Surveys 0.00 0.000 0.000 0.00 O.OON 0.00 E 0.00 0.000 0.00 100.00 1.110 16.670 99.99 0.93N 0.28 E 0.97 16.670 0.88 1.110 200.00 2.040 43.030 199.96 3.16 N 1.77 E 3.62 29.282 2.88 1.156 300.00 2.660 51.090 299.87 5.92 N 4.79E 7.61 39.001 5.19 0.701 400.00 4.360 68.410 399.68 8.77 N 10.13E 13.40 49.113 7.28 1.985 500.00 4.930 62.870 499.35 12.13N 17.49 E 21.28 55,257 600.00 4.660 64.240 599.00 15.86 N 24,97 E 29.58 57.589 700.00 4.160 72.800 698.71 18.69 N 32.10 E 37.14 59.783 800.00 1.770 130.340 798.59 18.77 N 36.74 E 41.25 62.943 900.00 2.210 127.680 898.53 16.59 N 39.44 E 42.79 67.191 1000.00 2.170 116.730 998.45 14.56 N 42.66 E 45.07 1100.00 1.740 102.850 1098.39 13.37 N 45.83 E 47.74 1200.00 2.410 24.370 1198.35 14.95 N 48.18 E 50.44 1300.00 2.140 347.190 1298.27 18.68 N 48.63 E 52.1~ 1400.00 1.910 348.530 1398.21 22.14 N 47.89 E 1500.00 1.790 356.980 1498.16 25.33 N 61.918 18.48 0.298 1600.00 1.360 357.100 1598.12 28.07 N 59.326 21.21 0.430 1700.00 1.130 7.120 1698.10 30.24 N 57.462 23.35 0.316 1800.00 0.480 49.520 1798.09 31.49 N 56.644 24.52 0.840 1900.00 1.180 83.260 1898.08 31.88 57.045 24.73 0.825 2000.00 0.990 91.420 60.25 57.941 24.56 0.244 2100.00 0.990 11 .400 61.56 57.801 25.24 1.273 2200.00 1.390 4.500 62.91 56.345 27.23 0.424 2300,00 1.370 4.230 64.42 54.657 29.59 0.021 2400.00 0.990 15.000 65.86 53.376 31.55 0.438 2500.00 40.84 N 53.33 E 67.17 52.557 33.02 0.140 2600.00 42.43 N 54.22 E 68.85 51.957 34.47 0.476 2700.00 44.08 N 56.21 E 71.44 51.897 35.83 0.831 2800.00 45.45 N 59.18 E 74.62 52.477 36.77 0.366 2867.00 46.33 N 61.58 E 77.06 53.044 37.31 0.627 70.352 2953.92 47.47 N 64.74 E 80.28 53.748 38.00 0.516 70.831 3042.57 48.50 N 67.67 E 83.26 54.369 38.61 0.181 71.150 3104.08 49.25 N 69,85 E 85.47 54.811 39.05 0.180 72.630 3159.68 49.82 N 71.57 E 87.21 55.158 39.38 1.189 136.680 3217.34 49.90 N 72.45 E 87.98 55.443 39.33 2.444 3281.36 0.810 221.820 3278.97 49.42 N 72.32 E 87.59 55.653 38.87 1.422 3362.57 1.880 242.810 3360.15 48.38 N 70,75 E 85.71 55.633 38,06 1.429 3404.57 1.860 243.240 3402.13 47.76 N 69.53 E 84.35 55.514 37.62 0.058 3485.81 1.840 241.940 3483.33 46.55 N 67,20 E 81.75 55,287 36.75 0.057 3527.82 1.910 239.940 3525.32 45.89 N 66.00 E 80.38 55.191 36.25 0.228 3608.90 1.730 244.310 3606.35 44.68 N 63.73 E 77.83 54.966 35.37 0.280 3650.95 1.790 247.020 3648.38 44.15 N 62.55 E 76.56 54.786 35.01 0.244 3712.64 1.800 249.960 3710.04 43.44 N 60.75 E 74.68 54.435 34.56 0.150 3774.29 1.580 254.890 3771.67 42.88 N 59.02 E 72.96 53.998 34.25 0.427 3835.98 1.550 256.660 3833.33 42.47 N 57.39 E 71.39 53.497 34.07 0.092 29 October, 2004 -13:12 Page 2 of 5 DrillQuest 3.03.06.006 e e Forest Oil Survey Report for West Foreland #2 Rec Alaska Cook Inlet Measured Grid Vertical Closure Vertical Dogleg Depth Incl. Azim. Depth Northings Eastings Distance Direcfn Section Rate (ft) (ft) (ft) (ft) (ft) (ft) (°/1000) 3897.72 1.520 249.760 3895.05 41.99 N 55.81 E 69.84 53.039 33.82 0.303 3959.37 1.510 255.450 3956.68 41.51 N 54.25 E 68.31 52.582 33.55 0.244 4021.03 1.520 254.510 4018.32 41.08N 52.68 E 66.81 52.049 33.35 0.043 4082.70 1.410 245.870 4079.97 40.56 N 51.20 E 65.32 51.616 33.04 0.400 4144.29 1 .460 253.580 4141.54 40.02 N 49.75 E 63.86 51.185 32.71 0.324 4205.80 0.990 248.790 4203.04 39.61 N 48.51 E 62.63 50.765 32.47 0.781 4267,51 1.180 251.000 4264.74 39.21 N 47.41 E 61.52 50.407 32.23 0.315 4329.20 1.190 244.380 4326.41 38.73 N 46.23 E 60.31 50.048 31.92 0.222 4390.85 1.340 247.370 4388.05 38.17 N 44.99 E 59,00 49.685 31.54 0.266 4452.50 1.180 258.400 4449.68 37.77 N 43.70 E 57.76 49,166 31.32 O. 0 4514,01 1.020 252.040 4511.18 37.47 N 42.56 E 56.71 4575.72 0.910 262.040 4572.88 37.23 N 41,55 E 55.79 4637.25 1.080 260.530 4634.40 37.07 N 40.50 E 54.90 4698.83 0.990 255.240 4695.97 36.84 N 39.41 E 53.95 4760.46 0.990 266.490 4757.59 36.67 N 38.36 E 53.07 4822.05 0.960 267.880 4819.17 36.62 N 52.2~ 45.540 0.062 4883.57 1.050 264.500 4880.69 36.55 N 44.759 0.175 4944.92 0.910 265.680 4942.03 36.46 N 43.991 0.231 5012.07 0.880 267.620 5009.17 36.40 N 43.176 0.063 5073.69 0.770 278.960 5070.78 36.44 N 42.393 0.319 5135.15 0.500 285.030 5132.24 41.712 31.68 0.452 5196.72 0.620 271.260 5193.80 41.131 31.84 0.292 5258.36 1.010 274.260 5255.44 40.309 32.01 0.636 5319.85 1.030 325.090 5316.92 39,147 32.62 1.424 5381.29 2.180 342.130 5378.34 37.371 34.26 2.006 5442.75 3.070 28.63 E 50.33 34.664 37.01 1.480 5504.35 3.560 27.34 E 52.42 31 .444 40.48 0.812 5565.95 4.050 26.25 E 55.27 28.348 44,52 1,232 5627.53 4.580 25.23 E 58.85 25.386 49.13 0.901 5689.05 4.790 23.87 E 62.72 22.371 54.11 0.609 63.42 N 22.25 E 67.21 19.332 59.70 1.646 70.08 N 20.33 E 72.96 16.175 66.56 2.229 77.67 N 18.17 E 79.77 13.169 74.38 0.716 85.86 N 16.06 E 87.35 10.596 82.79 1.165 95.09 N 14.27 E 96.16 8.534 92.18 2.086 352.980 6050.92 105.58 N 12.82 E 106.35 6.925 102.77 1.948 350.570 6111.36 116.94 N 11.17E 117.47 5.458 114.25 1.168 347.000 6171.55 129.51 N 8.65E 129.80 3.820 127.05 3.435 344.880 6231.16 144.27 N 4.93E 144.36 1.955 142.18 4.343 344.370 6290.12 161.48 N 0.19E 161.48 0.066 159.89 3.919 6365.91 19.300 345.320 6348.63 180.57 N 4.98W 180.64 358.421 179.51 2.083 6427.53 20.170 345.380 6406.63 200.70 N 10.24 W 200.96 357.079 200.18 1.412 6489.07 20.980 345.800 6464.24 221.65 N 15.62 W 222.20 355.969 221.67 1.338 6550.56 22.570 345.840 6521.34 243.76 N 21.21 W 244.69 355.028 244.34 2.586 6612.07 24.150 345.060 6577.81 267.37 N 27.34 W 268.76 354.162 268.57 2.617 6673.60 25.550 344,670 6633.64 292.33 N 34.09 W 294.31 353.348 294.23 2.291 6735.05 26.610 344.250 6688.83 318.36 N 41.33 W 321.03 352.603 321.01 1.751 6796.55 28.310 345.060 6743.40 345.70 N 48.83 W 349.14 351.960 349.13 2,830 6858.08 28.770 344.540 6797.45 374.07 N 56.54 W 378.32 351.405 378.30 0.850 6919.58 29.880 345.680 6851.07 403.18 N 64.27 W 408.27 350.942 408.20 2.020 29 October, 2004 -13:12 Page 3 of 5 DrillQuest 3.03.06.006 e e Forest Oil Survey Report for West Foreland #2 Ree Alaska Cook Inlet Measured Grid Vertical Closure Vertical Dogleg Depth Incl. Azim. Depth Northings Eastings Distance Direct'n Section Rate (ft) (ft) (ft) (ft) (ft) (ft) (°/1000) 6981.09 31.390 345.870 6904.00 433.56 N 71.97W 439.50 350.574 439.36 2.460 7042.25 32.970 346.310 6955.76 465.18 N 79.80 W 471.97 350.266 471.76 2.612 7103.77 34,460 347.130 7006.93 498.41 N 87.64 W 506.06 350.027 505.76 2.532 7165.15 35.520 347.620 7057.22 532,76 N 95.33 W 541.22 349.855 540.84 1.787 7226.48 38.300 348.270 7106.25 568.78 N 103.02 W 578.03 349,734 577.58 4.577 7287.85 39.860 347.300 7153.89 606.59 N 111,21 W 616.69 349.611 616.16 2.730 7349.22 41.310 347.070 7200.49 645.52 N 120.06 W 656.59 349.464 655.94 2.375 7410.63 42.270 347.150 7246.28 685.41 N 129.19W 697.48 349.326 696.72 1.566 7472.07 44.720 347.310 7290.85 726.65 N 138.54 W 739.74 349.206 738.86 3.992 7533.56 46.140 347.500 7334.00 769.40 N 148.09 W 783.52 349.105 782.52 2. 0 7595.05 46.710 347.820 7376.38 812.92 N 157.61 W 828.05 7655.97 47.570 348.510 7417.82 856.62 N 166.77 W 872.70 7717.40 47.270 348.840 7459.39 900.97 N 175.65 W 917.94 7778.96 46.630 347.230 7501.41 944.98 N 184.97 W 962.91 7840.38 47.720 346,690 7543.16 988.86 N 195.14W 1007.93 7901.92 47.980 347.000 7584.46 1033.29 N 1053.5~ 348.751 0.564 7963.36 48.190 346.960 7625.50 1077.84 N 1 348.677 0.345 8024.85 48.760 347.670 7666.27 1122.75 N 1 348.622 1.267 8086.29 48.540 347.740 7706.86 1167.81 N 348.587 0.368 8147.82 48.280 347.640 7747.70 1212.77 N 348.554 0.440 8209.33 48.000 347.640 7788.75 348.521 1280.82 0.455 8271.31 47.000 348.480 7830.62 348.505 1326.41 1.898 8332.90 48.360 349.890 7872.09 348.528 1371.89 2.782 8398.55 50.160 351.560 7914.93 348.605 1421.62 3.351 8460.13 51.090 352.490 7954.00 348.716 1469.22 1.909 8521.63 52.750 294.60 W 1519.96 348.824 1517.62 2.852 8583.27 52.860 301.30 W 1568.98 348.928 1566.72 1.024 8644.60 53.680 307.59 W 1618,03 349.041 1615.87 1.360 8706.09 51.740 313.81 W 1666.85 349.148 1664.79 3.158 8767.65 49.430 320.41 W 1714.35 349.228 1712.34 4.062 1729.81 N 327.65 W 1760.56 349.274 1758.57 2.138 1774.64 N 334.39 W 1805.87 349.329 1803.91 3.491 1818.27 N 340.43 W 1849.86 349.395 1847,95 2.744 1861.26 N 346.69 W 1893.27 349.449 1891.40 0.411 1902.89 N 353.31 W 1935.42 349.482 1933.55 5.364 350.630 8401.67 1943.26 N 360.09 W 1976.34 349.502 1974.46 0.501 350.830 8447.41 1983.97 N 366.74 W 2017.58 349.527 2015.70 0.856 351.370 8493.41 2024.37 N 373.06 W 2058.46 349.558 2056.59 2.238 351.900 8539.92 2064.15 N 378.91 W 2098.64 349.598 2096.79 0.705 352.240 8587.20 2103.16 N 384.35 W 2137.99 349.644 2136.19 2.962 9444.37 40.210 353.040 8634.51 2141.92 N 389.35 W 2177.02 349.697 2175.26 2.290 9505.93 43.050 353.490 8680.52 2182.53 N 394.14 W 2217.83 349.763 2216.15 4.639 9567.46 44.960 353.370 8724.78 2224,99 N 399.04 W 2260.49 349.833 2258.88 3.107 9629.03 46.910 353.120 8767.60 2268.93 N 404.24 W 2304,66 349.898 2303,10 3.181 9690.58 49.080 352.560 8808.78 2314.30 N 409.95 W 2350.33 349.955 2348.83 3.590 9752.03 49.400 353.280 8848.90 2360.49 N 415.68 W 2396.81 350.013 2395.37 1.029 9813.53 50.800 353.360 8888.35 2407.35 N 421.17W 2443.92 350.076 2442.54 2.279 9875.03 50.530 354.350 8927.33 2454,64 N 426.26 W 2491.38 350,149 2490.08 1.320 9936.61 50.510 355.470 8966.49 2501.99 N 430.48 W 2538.75 350.238 2537.55 1 .404 9998.11 50.970 355.140 9005.41 2549.44 N 434.38 W 2586.18 350.331 2585.09 0.856 29 October, 2004 -13:12 Page4of5 DrillQuest 3.03.06.006 e e Forest Oil Survey Report for West Foreland #2 Rec Alaska Cook Inlet Measured Grid Vertical Closure Vertical Dogleg Depth Incl. Azim. Depth Northings Eastings Distance Direct'n Section Rate (ft) (ft) (ft) (ft) (ft) (ft) (0/10Oft) 10059.66 51.060 355.350 9044.13 2597.12 N 438.34 W 2633.86 350.420 2632.85 0.303 10121.17 50.910 355.260 9082.85 2644.76 N 442.25 W 2681.48 350.507 2680.57 0.269 10182.65 51.030 356.000 9121.57 2692.37 N 445.89 W 2729.05 350,596 2728.23 0.955 10243.73 50.460 356.050 9160.22 2739.56 N 449.17W 2776.14 350.689 2775.41 0.935 10305.21 50.390 356.200 9199.38 2786.84 N 452,37 W 2823.31 350.780 2822.67 0.220 10366.82 50.220 355.810 9238.73 2834.13 N 455.68 W 2870.53 350.866 2869.96 0.560 10428.26 50.510 356.180 9277.93 2881.33 N 458.98 W 2917.66 350.949 2917.17 0.662 10489.71 50.440 357.440 9317.04 2928.65 N 461.62 W 2964.81 351.043 2964.40 1.586 10551.07 50.600 358.230 9356.05 2975.98 N 463.41 W 3011.84 351.149 3011.51 1.027 10612.62 52.320 359.060 9394.40 3024.11 N 464.54 W 3059.58 351.267 3059.33 2. 7 10657.63 53.330 359.030 9421.59 3059.96 N 465.14 W 3095.11 351.357 10717.00 53.330 359.030 9457.05 3107.58 N 465.95 W 3142.31 351.473 11508.94 53.330 359.030 9930.00 3742.69 N 476.70 W 3772.93 352.741 All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to Grid North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. ... The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 352.000° (Grid). Coordinate System is NAD27 Alaska State Planes, Zone 4. Grid Convergence at Surface is -1.511°. Based upon Minimum Curvature type calculations, at a Measured The Bottom Hole Displacement is 3772.93ft., in the Direction of 35 Comments Measured Depth (ft) Comment 465.95 W 476.70 W Projection to Bit at 10717' MD Projection to 9930' TVD - Maintaing current Trend 29 October, 2004 -13:12 PageS of 5 DrillQuest 3.03.06.006 [Fwd: RE: West Foreland #2 deepening] Î e . Jody, John wanted me to be sure to forward you this message. Tom -------- Original Message -------- Subject: RE: West Foreland #2 deepening Date: Fri, 29 Oct 2004 20:48:41 -0600 From: Jim Arlington <JDArlington@forestoil.com> To: 'Thomas Maunder' <tom maunder@admin.state.ak.us> CC: Steve Davies <steve davies@admin.state.ak.us>, John D Hartz <jack hartz@admin.state.ak.us>, Robert Mintz <robert mintz@law.state.ak.us>, Leonard Gurule <LCGurule@forestoil.com>, Bob Elder <RGElder@forestoil.com>, Chuck Wilson <CHWilson@forestoil.com>, Larry Casarta <LJCasarta@forestoil.com>, Tim Berge <TBBerge@forestoil.com>, Ted Kramer <TEKramer@forestoil.com>, Bill Penrose <bill@fairweather.com> - Gentlemen, THANK YOU very much for your time and effort in this matter! Bill Penrose will have our transmittal/application letter and the new APD to deliver to Tom Maunder this weekend, along with the $100.00 check of course. CIRI, BLM and ADEC have been contacted regarding this new APD. As you have seen in the email sent by the ADEC wherein they said "Based on this further determination by Steve Davies at AOGCC, our approval of your c-plan amendment for the Forest Oil plan remains valid. Our approval letter, dated September 13, 2004, approved a gas well at the West Forelands #2 pad, with a response planning standard of zero, based on information received from AOGCC. This information has not changed, and therefore the c-plan approval remains valid as written." The other items will be taken care of next week. Have a great Halloween weekend! Be safe! Jim Arlington -----Original Message----- *From:* Thomas Maunder [mailto:tom maunder@admin.state.ak.us] *Sent:* Friday, October 29, 2004 4:22 PM *To:* Jim Arlington *Cc:* Steve Davies; John D Hartz; Robert Mintz *Subject:* West Foreland #2 deepening Jim, This message confirms your conversation with Jack Hartz, Steve Davies and myself regarding drilling the West Foreland #2 well deeper than the presently permitted 10f2 1111/20047:29 AM [Fwd: RE: West Foreland #2 deepening] , ~ e e depth of 10649' md, 9445' tvd. Forest proposes to drill to approximately 11500' md, 9930' tvd. It is proposed to drill deeper due to the probability of encountering additional prospective gas pay sands. Your operations geologist indicated that there is no possibility of encountering liquid hydrocarbons in the new section. Drilling deeper than presently permitted requires that Forest submit a new 401 application with $100 check and initiate a new spacing exception process. A new spacing exception is needed due to the ownership change within the onshore federal lease in the new section and since ConocoPhillips is not party to the present spacing exception. Commissioner Norman has authorized me to send the following. Forest may continue drilling below the presently permitted depth of 10649' md, 9445' tvd in the West Foreland #2 well, subject to the following conditions: 1. Forest assumes all liability for drilling below the presently permitted depth of West Foreland 2 (204-143) without a spacing exception. 2. Authorization is given to drill, log and case the well. Forest may not open the well bore to test or regular production until a spacing exception is approved. 3. Forest acknowledges that there is no assurance that a spacing exception will be granted and will hold the Commission harmless from any loss or damages incurred by Forest if an exception is not approved. 4. Forest must submit a new permit to drill application by the close of business on Monday, November I, 2004. 5. Forest must apply for a new spacing exception for the well on or before Friday, November 5, 2004. 6. Forest must call ADEC immediately, and drilling deeper cannot proceed until all C-Plan issues are resolved with ADEC. 7. Forest must contact the offset owners and landowners as soon as possible. 8. Forest must continue to employ full mud logging services (including gas sensors) and insure that all equipment is fully operational while drilling below the presently permitted depth of West Foreland 2. 9. Forest must immediately cease all drilling operations and notify ADEC and AOGCC if any indication of liquid hydrocarbons is encountered in the well bore. 10. Drilling operations must cease prior to reaching the top of the Hemlock Formation. Please confirm receipt of this message by return email. If it is necessary, you may contact me at 345-0850 or cell number 441-2651 over the weekend. Tom Maunder, PE AOGCC 2of2 11/1/20047:29 AM I @ e FOREST OIL e CORPORATION ,; .'l10 dYC 6liJ<PÆt. ¿¡¡;-uw 700 C29tu:iuM<a:7Æ, Q91k,4ka .9.9.5"01 (.907) 258-86'00 · (.907) 258-86'01 (r:;}Pax) October 29,2004 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Drill: Deepening of West Foreland #2 Well Dear Commissioner Norman, By this Application for Permit to Drill, Forest Oil Corporation ("Forest") hereby requests authorization to proceed past the currently permitted total depth ("TD") for its West Foreland ("WF") #2 well. Drilling operations are presently underway on the WF #2 well as authorized by PTD No. 204-143. The WF #2 has attained its initially-permitted TD and wireline logs are being run. It is apparent that not all of the gas bearing and potentially gas bearing sands of the Tyonek interval have yet been penetrated. Forest proposes to extend the TD of the WF #2 well to the anticipated top of the Hemlock Formation which coincides with the base of the Tyonek. The proposed new TD is 11,500'MD, 9,930'TVD. To achieve this depth, drilling will be continued along the wellbore's current trajectory to the new permitted TD, yielding the bottomhole location indicated on the attached Form 10-401. Enclosed please find a completed Form 10-401 and a check in the amount of $100.00 payable to the State of Alaska. If you have any questions or require additional information concerning this application, please contact Chuck Wilson at (303) 812-1661 or Bill Penrose at (907) 250-3113. Sincerely, FOREST OIL CORPORATION y} Jim Arlington Land Manager enclosure DUPL¡CÞ,TE STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COM.ON PERMIT TO DRILL 20 MC 25.005 1b. Current Well Class: Exploratory 0 Development Oil 0 Multiple Zone 0 Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 0 5. Bond: Blanket 0 Single Well 0 11. Well Name and Number: Bond No. RLB0001940 ($200,000) WF #2 6. Proposed Depth: II SèD' q9..:7,A / 12. Field/Pool(s): /' /' ~) MD: J.O;62f§' .",.6]) TVD: 9,445' 7. Property Designation: 1/' f· t:>,/ A-035017 (surface) & ADL-359112 8. Land Use Permit: 13. Approximate Spud Date: Salamatof Native Association, Inc. Sept. 17,2004 9. Acres in Property: 14. Distance to Nearest ADL-359112 = 2,155 acres Property: -293' @ 9,400' 10. KB Elevation 15. Distance to Nearest Well (Height above GL): 25 feet Within Pool: -2,880' @ 9,400' feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) degrees Downhole: 4,224 psi Surface: 3,311 psi Setting Depth Quantity of Cement c.f. or sacks 1a. Type of Work: Drill 0 Redrill 0 Re-entry 0 2. Operator Name: Forest Oil Corporation 3. Address: 310 K Street, Suite 700, Anchorage, Alaska 99501 4a. Location of Well (Governmental Section): Surface: BfÞ~SL~FEL, Sec. 21, TSN, R14W, SM Top of Productive Horizon: 57/' ,~...D 1(./,0Y. 9,150' TVDss; 10,351' MD @ 9,400' Sand Total Depth: 900' FNL, 1150' FEL, Sec. 21, T8N, R14W, SM 4b. Location of Well (State Base Plane Coordinates): Surface:x- 190391 y- 2475578 Zone- 16. Deviated wells: Kickoff depth: 5,305 Maximum Hole Angle: 47 18. Casing Program: Size Casing Specifications Grade Hole Weight Coupling Length 9-7/8" 9-7/8" 7-5/8" 2,975' 8,500' 29.7# 29# P-110 N-80 Hydril521 LTC 7" West Foreland Top Bottom MD TVD MD (including stage data) TVD 25' 3,000' 3,000' 11 ,500 N/A 2,250 cu ft Class G 25' 3,000' 3000' 9,930' 19. Total Depth MD (ft): PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Size Cement Volume MD 20" Driven 145' 13-3/8" 761 sx G lead, 508 sx G tail 3,003' Filing Fee L:1 ,,~' BOP Sketch L.I IJríning Program U Property Plat 0 Divertet Sketch 0 Seabed Report 0 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowtedge. Leon~~ ¡j TIUe S~nalu," ~þ#o/~ é /¡f~:="", O"~ (907) 868·2150 Permit to Drill API Number:, . . ......IPermit Approval Number: ~SI'·/¥3 50- /33- 2DS'/Z "00 Date: Conditions of approval : Casing Structural Conductor Surface Intermediate Production Liner Length 120' 2,978' Perforation Depth MD (ft): 20. Attachments: Printed Name TVD 145' 3,000' Perforation Depth TVD (ft): Time v. Depth Plot U Shallow Hazard Analysis U Drilling Fluid Program 0 20 AAC 25.050 requirements 0 Date Contact Senior Vice President Date /t9/29þt see cover letter for other requirements. Yes Yes ~ No No o o Samples required <::::\ Hydrogen sulfi~ m~sures Other: '-.C;.;--'c7\~\<J,,",~ ~."" '\, \ Yes 0 No ~ Mud log required . Yes 0 No .~ . Directional survey required t ()t.; ~C>D\O~O \o..pp\"I \ , BY ORDER ðF THE COMMISSION Date: Approved by: Form 10-401 Revised 12/2003 UUPLICATE Submit inDuplicate Page 1 of2 e e Jim Arlington From: Jim Arlington Friday, October 29,20046:49 PM 'Thomas Maunder' Sent: To: Cc: Steve Davies; John D Hartz; Robert Mintz; Leonard Gurule; Bob Elder; Chuck Wilson; Larry Casarta; Tim Berge; Ted Kramer; Bill Penrose Subject: RE: West Foreland #2 deepening Gentlemen, THANK YOU very much for your time and effort in this matter! Bill Penrose will have our transmittal/application letter and the new APD to deliver to Tom Maunder this weekend, along with the $100.00 check of course. COO, BLM and ADEC have been contacted regarding this new APD. As you have seen in the email sent by the ADEC wherein they said "Based on this further determination by Steve Davies at AOGCC, our approval of your c-plan amendment for the Forest Oil plan remains valid. Our approval letter, dated September 13,2004, approved a gas well at the West Forelands #2 pad, with a response planning standard of zero, based on information received from AOGCC. This information has not changed, and therefore the c-plan approval remains valid as written." The other items will be taken care of next week. Have a great Halloween weekend! Be safe! Jim Arlington -----Original Message----- From: Thomas Maunder (mailto:tom_maunder@admin.state.ak.us] Sent: Friday, October 29, 20104 4:22 PM To: Jim Arlington Cc: Steve Davies; John D Hartz; Robert Mintz Subject: West Foreland #2 deepening Jim, This message confirms your conversation with Jack Hartz, Steve Davies and myself regarding drilling the West Foreland #2 well deeper than the presently permitted depth of 10649' md, 9445' tvd. Forest proposes to drill to approximately 11500' md, 9930' tvd. It is proposed to drill deeper due to the probability of encountering additional prospective gas pay sands. Your operations geologist indicated that there is no possibility of encountering liquid hydrocarbons in the new section. Drilling deeper than presently permitted requires that Forest submit a new 401 application with $100 check and initiate a new spacing exception process. A new spacing exception is needed due to the ownership change within the onshore federal lease in the new section and since ConocoPhillips is not party to the present spacing exception. Commissioner Norman has authorized me to send the following. Forest may continue drilling below the presently permitted depth of 10649' md, 9445' tvd in the West Foreland #2 well, subject to the following conditions: 10/29/2004 e Page 2 of2 e 1. Forest assumes all liability for drilling below the presently pennitted depth of West Foreland 2 (204-143) without a spacing exception. 2. Authorization is given to drill, log and case the well. Forest may not open the well bore to test or regular production until a spacing exception is approved. 3. Forest acknowledges that there is no assurance that a spacing exception will be granted and will hold the Commission harmless fÌom any loss or damages incurred by Forest if an exception is not approved. 4. Forest must submit a new pennit to drill application by the close of business on Monday, November 1, 2004. 5. Forest must apply for a new spacing exception for the well on or before Friday, November 5, 2004. 6. Forest must call ADEC immediately, and drilling deeper cannot proceed until all C-Plan issues are resolved with ADEC. 7. Forest must contact the offset owners and landowners as soon as possible. 8. Forest must continue to employ full mud logging services (including gas sensors) and insure that all equipment is fully operational while drilling below the presently pennitted depth of West Foreland 2. 9. Forest must immediately cease all drilling operations and notify ADEC and AOGCC if any indication of liquid hydrocarbons is encountered in the well bore. 10. Drilling operations must cease prior to reaching the top ofthe Hemlock Fonnation. Please confinn receipt of this message by return email. Ifit is necessary, you may contact me at 345-0850 or cell number 441-2651 over the weekend. Tom Maunder, PE AOGCC 10/29/2004 DTS 11/-</9-- Public Commissioner JKN ~~ 1111/2004: Deepening to 11,500' MD (9.930' TVD) of well originally permitted on 9/1/2004 to 10,649' MD (9,445' TVD) SFD. Hemlock Formation will not be penetrated. Mudlog required, but samples not required. AOGCC policy has been to require a mudlog from the first development well drilled from a pad. Adjacent West Foreland 1 well has cuttings samples from 30' to TD, but the well was not mudlogged. SFD Geologic Commissioner: Date: Engineering Commissioner: Date 35 36 37 38 39 Conta.ct namelpJ1onefor.weekly progre~s reports [explorç¡tory .only] .Yes .Yes NA NA Yes Ted Kramer. AK Production Manager. a68-:2:1:37. Appr SFD Date 11/1/2004 .Seç¡bed .conditioo survey (if off-~hore) Seismic analysis. of sbaJlow gaszooes. PeUTIit c.an be .D.ata.preseoted on pote.ntial overpre~sure .zOl1es Will pressure g"adieotexpected: drilli.ng with ppg.mud 10,600' MD, & ooly 7Q- 80 uoits.max.gas. Geology Appr -- Date 8/31/2004 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 issued w!o byd"ogen sulfide measures J~ pre~ence of H2S gas. probable Meçba.nicç¡Lcoodition o{wells within AOR yerified (forservjce we .test to.(put psig in.comments) .Choke.manifold compJies w/API RF>-53 (May 84) Work will occur without.operç¡Uon .shutdown 80PEs,do .80PEpress ra.tiog appropriate; .tbey.meet Jf.diverter required, does it .meet reguJations. .Drilliog fluid program schemç¡tic.& eC.uip Jistadequate re.serye pit If.a.re-driIL has.a. 10-403 for abandonment .Adequate well bore ~eparç¡tion .proposed Adequate tan.kage. or beeo ç¡pproved .C.asing de.sign~ adeQuate for C,T,6&permafrpst .C.MT.~oladeQuate.to CMT.will coyer.all knownpro.ductiye borizon.s known. USDWs .CMT. vol adeQu.ate.to çirculate.oncood.uctor. tie-in long .string to.s!Jd csg. .Cpnductor .S.urface .ca~il1g.protec.t~ all & surf csg .Yes Yes .Yes N.o. .Yes .Yes .Yes NA .Yes .Yes .Yes Yes .Yes .Yes .Yes No .NA 1:i2S monitoring equipm.ent Normç¡1 befUl1ctionin~.at all 10..1 times wJ1i]e. drilling & completing. ~Iow onJyj reguJation CalcuJated.MASP.3311 psi. 5QOO PsiJllitial test 400.0.pS thereafter. Maximum 6l:iP 8.ßEMW, PIç¡l1ned m.ud weigbt.up to. 9.5 ppg. proximity. analY$is perfprme.d, clearance report prepared. WE #1 is Ol)ly I)e.arby weU recently surveyed. Rig is e.quippe.d with steelpjts. No. rese.rv:e.pjtplanoed, Wastes to. Clas.sJ weJI. Any formaUo.n .pre.ssures. s.hould be ofsimilç¡r ~netrate any.hYdrocarbon .othe" than. gas. gradje.nt. NOTE ADDED Deepening. weJI is u.nlikely.to Engineering Appr e 11/1/2004 Date PTD#: 2041430 Administration .U.nique wellnarne.and oumb.er Jo.cated in.a. clefil)e.d .pool Company FOREST OIL CORP Permit fee attaçhed Field & Pool 2 13 14 15 16 17 2 3 4 5 6 7 8 9 10 11 st"illg.provided ACMP Findjng.of Com;istencyhas beeJ1i~sued for.this pr.oject Well Jocated within area and strata authorized by.lnjectioo Ordec # (put 10# .AJI welJs. within .1 l4.mile.area.of reyiew ideotified (For ~ervjcewell Ol1ly). . . Pre-produced injector; duratio.n.of pre-production less. than 3 montbs (For .seryice well only) Can permit be approved before ad.mioíst"ativ:e. approvaJ 15-day wait in commeots) (For .Oper.ator .Ope"ator PeUTIit c.an be issued witbo.ut Permitc.ao be issued witbo.ut bas. appropriate. bond i.nfQrce co.nserva.tiOI1 order ol1ly affected party .S.ufficiel1t .'fdeviated, locatei: e. Jocatei: e. fro.m otber wells ... "",=," ".." ",.....,.". in. drilliog unit js. weJlbo.re plat iocJuded _a"'rð~nø ~\I~p,,",¡"'I~ Wen Well Wen fro.m driJling ul1it b.oUl)dary. .Lease .number .appropriate W FORELAND, UNDEFINED GAS 920500 Initial ClassfType .Yes .Yes .Yes N.o. No No. No. No No .Ye$ No. .Yes No NA .NI\. NA .NA ·ev:ie.w: was completed {or this project bac~ in.1.99a. SFD8l5!2.004 . .8-~~"~\~\'~ ..... 11J02!Q4; Permitted .depth inçreaseddue to favorable drillir¡gto permitted depth.. An ACMP consistency the exception. APpro.val!o deepen given via ern.all by CQmmis~ion on Spacing exception w .be require.dto test 10l29/2004. or pr:oduce weU, .ForesUnc.ur:s.aJI liabjlity o.f drjjng .wjtbQut Two. ~eparately .0wnedJracts witbio a single drilling .unit in .Geoframe. proposed wellboresuryey provjded, .geoe.rated map (Section 21L sm 8cros.sproductiYe intervals .and aUhe.e.xtende.d.TD, well Aboye 710.600'.MO, .wjllbeJess th.an ;30QO' wilJ be lesstban500' from ga.s well open .to same.p.ool.as required. by 20 MC .25.055. Jrompropert~ bO!Jodary, DEV West.Foreland undefined ga~ pop Well Name: W FORELAND 2 Well bore seg 11-GAS GeoArea .820 On Annular Disposal Deepenil19- of previousJy. p.er:n)itted wellbore MD (9A45'JVD). to .11,500' MD(9,930' ND) after .spud. . Surface. loea.tion onsbQre inFed Lease A:035Q17~ top producti\lejoteryal and extended. TD offsbore inADL:359112 Unit from 00000 Q,649' Program DEV On/Off Shore o o [Fwd: [Fwd: West Foreland #2]] . . ~ Jody, Here is another message for the files. This message and the earlier one should likely go to the West Foreland #2 well file and a new file for their next spacing exception. Tom -------- Original Message -------- Subject: [Fwd: West Foreland #2] Date: Fri, 29 Oct 2004 17:41:09 -0800 From: Stephen Davies <steve davies@admin.state.ak.us> Organization: State of Alaska To: John Norman <john norman@admin.state.ak.us>, Daniel Seamount <dan seamount@admin.state.ak.us>, Tom Maunder <tom maunder@admin.state.ak.us>, Rob Mintz <robert mintz@law.state.ak.us>, John Hartz <jack hartz@admin.state.ak.us> FYI, Thanks for your help on this rush request. Steve D. Subject: Date: From: To: CC: <Bill -------- Original Message -------- West Foreland #2 Fri, 29 Oct 2004 17:36:58 -0800 Miner, Lydia <Lydia Miner@dec.state.ak.us> 'rgelder@forestoil.com' <rgelder@forestoil.com> 'Stephen Davies' <steve davies@admin.state.ak.us>, "Hutmacher, Bill" Hutmacher@dec.state.ak.us>, "Ballard, Kirsten" <Kirsten Ballard@dec.state.ak.us> Bob: Based on this further determination by Steve Davies at AOGCC, our approval of your c-plan amendment for the Forest Oil plan remains valid. Our approval letter, dated September 13, 2004, approved a gas well at the West Forelands #2 pad, with a response planning standard of zero, based on information received from AOGCC. This information has not changed, and therefore the c-plan approval remains valid as written. With this email, AOGCC's Condition #1 below has been met. Regarding AOGCC's Condition #3, if any indication of liquid hydrocarbons is encountered in the well bore, DEC must be notified immediately and drilling operations must cease until C-plan and financial responsibility approvals must be obtained before proceeding. Please let me know if you have any questions. Lydia Miner** Alaska Department of Environmental Conservation Exploration, Production & Refineries Section Manager 555 Cordova Street Anchorage, AX 99501 Ph: (907) 269-7680 Fax: (907) 269-7687 Email: lydiaminer@dec.state.ak.us -------- Original Message -------- Subj ect: [Fwd: West Foreland #2] Date: Fri, 29 Oct 2004 17:21:32 -0800 From: Stephen Davies <steve davies@admin.state.ak.us> Organization: State of Alaska To: Lydia M Miner <lydia miner@dec.state.ak.us> 100 1111120047:29 AM [Fwd: [Fwd: West Foreland #2]] - . . VCC: John Norman <john norman@admin.state.ak.us>, Daniel Seamount <dan seamount@admin.state.ak.us>, Rob Mintz <Robert Mintz@law.state.ak.us>, Tom Maunder <tom maunder@admin.state.ak.us> Lydia, Jim Arlington of Forest Oil phoned the Alaska Oil and Gas Conservation Commission ("Commission") this afternoon and spoke with Tom Maunder, Jack Hartz, and me. He indicated Forest has reached the permitted total depth of the West Foreland #2 well, and based on promising drilling results, that Forest would like to deepen the well an additional 400 to 500 true vertical feet. On September 1, 2004, I completed an assessment of the potential for the West Foreland #2 well to encounter oil or oil-bearing formations from the surface to the originally permitted total depth of the well. For that assessment, I examined the Commission's records for the nearby West Foreland #1 exploratory well. My assessment contains the following statements: "Within the well history file [for West Foreland #1], there is no mention of oil or other liquid hydrocarbons. On the well site sample description log, the shallowest indication of liquid hydrocarbons is mention of solvent cut at 10,980', which is in the West Foreland formation, approximately 1,500' deeper than the proposed TD of West Foreland #2." and "Summary The proposed West Foreland #2 well will reach total depth in the Tyonek, approximately 1,500' above oil indicators in the West Foreland. Based on previous drilling and the information supplied by Forest, the proposed drilling, testing and production activities in West Foreland #2 well are unlikely to encounter oil or oil-bearing formations between the surface and the permitted total depth of the well." Forest now proposes to drill an additional 400 to 500 true vertical feet deeper than the originally permitted depth of the West Foreland #2 well. The deepened well bore will drill only Tyonek Formation: it will not penetrate the Hemlock. This deepened well bore will still lie about 1,000 true vertical feet above the shallowest indication of liquid hydrocarbons in nearby West Foreland #1. Based on the Commission's records, it is my opinion that the proposed drilling activities in the deepened West Foreland #2 well are unlikely to encounter oil or oil-bearing formations between the surface and the revised, deepened total depth of the well. Forest's operations geologist has the same opinion, as stated in his attached email (below). The Commission is granting Forest permission to continue drilling below the presently permitted depth in the West Foreland #2 well, subject to several conditions. Among them are several that are pertinent here: 1. Forest must call ADEC immediately, and drilling deeper cannot proceed until all C-Plan issues are resolved with ADEC. 2. Forest must continue to employ full mud logging services (including gas sensors) and ensure that all equipment is fully operational while drilling below the presently permitted depth of West Foreland #2. 3. Forest must immediately cease all drilling operations and notify ADEC and AOGCC if any indication of liquid hydrocarbons is encountered in the well bore. 4. Drilling operations must cease prior to reaching the top of the Hemlock Formation. Please contact me if you have any questions. Steve Davies Petroleum Geologist -------- Original Message -------- West Forelan #2 Fri, 29 Oct 2004 17:08:19 -0700 (PDT) Larry Casarta <larrycasarta@yahoo.com> steve davies@admin.state.ak.us Subject: Date: From: To: 20f3 111112004 7:29 AM [Fwd: [Fwd: West Foreland #2]] . . I Steve, Based on our analysis, we believe that there is no chance of finding oil above the Hemlock in the Tyonek Formation. Forest Oil will not drill into the Hemlock. I am at the rig site now, so I am using my yahoo email addresss. Best regards, Larry Casarta Sr. Geologist Forest Oil ------------------------------------------------------------------------ Do you Yahoo!? Y! Messenger <http://us.rd.yahoo.com/mail us/taglines/msgr/evt=26088/*http://messenger.yahoo.com> - Communicate in real time. Download now. 30f3 11/1/20047:29 AM [Fwd: [Fwd: West Foreland #2]] . . cc: file -------- Original Message -------- Subject:[Fwd: West Foreland #2] Date:Fri, 29 Oct 2004 17:21 :32 -0800 From:Stephen Davies <steve davies@admin.state.akus> Organization:State of Alaska To:Lydia M Miner <lydia miner(â¿dec.state.akus> CC:John Norman <john norman@admin.state.akus>, Daniel Seamount <dan seamount@admin.state.akus>, Rob Mintz <robert mintz@law.state.akus>, Tom Maunder <tom maunder@admin.state.akus> Lydia, Jim Arlington of Forest Oil phoned the Alaska Oil and Gas Conservation Commission ("Commission") this afternoon and spoke with Tom Maunder, Jack Hartz, and me. He indicated Forest has reached the pemitted total depth of the West Foreland #2 well, and based on promising drilling results, that Forest would like to deepen the well an additional 400 to 500 true vertical feet. On September 1,2004, I completed an assess~nt of the potential for the West Foreland #2 well to encounter oil or oil-bearing formations from the surface to the originally permitted total depth of the well. For that assessment, I examined the Commission's records for the nearby West Foreland #1 exploratory well. My assessment contains the following statements: "Within the well history file [for West Foreland #1], there is no mention of oil or other liquid hydrocarbons. On the well site sample description log, the shallowest indication of liquid hydrocarbons is mention of solvent cut at 10,980', which is in the West Fa-eland formation, approximately 1,500' deeper than the prcposed TD of West Foreland #2." and "Summary The proposed West Foreland #2 well will reach total depth in the Tyonek, approximately 1,500' above oil indicators in the West Foreland. Based on previous drilling and the information supplied by Forest, the proposed drilling, testing and production activities in West Fa-eland #2 well are unlikely to encounter oil or oil-bearing formations between the surface and the pemitted total depth of the well." Forest now proposes to drill an additirna1400 to 500 true vertical feet deeper than the aiginallypermitted depth of the West Foreland #2 well. The deepened well bore will drill only Tyonek Formation: it will not penetrate the Hemlock. This deepened well bore will still lie abæt 1,000 true vertical feet abave the shallowest indication ofliquid hydrocarbons in nearby West Foreland #1. Based on the Commission's records, it is my opinion that the proposed drilling activities in the deepened West Fa-eland #2 well are unlikely to encounter oil or oil-bearing formations between the surface and the revised, deepened total depth of the well. Forest's operations geologist has the same opinion, as stated in his attached ellRil (below). The Commission is granting Forest permission to continue drilling below the presently permitted depth in the lof2 111112004 9:45 AM [Fwd: [Fwd: West Foreland #2]] . . West Foreland #2 well, subject to several conditions. Among them are several that are pertinent here: 1. Forest must call ADEC immediately, and drilling deeper cannot proceed until all C-Plan issues are resolved with ADEC. 2. Forest must continue to employ full mud logging services (including gas sensors) and ensure that all equipment is fully operational while drilling below the presently permitted depth of West Foreland. 3. Forest must immediately cease all drilling operations and notify ADEC and AOGCC if any indication of liquid hydrocarbons is encountered in the well bore. 4. Drilling operations must cease prior to reaching the top of the Hemlock Formation. Please contact me if you have any questions. Steve Davies Petroleum Geologist -------- Original Message -------- Subject:West Forelan #2 Date:Fri, 29 Oct 2004 17:08:19 -0700 (PDT) From:Larry Casarta <larrycasarta@!yahoo.com> To:steve davies@!admin.state.akus Steve, Based on our analysis, we believe that there is no chance of finding oil above the Hemlock in the Tyonek Formation. Forest Oil will not drill into the Hemlock. I am at the rig site now, so I am using my yahoo email addresss. Best regards, Larry Casarta Sr. Geologist Forest Oil Do you Yahoo!? Y! Messenger - Communicate in real titre. Download now. John K. Norman <John Norman@!admin.state.us> Commissioner Alaska Oil & Gas Conservation Commission 20f2 11/1/2004 9:45 AM [Fwd: West Foreland #2 deepening] . . Bob, Attached is AOGCC's email to Jim Arlington. Please send continnation of receipt of this message. Call me at 793-1224 if you have any questions. Thanks, Steve Davies -------- Original Message -------- Subject:West Foreland #2 deepening Date:Fri, 29 Oct 2004 16:21 :38 -0800 From:Thomas Maunder <tom maunder(a¿.admin.state.ak.us> Organization:State of Alaska To:Jim Arlington <JDArlington@forestoil.com> CC:Steve Davies <steve davies(ãf,admin.state.ak.us>, John D Hartz <jack hartzCã¿admin.state.ak.us>, Robert Mintz <robert mintz@law.state.ak.us> Jim, This message confirms your conversation with Jack Hartz, Steve Davies and myself regarding drilling the West Foreland #2 well deeper than the presently permitted depth of 10649' md, 9445' tvd. Forest proposes to drill to approximately 11500' md, 9930' tvd. It is proposed to drill deeper due to the probability of encountering additional prospective gas pay sands. Your operations geologist indicated that there is no possibility of encountering liquid hydrocarbons in the new section. Drilling deeper than presently permitted requires that Forest submit a new 401 application with $100 check and initiate a new spacing exception process. A new spacing exception is needed due to the ownership change within the onshore federal lease in the new section and since ConocoPhillips is not party to the present spacing exception. Commissioner Norman has authorized me to send the following. Forest may continue drilling below the presently permitted depth of 10649' md, 9445' tvd in the West Foreland #2 well, subject to the following conditions: 1. Forest assumes all liability for drilling below the presently permitted depth of West Foreland 2 (204-143) without a spacing exception. 2, Authorization is given to driJl, log and case the well. Forest may not open the well bore to test or regular production until a spacing exception is approved. 3. Forest acknowledges that there is no assurance that a spacing exception will be granted and will hold the Commission harmless from any loss or damages incurred by Forest if an exception is not approved. 4. Forest must submit a new permit to drill application by the close of business on Monday, November 1, 2004. 5. Forest must apply for a new spacing exception for the well on or before Friday, November 5, 2004. 6. Forest must call ADEC immediately, and drilling deeper cannot proceed until all C-Plan issues are resolved lof2 11/12/2004 11: 17 AM [Fwd: West Foreland #2 deepening] . . with ADEC. 7. Forest must contact the offset owners and landowners as soon as possible. 8. Forest must continue to employ full mud logging services (including gas sensors) and insure that all equipment is fully operational while drilling below the presently permitted depth of West Foreland 2. 9. Forest must immediately cease all drilling operations and notify ADEC and AOGCC if any indication of liquid hydrocarbons is encountered in the well bore. 10. Drilling operations must cease prior to reaching the top of the Hemlock Formation. Please confirm receipt of this message by return email. If it is necessary, you may contact me at 345-0850 or cell number 441-2651 over the weekend. Tom Maunder, PE AOGCC 20f2 11/12/2004 11: 17 AM [Fwd: Forest's WF #2] . . cc: file -------- Original Message -------- Subject:Forest's WF #2 Date:Fri, 29 Oct 2004 11 :09: 14 -0800 From:Thomas Maunder <tom maunder@admin.state.ak.us> Organization:State of Alaska To:Steve Davies <steve davies@admin.state.ak.us>, John D Hartz <jack hartz@admin.state.ak.us> CC:Daniel T Seamount JR <dan seamount@admin.state.ak.us>, John Norman <john norman@admin.state.ak.us>, Robert Mintz <robert mintz@law.state.ak.us> FYI. I was contacted this morning by Bill Penrose from Fairweather. He has handled some of the permitting for Forest on this well. They have evidently gotten to the proposed TD, however they believe that there is still the potential to encounter additional deeper gas sands. They evidently are preparing to log. They are proposing to continue drilling to the top of the Hemlock which is projected at 11500' md, 9930' tvd. I pointed out to Bill that there were complications with this proposal since Finding 20 of CO 532 noted that Phillips or a successor had interest in the intervals below 9527' md in WF #1 and since it was proposed to extend more than 500' that a new permit application would be necessary. I have received nothing formal with regard to the proposal. Bill indicated that he would be getting back to Jim Arlington on this matter. It is possible that Forest will contact us today on this. Another Friday Forest Fire!!!! I will keep you all informed. It is my opinion that extending as might be proposed is going to be a complicated issue due to the ownership change. Tom John K. Norman <John Norman@admin.state.us> Commissioner Alaska Oil & Gas Cmservation Commission 1 of 1 11/1/20049:46 AM . @~ /fiI = c rm' ~ ®. '. ~~ ~-« /fiI @ .. lJlJ _ 1: LW J- Ilu~ lfü 2i ~ 'ù /JlJ . '<0'( - Icf 3 AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 F~ (907)276-7542 Paula Inman Alaska Production Engineer Forest Oil Corporation 310 K Street, Suite 700 Anchorage, Alaska 99501 Re: West forelands #2 Sundry Number: 304-369 Dear Ms. Inman: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. The Commission expects Forest Oil Corporation to use absolute best efforts to minimize the volume of gas flared and this approval is so conditioned. Please note all conditions of approval set out in the enclosed fonn. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. BY ORDER OF THE COMMISSION DATED this Z day of October, 2004 Encl. @ . FOREST OIL . CORPORATION .J10Q/C&æt"e ~de 700 Qçxfn~r-af!Ø' Qr;;:t¡;.~Mlca .9.9/iOI (907) 2.5"8-8600 e (907) 258-8601 (dØŒr) October 1,2004 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 RECEIVED OCT 04 2004 RE: Application for Sundry Approval to Flare: West Foreland #2 Alaska Oil & Gas Cons, Commission Anchorage Dear Mr. Norman, Please find enclosed an Application for Sundry Approval for Forest Oil Corporation to flare produced gas during initial production testing of its West Forelands #2 gas production well which is currently being drilled. Testing of the WF#2 will be conducted after drilling operations are finished and before completing the well for production. Two zones will be tested. It is estimated that the absolute open flow potential for each zone will be 8 MMSCFPD. After clean-up, each zone will be either shut in for a build-up followed by conducting a 4-point test or by conducting a 4-point test then shutting in the zone for the build-up. The duration of testing is anticipated to be a total of 48 hours for both zones. After testing, if the gas proves to be of good quality, it will be placed into an existing pipeline for sales. If you have any questions or require additional information, please contact me at 868- 2135. Sincerely, FOREST OIL CORPORATION ~~ Paula Inman Alaska Production Engineer Enclosure nD''''''''^' ~ 1. Type of Request: . STATE OF ALASKA _ ALA. OIL AND GAS CONSERVATION COM~ION APPLICATION FOR SUNDRY APPROVAiRECEIVED 20 AAC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: ~O('-t Abandon U Alter casing D Change approved program D 2. Operator Name: Suspend U Repair well D Pull Tubing D Perforate U 0 C 1vßtJ @OÆnnular Dispos. U Stimulate qslc]~lI ~ffi~oe~. CommissioYlther [] Re-e~t~r ~uspend7fn~Hrltvk Flare while testing 5. Permit to Drill Number: Forest Oil Corporation Development [] Stratigraphic D Exploratory D 204-143 Service D 6. API Number: 50-133-20542-00 3. Address: 310 K Street, Suite 700, Anchorage, AK 99501 7. KB Elevation (ft): 9. Well Name and Number: 25' AGL West Forelands #2 8. Property Designation: 10. Field/Pools(s): 11. A-035017 (suñace) and ADL-359112 PRESENT WELL CONDITION SUMMARY West Forelands Casing Structural Conductor Surface Intermediate Production Li ner Total Depth TVD (ft): Length Effective Depth MD (ft): Effective Depth TVD (ft): Size MD I Plugs (measured): Burst Junk (measured): Total Depth MD (ft): TVD Collapse Well Not Yet Drilled See PTD #204- 143 for Planned Configuration Perforation Depth MD (ft): IperfOration Depth TVD (ft): Tubing Size: ITubing Grade: Packers and SSSV MD (ft): rUbing MD (ft): Packers and SSSV Type: 12. Attachments: Description Summary of Proposal LJ Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name P~ula Inman Title Signature ~~hone 868-2135 COMMISSION USE ONLY 10/8/2004 13. Well Class after proposed work: Exploratory D Development [] Service D 15. Well Status after proposed work: Oil D Gas [] Plugged D Abandoned D WAG D GINJ D WINJ D WDSPL D Date: Contact Paula Inman 868-2135 Alaska Production Engineer Date 10/1/2004 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3ó,-!- 3&.9 Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: <-wro~\ \;O~\<J-'Cc.. ÇX!S ð-()~'-~S .d5$"(~)C.~) \ \')«S~ Cl.5\~~~ "\,)~\-\)~((~\t)~ .\-c ~\ "" "'" '\ ~'<2:... .ç \o.~ -.JC \~""'Q. . Approved y - \.\(} \ ,,0 Dj I G I N A L <~fìl'~~'i"'" " ···\'···'-'~O !t~""L BY ORDER OF COMMISSIONER THE COMMISSION OCT fJ) , D~ ~o¿f:.,t 3 INSTRUCTIONS ON REVERSE RE: West Foreland #2--Sundry Request to Flare . . Subject: RE: West Foreland #2--Sundry Request to Flare From: Paula Inman <PRInman@forestoi1.com> Date: Mon, 04 Oct 2004 18:15:51 -0600 To: 'Thomas Maunder' <tom_maunder@admin.state.ak.us> CC: Ted Kramer <TEKramer@forestoi1.com> (ß\- \ C\:, Tom, Forest has permission to flare under ADEC Permit by Rule. We are looking for AOGCC permission under 20 AAC 25.235 (d) (6) so we can flare as an option. We are looking into connecting the well into the fuel gas system, but wanted to have this as a back-up. Yes, we will minimize the time in testing the well once the pressure analysis shows the flow to have stabilized. Thank you for your time in this matter. Paula Inman production Engineer Forest Oil Corporation (907) 868-2135 office (907) 317-8231 cell -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak..us] Sent: Monday, October 04, 2004 1:52 PM To: Paula Inman Cc: Jim Regg; Steve Davies; John D Hartz Subject: West Foreland #2--Sundry Request to Flare Paula, Flaring of gas is not something handled by AOGCC. DEC is the agency involved with flaring due to the air issues. AOGCC can approve to vent gas. With regard to your request, I do need some further information. Is it possible for the gas to be connected into the present gathering system?? Could the flow periods be shorter if the pressure analysis shows the flow to have stabilized?? Thanks in advance for your replies. Tom Maunder, PE AOGCC 1 of 1 10/4/20044:22 PM . . . . . production between each producing pool as a percentage of the total volume of gas that the facility handled for the month. The operator shall report gas acquisition or disposition by category, as follows: (1) gas sold; (2) gas reinjected; (3) gas flared or vented; (4) gas used for lease operations other than flaring or venting; (5) natural gas liquids (NGLs) produced; (6) gas purchased; (7) gas transferred; (8) other. (b) Any release, burning, or escape into the air of gas other than incidental de minimis venting as authorized under (d)( 4) of this section must be reported as flared or vented on the Facility Report of Produced Gas Disposition (Form 10-422). The operator shall submit a written supplement for any flaring or venting incident exceeding one hour. The supplement must describe why the gas was flared or vented, list the beginning and ending time of the flaring or venting, report the volume of gas flared or vented, and describe actions taken to comply with ( c) of this section. ( c) The operator shall take action in accordance with good oil field engineering practices and conservation purposes to minimize the volume of gas released, burned, or permitted to escape into the air. (d) Gas released, burned, or permitted to escape into the air constitutes waste, except that (1) flaring or venting gas for a period not exceeding one hour as the result of an emergency or operational upset is authorized for safety; (2) flaring or venting gas for a period not exceeding one hour as the result of a planned lease operation is authorized for safety; (3) flaring pilot or purge gas to test or fuel the safety flare system is authorized for safety; (4) de minimis venting of gas incidental to normal oil field operations is authorized; (5) within 90 days after receipt of the report required under (b) of this section, the commission will, in its discretion, authorize the flaring or venting of gas for a period exceeding one hour (A) if the flaring or venting is necessary for facility operations, repairs, upgrades, or testing procedures; (B) if an emergency that threatens life or property requires the flaring or venting, unless failure to operate in a safe and skillful manner causes the emergency; or (C) if the flaring or venting is necessary to prevent loss of ultimate recovery; (6) upon application, the commission will, in its discretion, authorize the flaring or venting of gas for purposes of testing a well before regular production. 53 . . (e) Notwithstanding an authorization under (d) of this section, the commission will, in its discretion, review flaring or venting of gas and classify as waste any volume of . gas flared or vented in violation of (c) of this section. (f) Notwithstanding conservation orders that the commission issued before 1/1/95, this section applies to flaring or venting of gas that occurs on or after 1/1/95. History: Eff. 4/13/80, Register 74; am 4/2/86, Register 97; am 1/1/95, Register 132; am 11/7/99, Register 152 Authority: AS 31.05.030 AS 31.05.095 AS 31.05.170 20 AAC 25.240 GAS-OIL RATIO LIMIT A TIONS. (a) An oil well may not be produced if the gas-oil ratio of the well exceeds the original solution gas-oil ratio of the crude within the producing pool by more than 100 percent. (b) Upon written application by an operator, the commission will, in its discretion, waive the limitation in (a) of this section if (I) an enhanced recovery project operates in the pool from which the well is producing; (2) produced gas is being returned to the same pool; or (3) acquisition of pool performance data is necessary to determine an optimum reservoir management program. . (c) The commission will, in its discretion, grant exceptions to the limitation in (a) of this section for conditions other than those specified in (b) of this section only after application, notice, and an opportunity for public hearing in accordance with 20 AAC 25.540. History: Eff. 4/13/80, Register 74; am 4/2/86, Register 97; am 11/7/99, Register 152 Authority: AS 31.05.030 AS 31.05.095 20 AAC 25.245 COMMON PRODUCTION FACILITIES. Common facilities may be used to receive the production from any number of wells or pools if appropriate tankage or other measuring equipment is installed so that production from each well can be determined by means approved by the commission in accordance with 20 AAC 25.228. History: Eff. 4/13/80, Register 74; am 4/2/86, Register 97; am 11/7/99, Register 152 Authority: AS 31.05.030 . 54 Alaska Oil and Gas Conservation Commisssion - Conservation Orde... . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West Seventh Avenue, Suite 100 Anchorage Alaska 99501 Re: APPLICATION OF FOREST OIL ) Conservation Order No, 532 CORPORATION for an order granting an ) exception to the spacing requirements of ) West Foreland Field 20 MC 25.055 to allow for the drilling ) West Foreland Undefined Gas Pool and operation of the West Foreland #2 ) gas production well. ) September 16, 2004 ) IT APPEARING THAT: 1. Forest Oil Corporation ("Forest"), by letter dated July 2, 2004 and received by the Alaska Oil and Gas Conservation Commission ("Commission") that same day, requests exception to the well spacing provisions of regulation 20 AAC 25.055 to allow for the drilling and operation of the West Foreland #2 gas production weB ("WF #2"), which is closer than 1 ,500 feet to a property line and within the same governmental section as, and less than 3,000 feet from, a well capable of producing from the same gas pool. 2. Notice of opportunity for public hearing was published in the Anchorage Daily News on July 12, 2004, pursuant to regulation 20 MC 25.540. 3. On July 21,2004, Forest requested the public hearing be rescheduled. 4. Subsequent notice of opportunity for public hearing was published in the Anchorage Daily News on July 23, 2004. 5 On August 11, 2004, Forest submitted documentation that a notice had been sent to all known royalty interest owners in the affected leases. 6, All owners, landowners and operators within 3,000 feet of the anticípated productive interval have been notified. 7. No protests to the application were received. 8. A hearing was held in conformance with 20 AAC 25.540 on August 26, 2004 at the Commission's offices, Representatives from Forest, the Bureau of Land Management ("BLM"), and the Alaska Department of Natural Resources ("DNR") attended. FINDINGS: 1, The record for this order includes the records for Conservation Orders 450, 450-A and 450B. 2. WF #2 will be drilled as a deviated well. The surface location of the well is onshore, 886 feet from the south line and 571 feet from the east line of Section 21, T08N, R14W, Seward Meridian ("SM"). The proposed bottom hole location of the welllíes offshore beneath the western side of the Cook Inlet, 1,365 feet from the north line and 1,105 feet from the east line of Section 21, T08N, R14W, SM, 3. WF #2 will lie entirely within Section 21, T8N, R14W, SM, which also contains the existing West Foreland #1 gas production well ("WF #1"). 4. The affected leases are onshore Federal Lease A-035017 and offshore State of Alaska Lease ADL-359112, 5. Testimony in the record of CO 450 established that: lof5 2/23/20062:01 PM Alaska Oil and Gas Conservation Commisssion - Conservation Orde... . . a. Lease ADL-359112 currently carries a 5% royalty obligation to the landowner. According to Forest's July 11, 2000 letter, overriding royalty interests (ORR!'s) burden the lease by 12.5%, of which Forest re-acquired a 0,65625% interest. b. Lease A-035017 carries a 12-1/2% royalty obligation to the landowners. According to Forest's July 11, 2000 letter, ORRI's burden the lease by 5%. 6. WF #1 is located entirely within Federal Lease A-035017, This well drilled and tested two gas-bearing sands, informally known as the "9200-foot sand" and the "9400-foot sand." 7. As presently equipped, WF #1 produces gas from only the 9200-foot sand. A bridge plug in the well bore of WF #1 prevents production from the 9400-foot sand. 8. Recompletion of WF #1 to allow production from the 9400-foot sand may jeopardize the well. 9, Forest testified that a steady fuel gas supply is critical to maintaining uninterrupted oil and gas production operations in this portion of the Cook Inlet Basin, 10. Forest utilized well data and 3D seismic data to map the West Foreland structure, including faulting that traps the gas accumulation being produced by WF #1 (CO 450B, Finding 5), 11. WF #2 is targeting the 9200-foot and 9400-foot sands updip of WF #1 on the same structure. 12. In WF #2, the top of the 9200-foot sand will be located within State Lease ADL-359112, approximately 242' east of the boundary with Federal Lease A-035017, The top of the 9400-foot sand will also located within State Lease ADL-359112, approximately 293' east of the boundary with Federal Lease A-035017. 13, Forest proposes to equip WF #2 to allow gas production from the 9200-foot and 9400-foot sands, using either a single or dual completion, 14, Forest has identified additional, shallower prospective intervals that may also be encountered while drilling WF #2. The top of the potential shallow pay intervals lies within the Federal Lease A-035017, about 216' west of the common lease boundary. 15, If the shallower, prospective intervals contain sufficient pay, Forest may equip WF #2 to allow gas production from them. 16, WF #1 and WF #2 may both produce from the 9200-foot sand at take points approximately 2,685' apart within the same governmental section, 17. In order to drill and operate WF #2 as planned, the following exceptions to statewide spacing regulations are needed: a. Under 20 AAC 25.055(a)(2): "for a well dri!!ing for gas, a wellbore may be open for test or regular production within 1,500' of a property line only if the owner is the same and the landowner is the same on both sides of the line." b. Under 20 MC 25.055(a)(4): "if gas has been discovered ... not more than one well may be drilled to and completed in that pool on any governmental section; a well may not be drilled or completed closer than 3,000 feet to any well drilling to or capable of producing from the same pooL" c, Under 20 MC 25,055(b): "a well may not,.. begin regular production of gas from a property that is smaller than the governmental section upon which the well is located, unless the interests of the persons owning the drilling rights in and the right to share in the production from the quarter section or section, respectively, have been pooled under AS 31.05.100," 18. No order has been issued by the Commission establishing drilling units or a spacing pattern for the reservoir that differ from the statewide requirements. 19. Forest is the sole working interest owner of both leases for all intervals including, and shallower than, the 9400-foot sand, 20. Phillips Petroleum Company, or a successor or affiliate, has an interest in zones below 9,527 feet 20f5 2/23/20062:01 PM Alaska Oil and Gas Conservation Commisssion - Conservation Orde... . (measured depth) in the WF #1 well (CO 450A, Finding 4). 21, Landowners of Federal Lease A-035017 are Cook Inlet Region, Inc. and the U,S. Government. The State of Alaska is the landowner of Lease ADL-359112. The DNR administers State Lease ADL-359112. The BLM administers Federal Lease A-035017 on behalf of Cook !nlet Region, Inc. In addition to the landowners, there are numerous Overriding Royalty Interest Owners ("ORRis"). . 22, On August 11, 2004, Forest submitted documentation to the Commission indicating that notice had been sent via certified mail to all known royalty interest owners in the affected leases and all owners, landowners and operators within 3,000 feet of the anticipated productive interval. 23. !n response to Forest's notice, evidence was presented indicating all but one of the notices had been successfully delivered. !n response to the notices, only one comment had been received regarding drilling and producing WF #2. That comment supported granting the requested spacing exception. 24. Due to non-compliant spacing, the Commission issued CO 450 on July 24, 2000 granting a temporary spacing exception to allow the regular production of WF #1 from the 9200-foot sand, The performance terms of CO 450 were extended by CO 450A, issued April 23, 2001, 25. CO 450 required that Forest establish an escrow account and make sufficient payments to protect the interests of all royalty owners caused by differing landownership and uncertain production allocation. Forest was further required complete negotiations with BLM and DNR to establish a compensatory royalty agreement ("CRA"). 26, Forest, BLM, and DNR negotiated a CRA to allocate production from WF #1 to each lease. Pursuant to that agreement, all parties agreed to an allocation of 58% to Federal Lease A-035017 and 42% to State Lease ADL-359112 of all gas reserves producible from any interval not deeper than 9,527' from the West Foreland #1 well. The allocation percentages were determined based on analysis of seismic information, production history and formation pressure data using accepted geological and petroleum engineering methods. 27. The Commission issued CO 450B on September 29,2003. CO 450B granted a permanent spacing exception for WF #1, approved the allocation factors from the CRA and ordered disbursement of the escrow funds, 28, The CRA applies to portions of the 9200-foot and 940Q-foot sands that lie within Federal Lease A-035017 or State Lease ADL-359112 and are in hydraulic communication with those same sands in WF #1, The CRA is valid until the Federal and the State leases have terminated and all weBs producing gas from the 9200-foot and 9400-foot sands are plugged and abandoned, 29. The CRA does not apply to sands other than the 9200-foot and 9400-foot sands. The CRA did not include a provision to adjust the allocation interests if new information were to be developed. 30, Forest desires a permanent spacing exception for drilling and production of the 9200-foot and 9400-foot sands within WF #2, and proposes to allocate any production from those sands according to the existing CRA. The notice described in Finding No. 23 informed recipients of this proposed allocation, 31. Forest recognizes there is a possibility that the 9200-foot and 9400-foot sands in WF#1 and WF #2 may not be in hydraulic communication within the 9200-foot sand, and that if there is no hydraulic communication, a revised allocation formula may be required to ensure fair allocation of production. 32, Forest desires a temporary spacing exception for drilling and production of gas-bearing sands within WF #2 that are stratigraphically shallower than the 920Q-foot sands. If the prospective shallow sand(s} are capable of producing gas, Forest proposes to establish a separate escrow account and deposit sufficient royalty payments to protect the interests of all royalty owners of both leases until an additional CRA is executed. A new CRA would include a provision to adjust the allocation interests if new information is developed, 33, The Alaska Department of Revenue publishes quarterly calculations of the prevailing value of Cook Inlet gas under 15 AAC 55.173(b). 34. Both the BLM and DNR representatives present at the public hearing agreed to the facts presented in the hearing and support granting the spacing exception. 30f5 2/23/20062:01 PM Alaska Oil and Gas Conservation Commisssion - Conservation Orde... . . CONCLUSIONS: 1. Exceptions to 20 AAC 25.055{a){2), (a){4), and (b) are necessary to allow drilling and operation of WF #2. 2, Ensuring a steady fuel gas supply is key to maintaining uninterrupted oil and gas production in this portion of the Cook Inlet Basin. 3. WF #1 only produces from the 9200-foot sand, and that production is allocated according to the CRA executed between the operator and landowners on April 20, 2001, 4. Dri!!ing and operation of WF #2 will allow production from the 9400-foot sand without jeopardizing WF #1. 5. The CRA, which governs production from the 9200-foot and 9400-foot sands, provides for additional wells. 6, Since the 9200-foot sand wi!! be opened by WF #1 and WF #2 closer than 3,000' and on the same structure, this sand can be reasonably assumed to be in hydraulic communication between the two wells. 7, The Commission does not expect production from the 9200-foot sand at the proposed exception location to cause waste or adversely affect ultimate recovery, 8, Regular production of WF #2 for a period of approximately 24 months is likely to yield sufficient information to confirm whether the 9200-foot sand within WF #1 and WF #2 is in hydraulic communication and that the previously agreed allocation percentages are valid, 9. In the absence of formal pooling of the two affected lease tracts, the purposes of AS 31.05.100 require that allocation of production from sands stratigraphically shallower than the 9200-foot sand either be agreed on by all interest owners or be approved by the Commission after notice to all interest owners. 10. If sands in addition to the 9200-foot and 9400-foot sands are produced, until an appropriate allocation of production is established, a separate escrow account should be establíshed and Forest should deposit funds equal to the volume of gas produced from those other sands times the maximum sum of the royalty percentages in the leases times t.he applicable prevaí!ìng value of Cook Inlet gas published under 15.AAC <:::'\ "- 55.173(b), 50 - r~ ~ - d\J 5 '-\ ~ ·()tJ , ò04 - \ 4 '3 ~ ,""oNJù-i ) NOW, THEREFORE, IT IS ORDERED: (;...Dcv-.~\<z\ciJ \:} I\\-O~~:') \0 /\\-()~ 1. Forest's application for a spacing exception to allow for drilling and initiating gas production from the WF #2 well from any interval not stratigraphically deeper than the 9400-foot sand is temporarily granted. This spacing exception expires 30 months after Forest completes WF #2, without prejudice to Forest's right to apply for an extension of this temporary spacing exception or for a permanent spacìng exception, 2, Until it is otherwise ordered by the Commission or it is otherwise agreed by all interest owners in Lease A-035017 and Lease ADL 359111, including overriding royalty owners, Forest shall allocate WF #2 production from the 9200-foot and 9400-foot sands in accordance with the allocation percentages established in the CRA \J i\\ -ó~ 3. Promptly after the WF #2 well has been produced from the 9200-foot and 9400-foot sands for 24 months, Forest shall provide the Commission geologic and geophysical data and the results of the production pertinent to establishing a. whether hydraulic communication exists between WF #1 and WF #2 in the 9200-foot sand; and b. what proportions of the gas reserves producible from WF #1 and WF #2 underly Lease A-035017 and Lease ADL 359111. 4. Before regular production of gas commences from any sands stratigraphically shallower than the 9200-foot sand, Forest shall establish a separate escrow account for royalties on such production, substantially similar to the account required under Conservation Order No. 450. Forest shall fund this escrow account on the same basis as that set out in Conservation Order No. 450 as amended by Conservation Order No. 450-A, except that the funding obligation applies to production from any sands stratigraphically shallower than the 9200-foot sand. No funds may be disbursed from the new escrow account except by order of the Commission, after Forest provides at least 30 days notice prior to hearing to all 40f5 2/23/20062:01 PM Alaska Oil and Gas Conservation Commisssion - Conservation Orde... . royalty owners in both leases, DONE at Anchorage, Alaska and dated September 16, 2004, John K. Norman, Chair Alaska Oil and Gas Conservation Commission Daniel T. Seamount, Jr., Commissioner Alaska Oil and Gas Conservation Commission Conservation Order Index 50f5 Home Webmaster . _"""~~wv,M""'»:_'_",,å:-~'->""·----'-,····_-, 2/23/20062:01 PM ~~fÆ~ . lID ~ ,; FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ted Kramer Alaska Production Manager Forest Oil Corporation 310 K Street, Suite 700 Anchorage, Alaska 99501 Re: West Foreland #2 Forest Oil Corporation Permit No: 204-143 Surface Location: 886' FSL, 571' FEL, SEC. 21, T8N, RI4W, SM Bottomhole Location: 1354' FNL, 1139' FEL, SEC. 21, T8N, RI4W, SM Dear Mr. Kramer: Enclosed is the approved application for permit to drill the above referenced development well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. Forest Oil Corporation assumes the liability of any protest to the spacing exception that may occur. 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. PIe provide at least twenty-four (24) hours notice for a representative of the Commission t . t ess any required test. Contact the Commission's petroleum field inspector at 659- ager). BY ORDER OIhJHE COMMISSION DATED thisr-'f[ày of September, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. e e Supplemental APD Information #2 West Forelands #2 Directional Surveys Forest Oil recently completed running a directional survey in the West Forelands #1 well and ran proximity calculations using it and the well path ofthe proposed West Forelands #2. The proximity calculations resulted in minor modifications to the proposed well path in order to maintain a sufficient separation between the two wells. Attached is the revised directional program for WF #2 and the calculated proximities between it and the WF # 1 wellbore. These directional modifications have also resulted in a slightly different sUrface location for the well. Please note that the WF #2 will be drilled from surface coordinates of: Grid N: 2475582 Grid E: 190452 Zone: AK-4 886' FSL, 571' FEL, Sec. 21, T8N, RI4W, SM BOP Equipment Forest Oil has decided to use a different drilling rig than earlier proposed. Kuukpik Drilling Rig #5 will now be used. Attached is a schematic ofKuukpik Rig #5's BOP equipment layout. RECEIVED AUG 1 82004 Alaska Oil & Gas Cons. Commission Anchorage 8/18/2004 IWellbore IName West Foreland#2 (8) Well Name West Foreland#2 Slot Name WF#2 Installation Name West Forelands Pad #1 Field Name West Foreland freáted BY> Comments. e Forest Oil Corp.,WF#2 West Forelands Pad #1, West Foreland,West Cook Inlet, Alaska I Created 17 -Auq-2004 I Government 10 I Grid Northinq 2475581.6250 I Grid Eastinq 1190452.3700 I Latitude N60 45 53.5586 I Eastinq 191000,2193 I Northinq 2474680.5740 I EastinQ 191000.2193 I Northinq 2474680.5740 e PROPOSAL LISTING Page 1 Wellbore: West Foreland#2 (8) Well path: WF #2 Verso #8 Date Printed: 17-Aug-2004 I Last Revised 17 -Auq-2004 I Last Revised 30-Apr-2004 I Lonqitude W151 43 52.3930 [North 886.32N .1. -- INTEQ lEast 571.37W I Coord Svstem Name I North Alianment AK-4 on NORTH AMERICAN DATUM 1927 datu~ True I Coord Svstem Name I North Aliqnment I AK-4 on NORTH AMERICAN DATUM 1927 datu~ True 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 90.0ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 349.58 degrees Bottom hole distance is 3092.24 Feet on azimuth 349.42 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated @ e Forest Oil Corp.,WF#2 West Forelands Pad #1, West Foreland,West Cook Inlet, Alaska e PROPOSAL LISTING Page 2 Wellbore: West Foreland#2 (8) Well path: WF #2 Verso #8 Date Printed: 17-Aug-2004 81. .... INTEQ Wellpath Report MD[ft] Inc[deg] i Azi[deg] TVD[ft] Vertical North[ft] East[ft] Station Station Dogleg Vertical Station Comment Depth SS Position(Grid Position(Grid [deg/10 Section[f North) East) Oft] t] 0.00 0.00 0.00 0.00 -90.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 Tie on 100.00 0.00 0.00 100.00 10.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 20.000in Casinq 200.00 0.00 0.00 200.00 110.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 300.00 0.00 0.00 300.00 210.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 400.00 0.00 0.00 400.00 310.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 500.00 0.00 0.00 500.00 410.00 O.OON O.OOE 2475581,63 190452.37 0.00 0.00 600.00 0.00 0.00 600.00 510.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 700.00 0.00 0.00 700.00 610.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 800.00 0.00 0.00 800.00 710.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 900.00 0.00 0.00 900.00 810.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 1000.00 0.00 0.00 1000.00 910.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 1100.00 0.00 0.00 1100.00 1010.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 1200.00 0.00 0.00 1200.00 1110.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 1300.00 0.00 0.00 1300.00 1210.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 1400.00 0.00 0.00 1400.00 1310.00 O,OON O.OOE 2475581.63 190452.37 0.00 0.00 1500.00 0.00 0.00 1500.00 1410.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 1600.00 0.00 0.00 1600.00 1510.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 1700.00 0.00 0.00 1700.00 1610.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 1800.00 0.00 0.00 1800.00 1710.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 1900.00 0.00 0.00 i 1900.00 1810.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 2000.00 I 0.00 0.00 2000.00 1910.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 2100.00 0.00 0.00 2100.00 2010.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 2200.00 0.00 0.00 2200.00 2110.00 O.OON O,OOE 2475581.63 190452.37 0.00 0.00 2300.00 0.00 0.00 2300.00 2210.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 2400.00 0.00 0.00 2400.00 2310.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 2500.00 0.00 0.00 2500.00 2410.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 2600.00 0.00 0.00 2600.00 2510.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 2700.00 0.00 0,00 2700.00 2610.00 O.OON O,OOE 2475581.63 190452.37 0.00 0.00 2800.00 0.00 0.00 2800.00 2710.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 2900.00 0.00 0.00 2900.00 2810.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 3000.00 0.00 0.00 3000.00 2910.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 Begin Nudge, 10 3/4in Casing, End of Hold 3100.00 2.00 45.00 3099.98 3009.98 1.23N 1.23E 2475582.83 190453.64 2.00 0.99 3200.00 4.00 45.00 3199.84 3109.84 4.93N 4.93E 2475586.43 190457.43 2.00 3.96 3250.00 5.00 45.00 3249.68 3159.68 7.71N 7.71E 2475589.13 190460.28 2.00 6.19 End Nudqe. End of Buildrrurn 3300.00 5.00 45.00 3299.49 3209.49 10.79N 10.79E 2475592.13 190463.44 0.00 8.66 3350.00 5.00 45.00 , 3349.30 3259.30 13.87N 13.87E 2475595.13 190466.60 0.00 11.14 Beqin Drop. End of Hold 3400,00 4.00 45.00 3399.15 3309.15 16.65N 16.65E 2475597.83 190469.45 2.00 13.36 3500.00 2.00 45.00 3499.01 3409.01 20.35N 20.35E 2475601.43 190473.25 2.00 16.33 3600.00 0.00 0.00 3598.99 3508.99 21.58N 21.58E 2475602.63 190474.51 2.00 17.32 End Drop. End of Droprrurn 3700.00 0.00 0.00 3698.99 3608.99 21.58N 21.58E 2475602.63 190474.51 0.00 17.32 3800.00 0.00 0.00 3798.99 3708.99 21.58N 21.58E 2475602.63 190474.51 0.00 17.32 3900.00 0.00 0.00 3898.99 3808.99 21.58N 21.58E 2475602.63 190474.51 0.00 17.32 4000,00 0.00 0.00 3998.99 3908.99 21.58N 21.58E 2475602.63 190474.51 0.00 17.32 4100.00 0.00 0.00 4098.98 4008.99 21.58N 21.58E 2475602.63 190474.51 0.00 17.32 4200.00 0.00 0.00 4198.98 4108.99 21.58N 21.58E 2475602.63 190474.51 0.00 17.32 4300.00 0.00 0.00 4298.98 4208.99 21.58N 21.58E 2475602.63 190474.51 0.00 17.32 4400.00 0.00 0.00 4398.98 4308.99 21.58N 21.58E 2475602.63 190474.51 0.00 17.32 4500.00 0.00 0.00 4498.98 4408.99 21.58N 21.58E 2475602.63 190474.51 0.00 17.32 4600.00 0.00 0.00 4598.98 4508.99 21.58N 21.58E 2475602.63 190474.51 0.00 17.32 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are frorn Rig and TVD's are from Rig ( Datum #1 90.0ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 349.58 degrees Bottom hole distance is 3092.24 Feet on azimuth 349.42 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated @ e Forest Oil Corp.,WF#2 West Forelands Pad #1, West Foreland,West Cook Inlet, Alaska e PROPOSAL LISTING Page 3 Well bore: West Foreland#2 (8) Well path: WF #2 Verso #8 Date Printed: 17-Aug-2004 ... .... INTEQ Wellpath Report MD[ft] Inc[deg] Azi[deg] TVD[ft] Vertical North[ft] East[ft] Station Station Dogleg Vertical Station Comment Depth SS Position(Grid Position(Grid [deg/10 Section[f North) East) Oft1 t1 4700.00 0.00 0.00 4698.98 4608.99 21.58N 21.58E 2475602.63 190474.51 0.00 17.32 4800.00 0.00 0.00 4798.98 4708.99 21.58N 21.58E 2475602.63 190474,51 0.00 17.32 4900.00 0.00 0.00 4898.98 4808.99 21.58N 21.58E 2475602.63 190474,51 0.00 17,32 , 5000.00 0,00 0.00 4998.98 4908.99 21.58N 21.58E 2475602.63 190474.51 0.00 17.32 5100.00 0.00 0.00 5098.98 5008.99 21.58N 21,58E 2475602.63 190474.51 0.00 17.32 5200.00 0.00 0.00 5198.98 5108.99 21.58N 21.58E 2475602.63 190474.51 0.00 17.32 5300.00 0.00 0.00 5298.98 5208.99 21.58N 21.58E 2475602.63 190474.51 0.00 17.32 KOP. 3DJ Kick off Point 5400.00 2.00 348.95 5398.97 5308.96 23.29N 21.25E 2475604.35 190474.22 2.00 19.07 5500.00 4.00 348.95 5498.82 5408.82 28.43N 20.24E 2475609.51 190473.35 2.00 24.30 5600.00 6.00 348.95 5598.44 5508.44 36.98N 18,57E 2475618.11 190471.91 2.00 33.02 5700.00 8.00 348.95 5697.69 5607.69 48.94N 16.24E 2475630.12 190469.89 2.00 45.20 5800.00 10.00 348.95 5796.45 5706.45 64.30N 13.24E 2475645.55 190467.30 2.00 60.84 5900.00 12.00 348.95 5894.61 5804.61 83.02N 9.58E 2475664.37 190464.14 2.00 79.92 6000.00 14.00 348.95 5992.04 5902.04 105.10N 5.27E 2475686.55 190460.41 2.00 102.41 6100.00 16.00 348.95 6088.63 5998.63 130.50N 0.31E 2475712.07 190456.12 2.00 128.29 6200.00 18.00 348.95 6184.25 6094.25 159.19N 5.30W 2475740.90 190451.27 2.00 157.53 6300.00 20.00 348.95 6278.80 6188.80 191.14N 11.54W 2475773.01 190445.88 2.00 190.08 6400.00 22.00 348.95 6372.15 6282.15 226.32N 18.41W 2475808.35 190439.94 2.00 225.91 6500.00 24.00 348.95 6464.20 6374.20 264.66N 25.90W 2475846.88 190433.46 2.00 264.98 6600.00 26.00 348.95 6554.83 6464.83 306.14N 33.99W 2475888.55 190426.46 2.00 307.24 6700.00 28.00 348.95 6643.92 6553.92 350.69N 42.70W 2475933.32 190418.93 2.00 352.63 6800.00 30.00 348.95 6731.38 6641.38 398.27N 51.99W 2475981.13 190410.90 2.00 401.11 6900.00 32.00 348.95 6817.09 6727.09 448.82N 61.86W 2476031.92 190402.36 2.00 452.61 7000.00 34.00 348.95 6900.95 6810.95 502.27N 72.30W 2476085.63 190393.34 2.00 507.06 7100.00 36.00 348.95 6982.87 6892.87 558.56N 83.29W 2476142.19 190383.83 2.00 564.42 7200.00 38.00 348.95 7062.73 6972. 73 617.62N 94.83W 2476201.54 190373.86 2.00 624.59 7300.00 40.00 348,95 7140.44 7050.44 679.38N 106.89W 2476263.60 190363.43 2.00 687.51 7400.00 42.00 348.95 7215.90 7125.90 743.77N 119.47W 2476328.29 190352.56 2.00 753.11 7500.00 44.00 348.95 7289.03 7199.03 810.70N 132.54W 2476395.55 190341 .25 2.00 821.31 7600.00 46.00 348.95 7359.74 7269.74 880.10N 146.09W 2476465.28 190329.53 2.00 892.01 7627.04 46.54 348.95 7378.43 7288.43 899.28N 149.84W 2476484.55 190326.30 2.00 911.55 EOC, End of BuildfTum 7700.00 46.54 348.95 7428.62 7338.62 951.25N 159.99W 2476536.77 190317.52 0.00 964.50 7800.00 46.54 348.95 7497.40 7407.40 1022.49N 173.90W 2476608.36 190305.49 0.00 1037.08 7900.00 46.54 348.95 7566.19 7476.19 1093.73N 187.81W 2476679,94 190293.46 0.00 1109.67 7978.24 46,54 348.95 7620.00 7530.00 1149.47N 198.70W 2476735.94 190284.05 0.00 1166.45 TQt#1 WF#2 8000.00 46.54 348.95 7634.97 7544.97 1164.97N 201.73W 2476751.52 190281.43 0.00 1182.25 8100.00 46.54 348.95 7703.75 7613.75 1236.21 N 215.64W 2476823.10 190269.40 0.00 1254.83 8200.00 46.54 348.95 7772.54 7682.54 1307.46N 229.55W 2476894.69 190257.37 0.00 1327.41 8300.00 46.54 348.95 7841.32 7751.32 1378.70N 243.47W 2476966.27 190245.34 0.00 1399.99 8400.00 46.54 348.95 7910.10 7820.10 1449.94N 257.38W 2477037.85 190233.31 0.00 1472.58 8500.00 46.54 348.95 7978.89 7888.89 1521.18N 271.29W 2477109.44 190221.28 0.00 1545.16 8600.00 46.54 348.95 8047.67 7957.67 1592.42N 285.21W 2477181.02 190209.24 0.00 1617.74 8700.00 46.54 348.95 8116.46 8026.46 1663.66N 299.12W 2477252.60 190197.21 0.00 1690,32 8800.00 46.54 348.95 8185.24 8095.24 1734.90N 313.03W 2477324.19 190185.18 0.00 1762.90 8900.00 46.54 348.95 8254.02 8164.02 1806.14N 326.95W 2477395.77 190173.15 0.00 1835.49 9000.00 46.54 348.95 8322,81 8232.81 1877.38N 340.86W 2477467.35 190161.12 0.00 1908.07 9100.00 . 46.54 348.95 8391.59 8301.59 1948.62N 354.77W 2477538.94 190149.09 0.00 1980.65 9200.00 I 46.54 348.95 8460.38 8370.37 2019.86N 368.69W 2477610.52 190137.06 0.00 2053.23 9300.00 46.54 348.95 8529.16 8439.16 2091,10N 382.60W 2477682.10 190125.03 0.00 2125.81 9400.00 46.54 348.95 8597.94 8507.94 2162.34N 396.51W 2477753.68 190113.00 0.00 2198.40 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 90.0ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 349.58 degrees Bottom hole distance is 3092.24 Feet on azimuth 349.42 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated e Forest Oil Corp.,WF#2 West Forelands Pad #1, West Foreland,West Cook Inlet, Alaska e PROPOSAL LISTING Page 4 Well bore: West Foreland#2 (8) Well path: WF #2 Verso #8 Date Printed: 17 -Aug-2004 81. .... INTEQ I Wellpath Report MD[ft] Inc[deg] Azi[deg] TVD[ft] Vertical North[ft] East[ft] Station Station Dogleg Vertical Station Comment Depth SS Position(Grid Position(Grid [deg/10 Section[f North) East) Oft1 t1 9500.00 46.54 348.95 8666.73 8576.73 2233.58N 410.43W 2477825.27 190100.97 0.00 2270.98 9516.39 46.54 348.95 8678.00 8588.00 2245.26N 412.71W 2477837.00 190099,00 0.00 2282.87 Anomaly A WF#2, Anomaly A WF#2 2-Jul-04. End of Hold 9600.00 46.54 348.95 8735.51 8645.51 2304.82N 424.34W 2477896.85 190088,94 0.00 2343.56 9700.00 46.54 348.95 8804.29 8714.29 2376.06N 438,26W 2477968.43 190076,91 0.00 2416.14 9800.00 46.54 348.95 8873.08 8783.08 2447.30N 452.17W 2478040.02 190064.88 0.00 2488.72 9900.00 46.54 348,95 8941.86 8851.86 2518.54N 466.08W 2478111.60 ' 190052.85 0.00 12561'31 10000.00 46.54 348,95 9010.65 8920.65 2589.78N 480.00W 2478183.18 190040.82 0.00 2633.89 10100.00 46.54 348,95 9079.43 8989.43 2661.03N 493.91W 2478254.77 190028.79 0.00 2706.47 10200.00 46.54 348,95 9148.21 9058.21 2732.26N 507.82W 2478326.35 190016.76 . 0.00 2779.05 10300.00 46.54 348,95 9217.00 9127.00 2803.51 N 521.74W 2478397.93 190004.73 0.00 2851.63 10400.00 46.54 348.95 9285.78 9195.78 2874.75N 535.65W 2478469.52 189992.70 0.00 2924.22 10500.00 46.54 348.95 9354.56 9264.56 2945.99N 549.56W 2478541.10 189980.67 0.00 2996.80 10600.00 46.54 348.95 9423.35 9333.35 3017.23NI563.48W 2478612.681 189968.64 0.00 3069.38 10631.48 46.54 348.95 9445.00 9355.00 3039.65N 567.86W 2478635.21 189964.85 0.00 3092.23 TD WF#2. 7 5/8in CasinQ, End of Hold 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 90.0ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 349.58 degrees Bottom hole distance is 3092.24 Feet on azimuth 349.42 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated @ e Forest Oil Corp.,WF#2 West Forelands Pad #1, West Foreland,West Cook Inlet, Alaska .i. .... II Comments MDlftl TVDlftl . 3000.00 3000.00 3250.00 3249.68 3350.00 3349.30 -----.9600.00 3598.99 5300.00 5298.98 7627.04 7378.43 7978.24 7620.00 9516.39 8678.00 10631.48 9445.00 e PROPOSAL LISTING Page 5 Wellbore: West Foreland#2 (8) Wellpath: WF #2 Verso #8 Date Printed: 17 -Aug-2004 INTEQ Eastlftl O.OOE 7.71E 13.87E 21.5~ 21.58E 149.84W 198.70W 412.71W 567.86W Northlftl O.OON 7.71N 13.87N 21.58N 21.58N 899.28N 1149.47N 2245.26N 3039.65N Comment Beain Nudae End Nudae I Beain Drop End Drop KOP EOC Tat#1 WF#2 Anomaly A WF#2 TO WF#2 [Hole Sections Diameter Start Start Start Start End End End End\n East[ftj Wellbore finl MDlftl TVDlftl Northlftl Eastlftl MDlftl TVDlftl Northlftl 24.000 0.00 0.00 O.OON O.OOE 100.00 100.00 O.OON O.OOE West Foreland#2 (8) 143/4 100.00 100.00 O.OON O.OOE 3000.00 3000.00 O.OON O.OOE West Foreland#2 (8) 97/8 3000.00 3000.00 O.OON O.OOE 10651.19 3053.69N 570.60W West Foreland#2 (8) I Casin!ls Name Top Top Top Top Shoe Shoe Shoe Shoe Wellbore M Dlftl TVDlftl Northlftl Eastlftl MDlftl TVDlftl Northlftl Eastlftl 20.000in Casina 0.00 0.00 O.OON O.OOE 100.00 100.00 O.OON O.OOE West Foreland#2 (8) 10 3/4in Casina 100.00 100.00 O.OON O.OOE 3000.00 3000.00 O.OON O.OOE West Foreland#2 (8) ì 7 5/8in Casina 0.00 0.00 O.OON O.OOE 10651.19 9458.56 3053.69N 570.60W West Foreland#2 (8) TarQets Name Northlftl Eastlftl TVDlftl Latitude Lonaitude Eastina Northina Anomaly A WF#2 2245.26N 412.71W 8678.00 N60 46 15.6687 W151 44 0.7026 190099.00 2477837,00 2-Jul-04 Tgt#1 WF#2- 1127.48N 238.18W 7620.00 N60 46 4.6614 W151 43 57.1881 190244.00 2476715.00 2-Jul-04 Tgt TD WF#2 3056.20N 539.13W 9445.00 N60 46 23.6543 W151 44 3.2488 189994.00 2478651.00 2-Jul-04 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 90.0ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 349.58 degrees Bottom hole distance is 3092,24 Feet on azimuth 349.42 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Scale 1 cm = 10 ft -160 -140 -120 Forest Oil Corp.. 5101: Well: Wesl Foreland#2 Wellbore: Wesl (8) Location: Wesl Cook Inlel, Alaska Field: Wesl Foreland Inslallallon: Wesl Forelands Pad #1 East (feet) -> -100 -40 -20 o 20 40 -80 -60 5900 9200 8300 7400 6800 6200 5600 4700 4100 2900 2000 500 3200 500 5600 3500 Created by: Planner Date plotted: 17-Aug-2004 Plot reference is West FÒreland#2(8). Ref weiipath is WF #2 Verso #8. Coordinates are in feet reference WF#2. True Verticai Depths are reference Rig Datum. Measured Depths are referenœ Rig Datum, Rig Detum: Datum #1 Rig Datum to Mean Sea Level: 90,00 ft. to TRUE North. 60 80 100 200 20 e e nil. ... Forest Oil Corp. INTEQ Location: West Cook Inlet, Alaska Field: West Foreland Installation: West Forelands Pad #1 Slot: WF#2 Well: West Foreland#2 Well bore: West Foreland#2 (8) @ Created by : Planner Date plotted: 17 -Aug-2004 Plot reference is West Foreland#2 (8). Ref wellpath is W F #2 Verso #8. Coordinates are in feet reference WF#2. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Oatum to Mean Sea Level: 90.00 ft. Plot North is aligned to TRUE North. Scale 1 em = 100 ft -1800 -1600 -1400 -1200 -1000 -800 -600 East (feet) -> -400 ~oo 0 200 400 600 800 1000 1200 1400 3400 West Foreland#2 3200 I lo 3000 \ \ 9200 2800 \ \ 2600 \ \ 8900 \ 2400 \ \ 2200 \ 8600 \ \ 2000 \ \ \ 8300 1800 ^ \ I \ z 0 1600 ;::¡. \ 8000 ::T - i ø' \ 1400 !. \ - \ 7700 1200 o \ \ 1000 \ \ 800 \ \ 7100 \ 600 \ \ 6800 \ \ 400 \ 6500 C/) Iw~,.,,_,,] \ 0 200 II) 6200 ëD I \ 0 \ 3 0 II ...... [ 0 0 -200 ;:I> e -- Forest Oil Corp. @) Ríi. .... Location: West Cook Inlet, Alaska Field: West Foreland Installation: West Forelands Pad #1 Slot: WF#2 Well: West Foreland#2 Wellbore: West Foreland#2 (8) ¡¡: 0 -500 IJ') C\ II E u 0 (]) J m u CI) 500 1000 1500 2000 2500 3000 - 3500 j - () .æ - J: 4000 - Q, () C 4S00 ñi (J 1:: 5000 () > () 5500 j i- t- I V 6000 6500 7000 7500 8000 8500 9000 9500 l 10000 INTEQ ~ I Created by: Planner Date plotted: 17 -AU9-2004 Plot reference Is West Foreland#2 (8). Ref welipath is WF #2 Verso #8. Coordinates are in feet reference WF#2. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Oatum to Mean Sea Level: 90.00 ft. Plot North is aligned to TRUE North. 20.000in Casing Scale 1 cm = 100 ft East (feet) -> -800 -600 -400 -200 o 200 - 3200 TO WF#2 . Tgt TO WF#2 2-Jul-04 - 3000 Jl 10 3/4in Casing Begin Nudge 4.00 End Nudge Begin Drop t End Drop I I I , KOP \ 4.00 8.00 DLS: 2.00 deg/100ft I 16.00 \ 20.00 24.00 28.00 ~2'~~'00 42.00 46.00 EOC Tgt#1 WF#2 - 2-Jul-04 Tgt#1 WF#2 - 2800 PLOT NORTH IS ALIGNED TO TRUE NORTH - 2600 - 2400 Anomaly A WF#2 Anomaly A WF#2 2-Jul-04 _ 2200 2000 - 1800 ^ I - 1600 ~ ::I- :T - - 1400 ø' CD - - - 1200 Tgt#1 WF#2 - 2-Jul-04· Tgt#1 WF#2 - 1000 800 ,- 600 ~<\> 400 ~~ 200 CI) 0 End Drop Q) CD Begin Drop KOP End Nu~e r 0 0 Begin Nu ge ì 3 1 0 3/4in Casing 20.000in Casing II ...... - -200 0 0 := Anomaly A WF#2 2-Jul-04 Anomaly A WF#2 TD~Tgt TD WF#2 2-J""" -500 -0 500 1000 1500 2000 2500 3000 3500 Scale 1 em = 250 ft Vertical Section (feet) -> Azimuth 349.58 with reference 0.00 N, 0.00 E from WF#2 @ e Forest Oil Corp. WF #2 Verso #8, West Foreland#2 (8) WF#2, West Forelands Pad #1 e CLEARANCE LISTING Page 1 Date Printed: 17-Aug-2004 West Foreland, West Cook Inlet, Alaska .t£ INTEQ Ellipse separations are reported ONLY if BOTH wells have uncertainty data Ellipse error terms are CORRELATED across ties between tools of the SAME CLASS Cutoff is calculated on CENTRE to CENTRE distance Summary data uses Closest Approach clearance calculation for all minima Hole size/Casings are NOT included Hole size/Casings are NOT subtracted from Centre-Centre distance Ellipses scaled to 2.00standard deviations. Closing Factor Confidence limit of 99.80% Errors on Ref start at Slot Permanent Datum (0.00) Report uses Revised: (D-C)/E Factor Calculation Well bore Name West Foreland#2 (8) I Created 17 -Aua-2004 I Last Revised 17-Aua-2004 Well Name West Foreland#2 I Govemment ID i I Last Revised 30-Apr-2004 Slot Name WF#2 I Grid Northina 2475581.6250 I Grid Eastina 190452.3700 I Latitude N60 45 53.5586 I Lonaitude W151 43 52.3930 ¡North 886.32N lEast 571.37W I Installation Name West Forelands Pad #1 I Eastina I Northina I Coord Svstem Name I North AJianment 191000.219~ 2474680.574~ AK-4 on NORTH AMERICAN DATUM 1927 daturl True Field Name West Foreland I Eastina I I Northina 191000.219j I Coord Svstem Name I North Alianment 2474680.574~ AK-4 on NORTH AMERICAN DATUM 1927 datu~ True Clearance Summary Offset Offset Offset WellName Well bore Slot Offset Structure Minimum Distance rftl MD[ft] Diverging Ellipse From[ft] Separation fftl 1649.96 5700.00 Ellipse MD[ft] Clearance Factor Clearance MD[ft] West West WF#1 Foreland #1 I Foreland #1 West Forelands Pad #1 31.80 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 90.0ft 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) Casings Included Prepared by Baker Hughes Incorporated e e .1. @ Forest Oil Corp. CLEARANCE LISTING Page 2 WF #2 Verso #8, West Foreland#2 (8) Date Printed: 17-Aug-2004 .... WF#2, West Forelands Pad #1 West Foreland, West Cook Inlet, INTEQ Alaska Clearance Data 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] , rdeQl rftl 0.00 0.00 O.OON O.OOE West Foreland 0.091 0.09 1.058 39.99W -91.5 38.17 #1 100.00' 100.00 O.OON O.OOE West Foreland 100.51 100.51 0.595 39.31W -90.9 37.48 #1 I 200.00 200.00 O.OON O.OOE West Foreland 200.40 200.39 0.06N 38.08W -89.9 37.02 #1 300.00 300.00 O.OON O.OOE West Foreland 300.27 300.25 0.31N 37.16W -89.5 36.10 #1 400.00 400.00 O.OON O.OOE West Foreland 400.23 400.21 0.43N 36.49W -89.3 35.43 #1 500.00 500.00 O.OON O.OOE West Foreland 500.19 500.17 0.48N 35.92W -89.2 34.86 #1 600.00 600.00 O.OON O.OOE West Foreland 600.15 600.12 0.46N 35.45W -89.3 34,39 #1 700.00 700.00 O.OON O.OOE West Foreland 700.10 700.08 0.41N 35.17W -89.3 34.11 #1 800.00 800.00 O.OON O.OOE West Foreland 800.13 800.11 0.38N 34.95W -89.4 33.89 #1 900.00 900.00 O.OON O.OOE West Foreland 900.15 900.12 0.63N 34.61W -89.0 33.56 #1 1000.0e 1000.0e O.OON O.OOE West Foreland 1000.12 1000.09 0.94N 34.26W -88.4 33.21 #1 1100.00 1100.0C O.OON O.OOE West Foreland 1100.0!: 1100.05 1.19N 34.03W -88.0 32.99 #1 1200.0C 1200.0C O.OON O.OOE West Foreland 1200.1< 1200.11 1.66N 33.83W -87.2 32.81 #1 1300.0C 1300.0C O.OON O.OOE West Foreland 1300.1S 1300.16 2.24N 33.39W -86.2 32.40 #1 1400.0C 1400.0C O.OON O.OOE West Foreland 1400.07 1400.03 2.90N 33.01W -85.0 32.07 #1 1500.00 1500.0C O.OON O.OOE West Foreland 1500.0S 1500.05 3.69N 32.81W -83.6 31.95 #1 1600.00 1600.0C O.OON O.OOE West Foreland 1600.0e 1600.01 4.53N 32.57W -82.1 31.82 I #1 1649.96 1649.96 O.OON O.OOE West Foreland 1650.0e 1649.96 4.96N 32.49W -81.3 31.80 #1 1700.0C HOO.oe O.OON O.OOE West Foreland 1700.0e 1699.96 5.43N 32.46W -80.5 31.85 #1 1800.0C 1800.0e O.OON O.OOE West Foreland 1800.0< 1799.99 6.14N 32.45W -79.3 31.96 #1 1900.00 1900.0C O.OON O.OOE West Foreland 1900.0~ 1899.99 6.95N 32.31W -77.9 31.99 #1 2000.0C 2000.0C O.OON O.OOE West Foreland 2000.01 1999.95 8.15N 32,10W -75.8 32.05 #1 2100.0C 2100.0C O.OON O.OOE West Foreland 2100.0e 2099.93 9.32N 31.95W -73.7 32,21 #1 2200.0C 2200.0e O.OON O.OOE West Foreland 2199,93 2199.86 10.33N 32.00W -72.1 32.56 #1 2300.0C 2300.0e O.OON O.OOE West Foreland 2299.9C 2299.82 11.54N 32.12W -70.2 33.07 #1 i 2400.00 2400.0C O.OON O.OOE West Foreland 2400.01 2399.92 12.65N 32.05W -68.5 33.401 #1 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 90.0ft 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) Casings Included Prepared by Baker Hughes Incorporated e e ..: @ Forest Oil Corp. CLEARANCE LISTING Page 3 WF #2 Verso #8, West Foreland#2 (8) Date Printed: 17-Aug-2004 WF#2, West Forelands Pad #1 West Foreland, West Cook Inlet, INTEQ Alaska Clearance Data 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] rdeQl fftl 2500.0C 2500.0C O.OON O.OOE West Foreland 2499.92 2499.83 13.39N 32.13W -67.4 33.74 #1 2600.0C 2600.0C O.OON O.OOE West Foreland 2600.03 2599.94 14.14N 32.17W -66.3 34.08 #1 2700.0C 2700.0C O.OON O.OOE West Foreland 2699.97 2699.81:' 14.69N 32.20W -65.5 34.33 #1 2800.0C 2800.0C O.OON O.OOE West Foreland 2800.11 2800.01 15.20N 32.18W -64.7 34.52 #1 2900.0C 2900.0C O.OON O.OOE West Foreland 2900.1 e 2900.0e 15.76N 31.87W -63.7 34.49 #1 3000.00 3000.0C O.OON O.OOE West Foreland 3000.21 3000.11 16.34N 31.30W -62.4 34.24 #1 3100.0C 3099.91:' 1.23N 1.23E West Foreland 3100.11 3100.0C 17.07N 30.71W -108.6 34.93 #1 3200.00 3199.84 4.93N 4.93E West Foreland 3200.11 3200.0C 17,83N 30.14W -114.8 36.64 #1 3250.0C 3249.61:' 7.71N 7.71E West Foreland 3249.9!: 3249.81:' 18.23N 29.76W -119.2 38.19 #1 3300.0C 3299.46 10.79N 10.79E West Foreland 3299.7!: 3299.67 18.69N 29.45W -123.8 40.28 #1 3350.0C 3349.3C 13.87N 13.87E West Foreland 3349.5!: 3349.41:' 19.13N 29.19W -128.0 42.66 #1 3400.00 3399.1e 16.65N 16.65E West Foreland 3399.4e 3399.33 19.48N 28.98W -131.4 44.98 #1 3500.0C 3499.01 20.35N 20.35E West Foreland 3499.4< 3499.32 20.07N 28.42W -135.3 48.04 #1 3600.00 3598.96 21.58N 21.58E West Foreland 3599.3!: 3599.2€ 20.86N 27.82W -90.8 48.68 #1 3700.0C 3698.9G 21.58N 21.58E West Foreland 3699.2E 3699.1e 21.70N 27.44W -89.9 48.29 #1 3800.00 3798.9!: 21.58N 21.58E West Foreland 3799.21 3799.07 22.59N 27.21W -88.8 48.07 #1 3900.0C 3898.99 21.58N 21.58E West Foreland 3899.0!: 3898.ge 23.53N 27.18W -87.7 48.07 #1 4000.00 3998.9!: 21.58N 21.58E West Foreland 3999.01 3998.8€ 24.52N 27.34W -86.6 48.28 #1 4100.0C 4098.9G 21.58N 21.58E West Foreland 4099.03 4098.87 25.54N 27.51W -85.4 48.52 #1 4200.0C 4198.99 21.58N 21.58E West Foreland 4199.13 4198.98 26.36N 27.51W -84.4 48.59 #1 4300.0C 4298.99 21.58N 21.58E West Foreland 4299.0< 4298.8E 27.48N 27.51W -83.1 48.71 #1 4400.0C 4398.99 21.58N 21.58E West Foreland 4398.96 4398.82 28.75N 27.66W -81.7 49.03 #1 4500.0C 4498.9!: 21.58N 21.58E West Foreland 4499.0€ 4498.81:' 30.04N 27.71W -80.3 49.28 #1 4600.0C 4598.99 21.58N 21.58E West Foreland 4599.07 4598.81:' 31.62N 27.60W -78.5 49.46 i #1 4700.0C 4698.96 21.58N 21.58E West Foreland 4698.9< 4698.74 33.25N 27.64W -76.7 49.85 #1 4800.00 4798.99 21.58N 21.58E West Foreland 4799.0L 4798.82 34.71N 27.68W -75.1 50.25 #1 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 90.0ft 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) Casings Included Prepared by Baker Hughes Incorporated ~ ~ e Forest Oil Corp. WF #2 Verso #8, West Foreland#2 (8) WF#2, West Forelands Pad #1 Reference MD[ft] Clearance Data Reference East[ft] 4900.0C 5000.0C 5100.0C 5200.09 i 5300.0C 5400.0C Reference TVD[ft] 4898.99 4998.99 5098.99 5198.91 5298.99 5398.9€ 5500.0C 5498.82 5600.0~- 5598.4< 5700.00 5697.69 r 5800.0C 5900.0C 6000.0C 6100.00 6200.0C 6300.00 6400.0C 6500.00 6600.0C 6700.0C 6800.0C 6900.0C 7000.00 7100.00 7200.00 ¡-----nOO.OO ~OO.OC 5796.45 5894.61 5992.01 6088.61 I 6184.25 6278.8C 6372,15 6464.2C 6554.83 6643.92 6731.38 6817.0~ 6900.95 6982.87 7062.7:: 7140.4£ 7215,9C Reference North[ft] Offset Well I Offset MD[ft] 21.58E West Foreland #1 21.58E West Foreland #1 21.58E West Foreland #1 21.58E West Foreland #1 21.58E West Foreland #1 21.25E West Foreland #1 20.24E West Foreland #1 18.57E West Foreland #1 16.24E West Foreland #1 I 13.24E West Foreland #1 83.0~~ 9.58E West Foreland #1 105.10NI 5.27E West Foreland ~ #1 13o.501jo.31E West Foreland . #1 159.19N 5.30W West Foreland #1 191.14N[ 11.54W West Foreland . #1 226.32N 18.41 W West Foreland #1 25.90W West Foreland #1 33.99W West Foreland' #1 42.70W West Foreland #1 51.99W West Foreland #1 61.86W West Foreland #1 72.30W West Foreland 1#1 83.2911I1 West Foreland #1 94.83W West Foreland #1 1 06.89W West Foreland #1 119.4 7W West Foreland 1#1 21.58N 21.58N 21.58N 21.58N 21.58N 23.29N 28.43N, 36.98N 48.94N 64.30N 264.66N 306.14N 350.69N 398.27N 448.82N 502.27N 558.56N[ 617.62N 679.38N 743.77N i 4898.91 4998.7 5098.9 5198.91 5299.01 5399.0E 5498.72 5598.31 5697.37 5796.33 5894.63 5992.55 6089.6€ 6186.0€ 6281.07 6373.87 6467.27 6559.55 6650.2€ 6738.6€ 6823,6~ 6905.83 6989.58 7065.61 7147.45 7230.02 e CLEARANCE LISTING Page 4 Date Printed: 17-Aug-2004 West Foreland, West Cook Inlet, Alaska Offset TVD[ft] 4898.72 4998.5:: 5098. n 5198.6€ 5298,7€ 5398.82 5498.4€ 5598.0~ 5697.1C 5796.05 5894.3~ 5992.21 6089.3€ 6185.75 6280.75 6373.5~ 6466.93 I 6559.19 6649.89 6738.27 6823.2~ 6905.42 6989.16 7065.19 7147.03 7229.5~ I Offset North[ft] 36.31 N 37.82N 38.65N 39.27N 40.02N 40.88N 41.82N 42.39N 42.76N 43.11 N 43.63N 44.48N 45.51 N 46.73N 48.08N 49.15N 50.09N 51.48N 53.11N 54.88N 56.42N ] 57.46N, 58.38N 59.08N 59.51 N 60.86N ... .... INTEQ I Angle Closest From Approach Highside Distance rdeQl fftl 27.65W -73.3 Offset East[ft] 27.98W 28.39W 28.72W 29.01W 29.01W 29.29W 30.02W 31.12W 32.29W 33.37W 34.44W 35.08W 35.45W 35.53W 35.72W 36.74W 37.63W 38.07W 38.22W 38.08W 37.86W 38.05W 38.45W 38.66W 38.82W I -71.9 -71.1 -70.6 -70.0 -59.7 -63.9 -72.6 -86.3 -103.6 -120.9 -134,9 -145.4 -152.91 -158.3 -162.2 -164.9 -166.9 -168.7 -170.0 -171.2 -172.1 -172.8 -173.3 -173.8 -174.3 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 90.0ft 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) Casings Included Prepared by Baker Hughes Incorporated Ellipse Separation [ft] 50.66 51.43 52.08 52.59 53.11 52.52 50.58 48.17 47.03 49.49 57,56 71.73 91.34 115.71 144,35 177.29 214,13 253.99 296.95 343.01 392.44 445.44, 501.53 560.66 622.93 687.07 J e e @ Forest Oil Corp. CLEARANCE LISTING Page 5 -rA: WF #2 Verso #8, West Foreland#2 (8) Date Printed: 17 -Aug-2004 WF#2, West Forelands Pad #1 West Foreland, West Cook Inlet, INTEQ Alaska Clearance Data 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] fdeQl fftl 7500.00 7289.03 810.70N 132.54W West Foreland 7302.69 7302.25 62.29N 38.96W -174.6 753.63 #1 7600.0C 7359.7< 880.10N 146.09W West Foreland 7370.71 7370.25 63.39N 38.94W -174.9 823.04 #1 7627.04 7378.43 899.28N 149.84W West Foreland 7389.65 7389.19 63.64N 38.90W -175.0 842.30 #1 7700.0C 7428.62 951.25N 159.99W West Foreland 7438.5C 7438.04 64.20N 38.76W -175.3' 894.61 #1 7800.0C 7497.4C 1022.491\ 173.90W West Foreland 7508.46 7507.99 64.98N 38.54W -175.7 966.36 #1 7900.00 7566.19 1093.73[\ 187.81W West Foreland 7578.615 7578.1 E 65.79N 38.45W -176.0 1038.0e #1 8000.00 7634.97 1164.971\ 201.73W West Foreland 7648.42 7647.94 66.60N 38.52W -176.3 1109.71: #1 8100.0C 7703.715 1236.211\ 215.64W West Foreland 7716.1 E 7715.70 67.35N 38.67W -176.5 1181,52 #1 8200.00 7772.54 1307.461\ 229.55W West Foreland 7782.17 7781.6E 67.86N 39.15W -176.7 1253.44 #1 8300.0C 7841.32 1378.70[\ 243.47W West Foreland 7849.11 7848.62 68.14N 39.95W -176.8 1325.55 #1 8400.0C 7910.1C 1449.941\ 257.38W West Foreland 7911.8< 7911.34 68.28N 40.68W -176.9 1397.82 #1 8500.0CI 7978.89 1521.181\ 271.29W West Foreland 7970.57 7970.07 68.08N 41.38W -177.0 1470.47 #1 8600.0C 8047.67 1592.421\ 285.21W West Foreland 8038.515 8038.04 67.52N 42.28W -177.1 1543.43 #1 8700.0C 8116.46 1663.661\ 299.12W West Foreland 8127.63 8127.11 67.44N 43.47W -177.2 1615.86 #1 8800.00 8185.24 1734.90[\ 313.03W West Foreland 8210.4C 8209.87 68.23N 44.61W -177.3 1687.6C #1 8900.0C 8254.02 1806.141\ 326.95W West Foreland 8273.915 8273.41 68.95N 45.40W -177.3 1759.23 #1 9000.0C 8322.81 1877.38[\ 340.86W West Foreland 8335.17 8334.62 69.37N 46,06W -177.4 1831.2C #1 , 9100.00 8391.59 1948.62[\ 354.77W West Foreland 8393.84 8393.29 69.39N 46.73W -177.5 1903.5E 9200.01 #1 8460.37 2019.861\ 368.69W West Foreland 8483.3C 8482.75 69.61 N 47.97W -177.5 1975.84 #1 9300.0C 8529.16 2091.10[\ 382.60W West Foreland 8556.69 8556.12 70.44N 48.88W -177.6 2047.48 2162.34j #1 9400.0C 8597.94 396.51W West Foreland 8623.04 8622.46 71.25N 49.10W -177.7 2119.17 #1 9500.0C 8666.73 2233.58 41 0.43W West Foreland 8686.83 8686.25 71.91 N 49.05W -177.8 2191.03 #1 9516.39 8678.0C 2245.261\ 412.71W West Foreland , 8697.63 72.01N 49.04W -177.8 2202.82 86862~ #1 9600.00 8735.51 2304.82[\ 424.34W West Foreland 8750.0 8749.42 72.40N 48.93W -177.8 2263.0E 9700.01 #1 8804.29 2376.061\ 438.26W West Foreland 8618·'1 8818.17 72.80N 48.90W -177.9 2335.25 #1 9800,O~ 8873.0e 2447.30[\ 452.17W West Foreland 8892.7 8892.16 73.31N 49.05W -178.0 2407.33 #1 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 90.0ft 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) Casings Included Prepared by Baker Hughes Incorporated (j) e Forest Oil Corp. WF #2 Verso #8, West Foreland#2 (8) WF#2, West Forelands Pad #1 e CLEARANCE LISTING Page 6 Date Printed: 17-Aug-2004 West Foreland, West Cook Inlet, Alaska ... .... INTEQ Clearance Data 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] rdeQ] 1ft] 9900.0C 8941.8E 2518.54/\ 466.08W West Foreland 8955.57 8954.91:' 73.74N 49.33W -178.0 2479.38 #1 10000.~ 9010.6: 2589.78[\ 480.00W West Foreland 9027.78 9027.2C 74.08N 49.77W -178.1 2551.55 #1 10100.0 9079.42 2661.03[\ 493.91W West Foreland 9116.9E 9116.3E 74.93N 50.44W -178.1 2623.37 #1 10200.0C 9148.21 2732.26[\ 507.82W West Foreland 9188.7C 9188.17 75.87N 51.13W -178.2 2694.9~ #1 I 10300.0C 9217.0C 2803.51 [\ 521.74W West Fore/and 9245.7E 9245.1 : 76.51 N 51.78W -178.2 2766.61 #1 10400.0C 9285.71:' 2874.75[\ 535.65W West Foreland 9266.0C 9265.39 76.67N 52.03W -178.2 2838.9C #1 10500.0C 9354.5E 2945.99[\ 549.56W West Foreland 9266.0C 9265.39 76.67N 52.03W -178.2 2912.7E #1 10600.0C 9423.35 3017.23[\ 563.48W West Foreland 9266.0C 9265.39 76.67N 52.03W -178.2 2988.15 #1 10631.41:' 9445.0C 3039.65[\ 567.86W West Foreland 9266,OC 9265.39 76.67N 52.03W -178.2 3012.17 #1 Offset Well bore Survey Tool Proarams Well I Well bore I Survey Name I MDIft] d Survev Tool I Error Model West Foreland #1 West Foreland #1 , Gvro<0-9266'> 9266.0 Level Rotor Gvro Standard All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 90.0ft 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) Casings Included Prepared by Baker Hughes Incorporated e e 13 5/8" Annular ( ~ 13 5/8" Double Gate o 0 13 5'8" Mud Cross ~ ~ 13 5/8" Single Gate ~ ~ Kuukpik Drillin~ Rig 5 13 5/8" 5,000 PSI BOP Stack Drawn By: L Ross Date: 8/13/04 e . Choke And Kill Lines and Valve on Kuukpik Rig 5 3" Mud Line from Mud Pumps to Rig Floor I u 52 - 2" 5,000 psi threaded valve = _ 2" 5,000 psi flanged hose KiiI Line Side = 2 2 1116" 5,000 p"..1ed man,al ,,"Ive 0- .. 2 1/16" 5,000 psi rated manual valve = o D,'"'ng Spool Choke Line Side co=r 52 co=r ~ = ~ 31/18" 5,000 psi Hydraulic Operated Valve _ 3 1/18" 5,000 psi Manual Valve 3" Flanged Choke Hose = To Choke Manifold inlet Kuukpik Drilling Rig 5 Choke and Kill Line Layout July, 2003 Drawn By L Ross 2 To Shaker 3" Panic To Gasbuster --~~ Automatic Choke 3" 5,000 Choke Manifold Kuukpik Drilling Rig 5 Drawn Date: 8/1/04 '\ ------- ~ I o Close 21 1/4" 2,000 PSI Annular To Accumulator 16" Hydraulic Operated Knife Valve ,- I 21 1/4" Diverter Spool ¡ K\,I(jkpikDríl!ìngRìg5 21114"DìverterSystem DrawnBy:lRO$$ Date"a/13104 e e Supplemental APD Information West Forelands #2 On August 19,2004, the BLM issued a request for additional information from Forest Oil Corporation to supplement its Application for Permit to Drill the West Forelands #2 well. The information requested is provided below to the BLM and AOGCC: 1. BOP Test Pressure The BOPs will be tested weekly to a low pressure of 500 psi and a high pressure of 5,000 psi. In addition, the BOP stack to be used has been modified since the original APD was filed. A new BOP description is attached here. 2. Geological Information The prognosed geological tops are: Tyonek E 7400' Sand Tyonek F GO-Zone Upper Lower G-Zone -7260' TVD(ss) -7330' TVD(ss) -7935' TVD(ss) -8833' TVD(ss) -8968' TVD(ss) -9151' TVD(ss) -9300' TVD(ss) 3. Completion Diagram A completion diagram is attached. 4. Check Valve for Kill Line on Choke Manifold Forest Oil requests ofthe BLM a waiver from the requirement to incorporate a check valve in the kill line. This well will be drilled in the wintertime and the check valve would result in fluids being trapped in the kill line between it and other valves. If the trapped fluid freezes it would cause damage to the line and valves on the kill side, resulting in a compromised well control capability. 5. Survey Plat An as-built survey of the West Forelands pad, WF #1 well, existing facilities and the staked location for the WF #2 well was included in the original APD submission. We include here an additional copy of the as-built survey in case the one in the original submission was misplaced. 8/13/2004 I I e 13 5/8" 5000# WP HYDRIL, TYPE "GK" 13 5/8" 5000# WP SCREWED TOP BY 13 5/8" HUBBED BOTTOM ANNULAR BOP . MANUALL Y ACTUATED 2-1/16" 5,000# WP McEVOY TYPE ''£'' GATE VALVE MANUALL Y OPERATED 2-1/16" 5,000# WP McEVOY TYPE "E" GATE VALVE e KILL UNE 13-5/8" 5000# API FLANGED TOP AND BOTTOM MUD CROSS W/ ONE (1) 3-1/8" (CHOKE LINE) & ONE (1) 3-1/8" (KILL LINE) 5,000# API FLANGED OUTLETS 13-5/8" 5000# SHAFFER SINGLE GATE PREVENTOR - 13-5/8" 5000# WP STUDDED TOP AND BOTTOM ') ~ ~UUUU1 ~ r~ O[}-{]O ~ ~ï C~D] 1 O[}-{]O ~ ï_ f\Jln J ( 13-5/8" 5000# SHAFFER DOUBLE GATE PREVENTOR 13-5/8" 5000# WP STUDDED TOP AND BOTTOM HYDRAUL. ACTUATED ~ 3-1/8 " 5,000# WP\ ~ McEVOY TYPE "E" GATE VALVE n LINE MANUALLY OPERATED 3-1/8 " 5,000# WP McEVOY TYPE "E" GATE VALVE CHOKE 3" 29 BOP STACK 1 RIG WEST FOR.ELAND # 2 PROPOSED WELL COMPLETION ELEVATION: 88' Date: 8/4/04 RKB: 25' Prepared: .... '" ~ Methanol Injection Mandrels @ / 3,000' LS & 2,940' SS wi 3/8" Control J" Lines w/S' pups above and below M'" ~ 133/8" @ +1- 3,000' MDITVD - / .~ 7 S/8" 29.7# X 7" 29 # XO @ +1- 3,100' 3% KCL Completion Fluid ~ +-----= BOTH TUBING STR.INGS - 23/8" 4.7#/ft N-aO CS Trip Sub ~....-_........-- 2 3/8" "X" Nipple 2 joints above Packer in SS w/S' pups above and below ( 2 3/8" "X" Nipple 1 joint above Packer in w/S' pups above and below 7" 29 # Dual Hydraulic Packer for 2 3/8" @ 9,800' MD 4"_ ------ 2 3/S" Blast Joints across perforations +1.. SO' <II 2 3/S" "X" Nipple 1 joint above Packer in w/S' pups above and below ... 7" 29# Permanent Packer @ +1..10,27S'MD .. <Ci 7" 29# N-SO @ 10,649'MD/9,44S' SEE DETAIL WEST FORELANDS PAD #1 CENTERLINE EXISTING ROAD 9 ~ ~ SECl'ION 7J, TOWNSHIP SN. RANGE l4W SURFACE OWNERSHIP: SALAMATOF NATIVE ~ SUBSURFACE RlGHfS: CIRI ~ ~ -- - - --.... ~.,. "'- '- -...!?o "'- '- "'- '- "'" '- """ '-:--.. """ & '- '- ~ tel '-,- '- ~ ~ '-, 0 0 ~~ ..;:3 <: ~~ C\S ~ ,,~ $-..4 '" 0 CJ:} ~~ ~N o <: ~'ì' U ~ 5: ~ ~ ~¡ o 2~9 tn ~ ~ C)CJ:} $-..4~ ~~ .~ 9 "' Ii: ~ þ! e o .~/ --- ----------- -------- --...,...------ UNITED STATPS SURVEY NO. 4525 lOT 1 SURFACE OWNE.RSHIP: SAlAMATOP NATIVE ASSOC. SUBSURFACE RI~ CIRI -- = ~ .'<""~~ -- fIJ-Y= ø-- -- SECI10N 28, TOWNSHIP SN. RANGE 14W SURFACE OWNERSHIP: SAlAMATOF NATIVE ASSOC. SUBSURFACE RI~ CIRI NOTES: 1) BASIS Of COORDINATES IS FROtJ THE CONTINUOUSLY OPERATING REfERENCE STATION KEN' NEAR KENAI, ALASKA. COORDINATtS SHO¥/N HEREON ARE ALASKA STATt PLANE NAD 27 ZONE 4. 2) BEARINGS SHOWN ARE GRID AND ARE BASED ON REPEATABLE GPS OBSERVATIONS BETWEEN THE 2 INCH AUJMINUÞoI CAPPED ÞoIONUMENTS SET NEAR THE BLUFF ONE ON EITHER SlOE Of THE PIPELINE AUGNMENTS WHERE THEY COtJE ON SHORE FROtJ THE OSPREY PLA TFORÞoI. J) STATIONING SHO\\N HEREON IS BASED ON THE ASBU1LT LOCATION Of THE B" OIL UNE CONSlRUCTtD IN 2002- STATIONING BEGINS AT THE WESlERN MOST LEG Of" THE OSPREY PLATFORW (STATION 0+00) AND CONTINUES TO THE NORTH BOUNDARY OF UNITED STATtS SURVEY NO. 4520 AWENDEO (WOSOUITO ALLOTlotEND. 4) EASEMENT CENTtRUNE BETWEEN THE WHIIL OF COOK INLET AND THE WEST WCARTHUR FAClUTY SHOIWol HEREON IS NOT BASED ON ANY PlPEUNE CENTtRUNE. BUT WAS PLACED SO THAT AU. REOUIRED PIPELINES WOULD FALl. WITHIN THE EASEMENT \\10TH. FROtJ THE WEST MCARTHUR FAClUTY NORTH TO THE NORTH BOUNDARY Of" UNITED STATtS SURVEY NO. 4520 .wENDED, THE 60' EAsalENT SHOIIN HEREON SHARES ITS EAST EDCE '/11TH THE EXISTING 1I19S 20' ClRI EASEIotENT. THEREFORE, IT LIES DIRECTtY ADJACENT AND WESTERLY Of THE EXISTING 1995 ClRI EASEÞoIENT. 5) DISTANCES SHOWN HEREa-I ARE GRID, 6) THE PROPERTY BOUNDARIES SHOWN HERON wERE NOT RETRACED IN THE FIELD DURING THIS SURVEY AND ARE SHOWN FOR INFORWATlONAL AND COtJPUTATla-IAL PURPOSES ONLY. THE UNES SHO\\N HEREON REPRESENTING THE BEGINNING AND THE END Of" THE EASEMENT DESCRIPTIONS AT BOTH CENTtRUNE AND EDGE Of" EASEÞoIENT SHALL BE EXTtNDED OR SHORTENED TO ŒRt.lINÞlTt OR BEGIN AT THE TRUE PROPERTY BOUNDARIES. 7) SECTION UNES SHOIMol HEREON ARE PROTRACTED. e) SURVEY CONDUCTED BY WCLANE CONSULTING GROUP DURING CONSTRUCTION Of" PIPEUNES DURING SUMÞoIER 2002. 9) THE FIBER OPTIC UNE INSTALLED IN 2002 IS NOT SHOIMol GRAPHICALLY HEREON AND ITS LOCÞlTlON WÞlS NOT PHYSICALLY LOCATED. FRON THE BORE SlTt TO FOREST OIL FEE PROPERTY (STATION 94+47 TO STATION 152+02) THE ABER OPTIC UNE WAS INSTÞlLLED BETWEEN THE S· OIL LINE AND THE 6" GAS UNE, FROW FOREST OIL FEE PROPERTY HEADING NORTH TO WEST FORELANDS " PÞlD (STATION 22H2J TO STATION J70+00) THE FIBER OPTIC UNE WAS INSTALLED BETWEEN THE 6· GÞlS UNE AND THE ROAD SHOULDER. FROW WEST FORELANDS 11 PAD TO THE TRADING BAY PRODUCTION FAClUTY (STATION J70+00 TO 603+75) THE FIBER OPTIC UNE WAS INSTALLED BETWEEN THE 6· GAS UNE AND THE 8" OIL UNE. __,'~1"!\J.I(" -~..., ,~:. II - ....: :"'~.. I =.... ¡ :~ ....":.;,. _..,,~. 'I":," ~:[ ~~ it;.L 1 pj ~ "0'. j!:¡ ,.dJ!.. ~~~" en; :X:I: "Y'~'. +. ,,. ,';" = ",f.s-...~ jø~,-- " ,\\",-" ~ s '" " ... ¡¡¡ !G ~ ... s ... tJt: I- Z ... ;:¡ u .. ~ '" ~ .... t5 F "- Ii ¡¡ .., o ... l- e Q > ... tJt: ~ g .. o o z ~ 7'" o .ø N ~ ;¡ " z a. ~m ~ t:. !e _ "ði \T ~ ~~'" ~.:¡:¡ ~ :g Cl ãi~ ~ ¡..;. ~~~ ð ~~;::- Qj l:~ \J ~q ~ !i"- "' DRAIIN BY PCO CHEO<ED BY HORZ, SCALE I" .. 200' 'ÆRT. SCALE 1".. 20' DRWG. NO. O+J05tI SHEET 1 · e e TÞ~ @ FOREST OIL CORPORATION .51 0 oY{'c';líJ{cel. C.'fIZtlle 700 c.çfJlcIUJl'I~'€' Q9$la.Jlrx:r .9.9.501 25â'-S600 · (907) /ì5â'-/i60f (Q-¿;a,) August 11, 2004 D20~- \'-\ ~ Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Sent Via United States Postal Service Certified Mail Re: Forest Oil Corporation Application for Well Spacing Exemption West Foreland Field; West Foreland #2 gas well ("WF #2") Federal lease A-035019, State of Alaska lease ADL-359112 Dear Commissioner Norman: Pursuant to the direction I received yesterday from Mr. Steve Davies, Petroleum Geologist for the Alaska Oil and Gas Conservation Commission ("AOGCC"), I hereby transmit with this letter the following attached documents: 1. Personal notice prepared by Jim Arlington for Forest Oil Corporation (''Forest'') of the public hearing tentatively scheduled for August 26, 2004, at 9:00 am at the Alaska Oil and Gas Conservation Commission offices containing the following information, inter alia; i. Forest's drilling plans for the WF #2 and proposal for allocation of production; ii. Assertion that a spacing exception from the AOGCC is required prior to WF #2 production; iii. Forest's assertion that the CRA for the WF #1 well is in effect and, as to the parties to said CRA, stipulates how production from the WF #2 is to be allocated; IV. Forest's proposal that allocation of production from the WF #1 Reservoir encountered in the WF #2 be allocated based on the existing WF #1 CRA, i.e. 58% to the federal lease and 42% to the State of Alaska lease, and paid to the royalty owners without being escrowed; v. Forest's proposal that royalty monies from productive sands encountered in the WF #2 that are shallower than the WF #1 Reservoir be escrowed pending equitable determination. 2. List of Alaska State Lease ADL 359112 Royalty Owners known to Forest as of August 10,2004. 3. List of Federal Lease A- 035017 Royalty Owners known to Forest as of August 10,2004. 4. Proof of mailing to each of the parties named in each royalty owner list identified in documents #3 & #4. 5. Verification of Facts and Affidavit of Jim Arlington, dated August 10,2004, certifying that all the steps required by the AOGCC, as contained in the direction from Mr. Davies, have been taken by Forest and/or Jim ,,A,rlington on behalf of Forest I will be out of the country and/or out of the state until August 23m. During my absence, if there are any questions, or should you need additional information concerning this matter, please contact Mr. Bradley Brice in this office at (907) 868- 2126. Sincerely yours, AUG 1 2004 Enclosures as listed above cc (w/o enclosures): Bradley Brice Leonard Gurule ( o p y e e Forest Oil Corporation 310 K Street, Suite 700 Anchorage, Alaska 99501 (907) 258-8600 Fax: (907) 258-8601 W: Known royalty owners offederallease A-035017 and State of Alaska lease ADL-359112 (Distribution list provided to the Alaska Oil and Gas Conservation Commission) DAlE: August 10, 2004 SUBJECf: Forest Oil Corporation spacing exception application in accordance with 20 AAC 25.055. West Foreland #2 Well; Allocation of Reserves & Production Federal Lease (A-035017); State of Alaska Lease (ADL-359112) Forest Oil Corporation ("Forest") is providing you this letter as a versonal notice pursuant to directions received by Forest from the Alaska Oil and Gas Conservation Commission ("AOGCC''). This personal notice is to inform you of your opportunity to be heard by the AOGCC at a public hearing tentatively scheduled for August 26, 2004, at 9:00 am at the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. At this hearing the AOGCC will act upon the request submitted by Forest to approve an exception to the drilling unit and spacing requirements of 20 AAC 25.055 to allow drilling and operation of the West Foreland #2 gas production well bore to a location within 1,500 feet of the property line between Federal Lease A- 035017 and State Lease ADL-359112, and within the same governmental section as, and less than 3,000 feet from, a well capable of producing ftom the same gas pool. The West Foreland #2 gas well (''WF #2") will be drilled as a deviated well bore with drilling planned to commence in approximately one month. Production ftom the WF #2 is contingent upon approval of a spacing exception issued by the AOGCC, otherwise production ftom the WF #2 well will not be allowed, nor any royalties paid, as it would violate the statewide spacing requirements stated in 20 AAC 25.055. The surface location of the well is 880 feet from the south line and 631 feet from the east line of Section 21, T08N, RI4E, Seward Meridian ("SM"). The proposed bottom hole location of the well is 1,365 feet ftom the north line and 1,105 feet ftom the east line of21, T08N, RI4E, SM. The AOGCC has tentatively scheduled the public hearing on this application for August 26, 2004 at 9:00 am at the offices of the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. The AOGCC public notice, published July 23, 2004, provided that a person may request that the tentatively scheduled hearing be held by filing a written request with the AOGCC no later than 4:30 pm on August 10, 2004. The public notice went on to say that if a request for a hearing is not timely filed, the AOGCC may consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call (907) 793-1221 or check the Commission's hearing calendar at: http://www.state.ak.us/loca1lakpages/ADMIN/o¡1:c/hearlhear.htm However, even if a public hearing is not held, a person may submit written comments regarding this application to the Alaska Oil and Gas Conservation Commission at 333 West 71h Avenue, Suite 100, Anchorage, Alaska 99501. Written comments must be received no later than 4:30 pm on August 24, 2004 except that if the AOGCC decides to hold a public hearing, written protest or comments must be received no later than the conclusion of the August 26, 2004 hearing. If you are a person with a disability who may need special accommodations in order to comment or to attend the public hearing, please contact Jody Colombie at (907) 793-1221 before August 13, 2004. As you may recall, you received a similar notice ftom Forest last year regarding a hearing before the AOGCC regarding the West Foreland #1 gas well (''WF #1"). At that hearing the AOGCC granted Forest a permanent spacing exception for the WF #1 and authorized tennination of the escrow account established by Forest into which all royalty proceeds from WF # 1 production were deposited since the well began production in 2001. The WF #1 was shut-in until April 2001 when Forest, the Bureau of Land Management ("BLM") and the Alaska Department of Natural Resources ("DNR") executed a Compensatory Royalty Agreement ("CRA") to allocate production ftom the WF #1 between federal lease A-035017 and the State of Alaska lease ADL-359112. The CRA was required by the AOGCC J pursuant to Conservation Orders No. 450 and 450-A granting a pennanent exception to the spacing requirements of 20 AAC 25.055 to allow production of gas ftom the WF #1 from any interval not deeper than 9,527' MD. The terms of the CRA and Conservation Order No. 450B established an allocation of 58% to the federal lease and 42% to the State of Alaska lease for any gas production from any interval not deeper than 9,527' MD in the WF#I. Forest is currently awaiting approval ftom the BLM and DNR regarding the valuation of the gas produced so that the funds from the escrow account can be disbursed to all parties who have an interest in the gas produced from the WF #1. Page 1 of2 (Over) e e Forest's requested exception to the statewide spacing regulations for the WF #2 is necessary to optimize gas recovery from the Tyonek fonnation in the West Foreland Field. The proposed bottomhole location for the WF #2 will be updip from the existing WF #1 and near the common lease line separating the State of Alaska and federal leases. The proposed bottomhole location of the WF #2 for projected productive intervals in the 9,200' sand and 9,400' sand will be in Section 21, T08N, RI4W, Seward Meridian and east of the . common lease boundary. Forest is seeking a permanent spacing exception from the AOGCC for the 9,200" sand and the 9,400' sand in the WF #2, since production from these sands has already been scrutinized during, and was the subject of, the AOGGCC spacing exception hearings regarding the WF # 1 well. Further, these sands are part of the "Reservoir" already the subject of the CRA, entered into to address not only the allocation of production from the WF # 1 among the two leases, but also the allocation of such production from other wells drilled into these producing sands. The "Reservoir" is defined in the CRA as the following; 'The two gas-bearing zones as encountered in WF #1 at 9502'-9527' and 9336'-9352' and all gas-bearing strata in communication therewith are jointly referred to hereinafter as "the Reservoir." Forest is seeking a temJJOrarv spacing exception from the AOGCC for any producing sands encountered in the WF #2 well that are shallower than the top of the 9,200' sand, which Forest anticipates will be no shallower than -8,850' TVDss. Forest would expect the AOGCC to prescribe a procedure similar to that prescribed for the temporary spacing exception granted for the WF #1 well, i.e. place an amount equal to 17 1/2% of the total production of WF #2 shallow sands for the Production Month, multiplied by the prevailing value for Cook Inlet gas into an escrow account until a CRA is entered into and a final allocation of production among the two leases is agreed to by and between the royalty owners or the parties to the CRA, subject to approval of the AOGCC. As stated above, the CRA that was entered into by and between the mineral interest owners and the operator for allocation of production from the WF #1 well already addresses additional wells to be drilled into the Reservoir to be penetrated by the WF #2 by providing the following: "Lessee intends to produce natural gas from WF #1 and potentially from additional wells drilled into the Reservoir with a bottomhole location on the Federal Lease or the State Lease. Gas and associated hydrocarbon liquids produced by WF #1 and by any other well with a bottomhole location in the Reservoir and on the State Lease or the Federal Lease is referred to herein as "Subject Gas." Forest proposes to apply the provisions of the existing CRA to production from the Reservoir in the WF #2 as well. The relevant language from the CRA is excerpted below: "5. Term and Modification of Final Allocation. 1bis Agreement shall become effective when it is fully executed by the United States (in a manner binding the Bureau of Land Management), the State of Alaska, and Lessee, and shall apply to all production of Subject Gas from the State Lease and the Federal Lease beginning on the Effective Date. 1bis Agreement shall continue in full force and effect until: (1) all Escrowed Funds have been paid out of the Escrow Account pursuant to the Final Allocation and the terms of this Agreement; (2) the Federal and the State Leases have terminated; and (3) all wells producing Subject Gas from the Reservoir are plugged and abandoned." Forest proposes that production from the Reservoir encountered in the WF #2 well be allocated as provided for in the CRA and CO··450B· andthatfurestbe allowed-to distribute royaltienluefromsaid·ReservoirproductiOttwthe·mínerahnterest ·and-GRRlowners pursuant to the terms of each lease. 1bis means that production from the WF #2 will be allocated 58% to the federal lease and 42% to the State of Alaska lease and royalties paid from WF #2 Subject Gas produced from the Reservoir as provided pursuant to the tenns of each lease without the need to deposit said production into the escrow account which the AOGCC authorized Forest to terminate in CO 450B. If there is any production from any sands other than the Reservoir, Forest plans to place an amount equal to 17 1/2% of the total production of WF #2 shallow sands for the Production Month, multiplied by the prevailing value for Cook Inlet gas into an escrow account until a CRA is entered into and a final allocation of production among the two leases is agreed to by and between the royalty owners or the parties to a CRA for said shallow sands, subject to approval of the AOGCC. Forest has established a dedicated email account for you to send any questions to you may have regarding Forest's spacing exception application for the WF #2 submitted in accordance with 20 MC 25.055. That email addressiswf2@forestoiI.com . Forest will provide responses to any question submitted to that email address to all recipients of this personal notice who send their email address to the wf2@forestoiI.com email address. cc: Alaska Oil and Gas Conservation Commission by certified mail Page 2 of2 e e Distribution List for Notice Regarding Alaska Oil and Gas Conservation Commission Hearing August 26, 2004 Alaska State Lease ADL 359112 Royalty Owners as of August 10. 2004 Alaska Department of Natural Resources Division of Oil and Gas Attention: Mr. Chris Ruff 550 W. ih Avenue, Suite 800 Anchorage, AK 99501 Gregory S. Burgess 3 Shªlœsfield Close Trendington, Warwickshire United Kingdom CV36 4ND Keith W. Calderwood Revocable Trust Nadene Calderwood Trustee P. O. Box 495 Kenai, AK 99611 Enea Tekna Investments Attn: Mathew Gavora PO Box 70021 Fairbanks, AK 99707 Lab Properties Inc. 5919 7ih Avenue SE Mercer Island, W A 98040 The Medema Family Trust James D. & Mille Medema Trustees D. Medema Perry, Co-Trustees P. O. Box 70109 Fairbanks, AK 99707-0]09 Robert L & Deanna Persons PO Box 403 Girdwood, AK 99587 William D. Renfro Estate 3940 Arctic Blvd., Suite 103 Anchorage, AK 99503 John. M. Robinson 9333 Memorial Drive Suite 203 Houston, TX 77024 William G. Stoecker PO Box 71230 Fairbanks, AK 99707 Edgar Boyko Estate Georgie Lee Boyko Executor 3020 S. 5th Avenue Pocatello, ID. 83204 Robert Breeze Irrevocable Trust Virgina Breeze Trustee 800 F Street Unit P-6 Juneau AK, 99803 Jason M. Burgess 3346 E. Toronto Drive Phoenix, AZ 85044 Jefferey L. Burgess 4691 N. La Lomita Tucson, AZ 85718-6028 Charles E. Cole 406 Cushman Street Fairbanks, AK 99701 Coil Inc. 5914 124th CT NE Kirkland, W A 98033 HV A Royalties Attention: Harold Van Arnem 733 North Ocean Boulevard Delray Beach, FL 33483 William Harry McDonald 6640 Jollipan Court Anchorage, AK 99506 Limestone Oil & Gas Company 4501 Nassau Wichita Falls, TX 76308 John C. McDonald 1800 E. A Street Anchorage, AK 99501-1834 William Harry McDonald 6640 Jollipan Court Anchorage, AK 99506 Patina Oklahoma Corp. Attn: Debbie Ahlstrom 1625 Broadway, Suite 2000 Denver, CO 80202 Polaris Fund L. P. 400 Seaport Court, Suite 250 Redwood City, CA 94063 Jin K Raee 2233 Birchda1e Drive Thousand Oaks, CA 91362-1532 John K. Garvey Revocable Trust R.H. Garvey Bldg., Suite 1050 300 W. Douglas Ave. Wichita, KS 67202-2911 Jack H. & Helen E. Richardson 3511 A Andree' Drive Anchorage, AK 99517 Carolyn L. Shogrin PO Box 29450 Santa Fe, NM 87592-9450 SPC LLC Attn: K. Battley Managing 500 L Street, Suite 302 Anchorage, AK 99501 James L. Thurman & Leta Thurman 925 Aurora Drive Fairbanks, AK 99707 Richard E. Wagner P. O. Box 60868 Fairbanks, AK 99706 e e Distribution List for Notice Regarding Alaska Oil and Gas Conservation Commissi on Hearing August 26, 2004 Federal Lease A-035017 Royalty Owners as of August 10. 2004 Winton C. Arnold JI. and Alice Calvert 411 University St., Suite 1200 Seattle, W A 98104 Mary T. Brooks 415 Flat Top Sheep Ranch Carey, ID 83320 Barbara Dimock 4093 220th Place S.E. Issaquah, W A 98027 Mary H. Hale 3157 D Road Grand Junction, CO 81504-6181 Harold Kravik 3020 E. Main St., # E-44 Mesa, AZ 85213 Medema Family Trust James D. & Millie Medema, Trustees P. O. Box 70109 Fairbanks, AK 99707-0109 Cook Inlet Region, Inc. Attention Kirk McGee, VP PO Box 93330 Anchorage, AK 99509-3330 Paul Dixon Beaulieur 9 bis rue du Pont 41400 Montrichard, FRANCE David R. Cottis 35670 Hummingbird Lane Squaw Valley, CA 93675-9715 Dippel West Foreland Trust Nola B. Sanders Trustee 359 Gean St. Mesquite, NV 89027 Gregory C. Taylor, Esq. (representing Harry 1. Hill, Deceased) Jermain, Dunnigan & Owens 3000 A St., Suite 300 Anchorage, AK 99503 Kreielsheimer Foundation (representing Leo T. Kreielsheimer, Deceased) 10 Harrison St., #302 Seattle, W A 98109 Oil Investment Trust Address Unkown Minerals Management Service Royalty Management Program Box 5810 T.A. Lakewood, CO 80217 Richard D. Beaulieu, JI. Address Unknown C.P. (Jack) Coughlan, Deceased Heirs & Addresses Unknown The Erven Revocable Living Trust Melba C. Erven, Trustee 707 Hillcrest Ave. Roseville, CA 95678 L. Warren Hines 4856 Bryn Mahr Ct. # 1 Anchorage, AK 99508 MI. Steve Martinez US Dept of the Interior Bureau of Land Management 222 West 7th Ave. #13 Anchorage, AK 99513 Mary Pryor Thomas 10800 Hideaway Lake Drive Anchorage, AK 99516 The Donald and Nola Dippel Trust Nola B. Sanders Trustee 359 Gean St. Mesquite, NV 89027 ru Ul ..D Ul . - . - CERTIFIED MAIL RECEIP (Domestic Mail Only; No Insurance Covero~e Provided) f"'\'i .1 ~} :.~^' ft"'E 2;'",,,ik-^_o:c FAIRBANKS,ÀK -,;'¡^ ;<; Postage !;¡97fJ7 · ,. .~:~(:~i~~f /1_" (', ~ Here! '" ¥'": ,~~ "'",,- J./) " c~4 QF'lNP~ ,>::-: -- ~ $ 4;~o~ - ';\~¿1 "",'''i"'i 0- o .::r ITI Certified Fee .::r o o o Return Receipt Fee (Endorsement Required) Restricted Delivery Fee (Endorsement Required) o r'I Ul ru Total Postage & Fees Ser The Medema Family Trust James D. & Mille Medema Trustees D. Medema Perry, Co-Trustees P. O. Box 70109 Fairbanks. AK 99707-0]09 ._~~----------- .~------------- r'I -'ši¡', 0 orl 0 '-ëi~ ['- .. ",.,,¡.;tIIllI(lme111}; ITI t:Q ...D Ul u.s. p' OS 'a . - -~i'" ~_.. .. '.. . -- CERTIFIED MAIL RECEIPT (Domestic Mail Ohly; No Insurance Coverage Provided) fY:,'\i, !"';~' ,_A KENAI', fíK99611 0- o ::z- ITI Postage $ Certified Fee .::r o o o Return Receipt Fee (Endorsement Required) Restricted Delivery Fee (Endorsement Required) o r'I Ul ru I.J .'Jf-~ 08/10/04 Total Postage & Fees $ Sent To Keith W. Calderwood Revocable Trust Nadene Calderwood Trustee P. O. Box 495 Kenai, AK 99611 r'I ušii-èëi; o or POI o --ëïiÿ,'si ['- - ..- u.s. Postal Service -- - - -- - -- -'-- CERTIFIED MAIL RECEIPT (Domestic Mail Only; No Insurance Coverage Provided) ê r n r;::' \í""'\' ,èçc" ANßHðRAGE, ~R ¡~~1 ~1J -E; :,;::;: 0l;g '1 I)~,ífl: 0502",,\ n. -.~ '/.'1' -".~' "," ~'';' ,""¡ ~,,~... -'~"- <... )¡ pos~Jrk \ .::r Return Receipt Fee Ii ....c-- ( Here o (Endorsement Required) JJ. ., (J,I \ ,C. g (:n"J::::~e~te~~~~i~~ çi~}fQF'lNP ~Q." ~ Total Postaae& Fee,s $ 44~ O~-~' \) Ul -šëñï7 A~a~~a Department of Natural Resources _ ru DlvISlon of Oil and Gas Attention: Mr. Chris Ruff 550 W, 7th Avenue, Suite 800 Anchorage, AK 99501 ~t 0- o .::r ITI Postage $ Certified Fee r'I . sii-èëi, o or PO o ['- "ëiiÿ,-~ - I!IIIIIIIII!II!- S;lJ s»(fJ '<" ,,1\)0 Qg3 0.'" Co) TO FROM ¿t 2 ~~ ~ ~ S g_~9> ~~~þ..~~ ~~ ~6 ~ \1\ ~ ~ ~ <I> ~ ~, c¡¡g:c ~ ~ '\..: ~ ~:? <:> i~h ~ (}:, .,.. ~ "" ~ :I ¡;: §-='9.~~ ) ~ ~ ~ h Ø> -:Þ-~ F: ~ ~ \J\~' (- ~~ (Þ!p. !: ~~~~ ~~ ~ ~~~ oKlr::;<q ~1!3 ~ ceo ~ ~~ ~\'T ~< 'i =(þ-'" ~ ~ ~ ì\ ~ š~ š~ ~ $-.ti ~ ~s~~ ~ a. ~ ""-It'- ~:i!~:i!~ - , 'í:::JV I' ~I" ~Û):s: ~,~ ~ !: - ~ & ê: ~ ~~ ~ è (IJ ~~ ~ ~ m C:§ )0., \:S ~ ~ ~ {"" ~ g<~ ~g~ "':0 g¡ ~ä ii!:¡ ~~ To Be Completed By C'" (Please Print) ... All Entries Must Be in Ballpoint or Typed S;"'t1 s»(fJ '<" ,,1\)0 Q83 a.'" Co) TO o~co !I§;~~ Ú\f t8:D~'~ ~ -<~~ C:! (S ~ ~~~"~ ~.'- ~~ ~~: ~ .l\Y ' go. Q~ ~ ~ ~ f~ ~ ~ r l ~ ~~ ~~ éÕ :S:~~~& ~g>æ ~ ~ !~ ; -"s' ~ ~ . :~ Õ' ~ 'i:: 3 '" ~~¡{"* ~g~~.l\' ¡~ g -;' '- \, . <;\:0 g¡ I.......... (þ ., \./ (§õ ii! '3 (þ(þ ~-. To Be Completed By Customer (Please Print) All Entries Must Be in Ballpoint or Typed FROM }~f ~ ~ '\ ~ ~ '. \). ('. ~~ ~~~ ,,~ ~' ~ ~\f\~ ~.~ t ~ . ~ ~ ~ To Be Completed By Post Office ::t (þ ~ ~S ~ ; 'P a ~ ~~ i\" :-'1 !ij; ,_'1 o i ~ :D CD () (1) <' (1) a. 'UOI o :::r I» ¡. ~ ~ ~ <g~. /' ;>'.\''''''¡-IO ~ g./ . /';J;---0' ~ i ,('./ ~ g: ~-VGì ~ .3 - !C;)( - ~ -4 \ 111 *' ¡d~ ~ ~ ~ ~ ....... ¡m ;- ",,,,g !2.'2;" oQ '=' J;. (f) _ ;:J (» s: ~.. ...¡::-.... I Ii ~ ~ ~ ~. , ~~ 0/':'--'/;- ¡;¡. D. \, (JI. , 3 {!.. g¡ 5' CD -., ' , ö"~:;;~.() " - c ..... r.'·..}.... - i" '0 '" ,~- ~ """ .:c __ '. /' !E O' ./ "'--'-:--:,-~,,,;=-~-_. To Be Completed By Post Office ; ~ :D (1) ~: 'P -n ~: (1) (1) -4l~ ;;>:I --J t r_r. ~ 0 - t G -no :D 'U OI <: <: (1) 0 :::rl» =", () '" I» ::J <ô (1) or ~a. <- IO=: !!!.3 '" (1) ::J (1) (1) '" <: (1) a. (1) ~ CT ....š:: '< <: !!¡. '\ 0 0 '" () en ¡¡¡ 0 ¡¡¡ F O:D :IJ:D <D CD <D <D r\lD. II!~ ~:;::E ~~ ~~ ~~ ~~ ~ '1J g!. o .. ,. - !: ..... ....:¡ (.f¡ \, '" (:<"onc 5"~ 0 / CO -I' Z ¡þ3/ ........mP-oi ~ ~ ~I :5 *:"'-,¡t :t ~ go :fX..!l ~~. \''j'. \~ i' 3' ¡¡: ~ 'gí1~~ ~ ;;; i i ~'B: ¡ , ."1 " 2i <:> ~. i ~s: ~~" ~ g " 5''iP~~', 0 r·-.), ~ ¡. õ~;- ..,".1 . '._~---'- t II ¡¡ (¡ § -t . .. . C·ERTIFIED MAILTM RECE T " 1_,,-' ","., ..- I .., - - -.,--, ,-. ...[] .C{ ~ r;¡·I.'r'1II'l~".llj¡.]jll"jn'JII.'/~ill:'IIIA"'¡~'J.iIL(~\.'I"I.·..u'llIl~i ~.s~~~·JI~ £r _. ,t: ~I 1,/"\ I ·.,ø%' ..~ I f'- . 1Ab~'~1 ..~\.-_ A.. -..,~ ~ Postage $ O.Jl yt1¡....JH'fI: 05C....02.)~.\ ((~i 8.; '. ç;;c' \ 8 Certified Fee 2, 30 ~ i postma~ '. ! CJ Return Reciepl Fee . 75 0: i "Here ! ~ (:::::e:e::i: l. ;J ~erk:~QP1NP~::~i Lf} (Endorsement Required) i t / ~ $ l¡.42 081 1 0.ttì4 .... Total Postage & Fees .::r CJ CJ I"- Mary Pryor Thomas 10800 Hideaway Lake Drive Anchorage, AK 99516 -..-...... -, .............-... --. .-.-....-.-.... .-.....-......-. ¡.r.).h~"iUU.ur'1.1 u.s. Postal ServiceTM . . CERTIFIED MAILM - F I- r " I_,,~ . ",'., .._, . ~ . . .,.. - ,_. CJ Lf} c{ ~ i"';;Q;f1:~J£'TÃ"l"'"''ij''~''' Lf} ,L. _ '"'. ,,';.9 "- ru Postage $ . lJarr Uf~t iD. O,J~" ~~ M Certified Fee ~~it) ~í' , \ CJ ;. ~, : : Postmark ) g Retum Reclept Fee Ii . ""fI.L:"".:.. \, ..J:. Here l/.. J (Endorsement Required) '''' -r';:;;;J /") \ ',::¡' 1/) ./ ì ~ (~n~s¿nr:~W~~i~ q~}.:t~· QP1~f:W ~ $ l/-1.¡tJ,þ- 08/10ìOl¡ o' r-. Total Postage & Fees .::r CJ CJ I"- Patina Oklahoma Corp. Attn: Debbie Ahlstrom 1625 Broadway, Suite 2000 Denver, CO 80202 ...... ........- ...-.- -- ...-- --,'" ....---................-...----. iI.(.~"'i.IIIl-i¡r.D.J u.s. Postal ServiceTM ., "Ñ "I,~D., ~.A,IL, :eM ,R, E. C,E,IP, ,T, . , '. _. IT1 .::r c{ ~ r··..;~',·'''·Ë~~:¡:c:¡:;;:T''''1rs·''~ ~ Postage $ o,~l' ~-ÙI: 0502 ~\ 8 Certified Fee ~.ao (If Postmark \~) g (End:r:r:~:¡~I;:ij 11."~'(:/'i' Here .... / CJ Restricted Delivery Fee C~;r~::: QP1NF~';;/ ::ri (Endorsement Required) JI.12 08~;;' '::/ M Total Postage & Fees $ .::r _ CJ Sen CJ I"- -~ orF 'ëitÿ, Jin K Raee 2233 Birchdale Drive Thousand Oaks, CA 91362-1532 ..................-.....---. ...."'--,_.................. -. ¡¡¡¡IIU"'('''~ U.s. Post,.' C)erViCeTM CERTIFta...J MAlbM RECEIPT . . ,,- . ",' ., '.. I .., ~ _ - ~.. . _ .,.. I"- ...[] c{ IT1 ~ ri·..·"'··'":i·:~I';E:'ï"Ã"r:¡Š~, I ru Postage $ Q:ø1 /~Ii: 05Q2·;~.,,\ 8 Certified Fee ;?tiD ¡ ¿[{(ô'r '. \ g (Ern:r:~~~:rui~ J;~ ';~\\ .2P= /~')) ,0" /~1 CJ Restricted Delivery Fee mgrr" QP1N~'6 '> ./ ~ (Endorsement Required) .'.:<~. ':_ ~,. M TotalPostage&Fees $ Jf.dtiL- 08/10/04 .::r CJSe CJ 1"-'& or 'ë¡ Jo1m C. McDonald 1800 E. A Street Anchorage, AK 99501-1834 _..........._--..._--~ ...-...-.......-..--...-. "I ~"I~~"1U~.(II.,'.1A1..... u.S. Postal ServiceTM - lED MAILM RECEIPT I . " - J'J .." ., .. _ ., - _ _ ..... _ .,., M c{ c{ IT1 ~ ri·";~Qjr¡:¡:z~L"·:iŠ'.~...',. I ~ Postage $ jj U~! Ii: 05ûi Q~ CJ Certified Fee a. 0")2 ^ . \ CJ ~ f/,Y .J>ostmark' CJ (End:~r:~~:Fui~ I ,r;f1S- '~3- Here /.0 J ~ Restrl.cted Delivery Fee Cl~WPlNPO / IT1 (Endorsement Required) ~ M Total Postage & Fees $ #.4f:(z~8/1 0/04- .::r CJ-¡ CJ I"- -: -..--- William Harry McDonald 6640 Jollipan Court Anchorage, AK 99506 ....--.--..-.....-----...-. .--..-..............--........-. . ~].m..'IUU.w.ld:- c{ .:r . ._, ., - . CJ t,,,- JI' , M ' :n(:I:~iI." 01 '.' u...¡...}..."f{'¡.111 ~ .::r .~.1.1.r'1II.¡~.·.I,,¡.Jj,,"jll.hlm,'HI..IIIA·I¡~.~ . ,';~ s e".. ~, T,t.OF~fioh(lrC I A lI;::_ '. \ Lf} . l· P_ '1'"{=L , JlN IT II!: 0502 ru postage $ va! 1 . ~l¡P ',1""& ~. M CJ CJ Retum Reciept.Fee CJ (Endorsement ReqUITed) CJ Restricted Delivery Fee Lf} (Endorsement Required) IT1 M Pc: 'St c~ postmark '.<{- Here .>_. C"l' e¡;;!.'·}'f:..Q· 1'1 fJPO . l-t~~,''''' Certified Fee .::r CJ CJ I"- ~rIV _Total postage & Fees $ . Minerals Management Service Royalty Management Program Box 5810 T.A. Lakewood, CO 80217 ...-...-..-------------. 08/10/04 - - --.-...----..-..-- - -.... !I1.JAIñ."UilU,w..,.. 'IT"' I'- ~ ~'::~;''"''''':';'''':':'''''':':':''''''::''':'~:'.'.'......;:.~,;,;<.,,:~ ~I . ~1E.1,c,1^~ L<!li~)f: I ,...:¡ CertifiedFea ".,J: J~Nrr IIi: 0502 ~ . f ........ ?10 ". D Return Rec1ept Fee P (Endorsement Required) '". ostmark 1. 75 ~.'J; Here D Restricted Delivery Fee' ~,' ~ (Endorsement Required) Cle~lN¡:'{\> ,...:¡<'_...!!~ "V Total Postage & Fees $ '1.42 08/10/04 =r r:: r:: I'" L. Warren Hines 4856 Bryn Mahr Ct. # 1 Anchorage, AK 99508 -..-.. ...-..- -----....---......... ......... -..-...-.......-..--....--- .\f~(.1."L.;.tlu,¡k.üJ..." u.s. Postal Servjcen~ CERTIFIED MAILTM RECEIPT . . ".. . ".' . ..... -, - . - ... - . . .,., =r c:J IT' IT1 ~ i>"'Z¡r~J';ë"ï"Ã"¡:"""'ij"i;"M ,...:¡ postage $ 0,",1 yµ,~~:Ú!: 0502 \ g CertlliedFee R'¡O 'á/ \\ c:J Retum Reciept Fee ~ . <" : PosImark c:J (Endorsement Required) /1.,16' ~'2.~' Here ..' .., J U1 Restricted Delivery Fee >" ' (Endorsement Required) }erk.~ QP1NPO"q~ / IT1 ," ,'. . -' ,...:¡ =r c:J c:J I'- Total Postage & Fees L.lf. ~~ Jefferey L. Burgess 4691 N. La Lomita Tucson, AZ 85718-6028 .-- ...--- .......... .........-..-. ',,-/ 08/10104 ........---------------- l"l...J.."i..ttl~fl~ u.s. Postal SerViCe"fM .' C. ,ER. ~IFI~D MAILM RECEIPT " J .. ., . i' I .. ' .. I ..... . - . , ',., cO IT' cO (T IT' .¡.J...~h.,q"..IJI(.J/II"¡IT.h...j!_ill".J"."lq !--11 . ~ I nQ¡Æ, Ii laG I Â l'~""":'s''''M n -.. · o:¡ ~~"':rïl: 05&<9 c:J Certirled Fee :h' s> c:J . :20·J :\~ ,,0 c:J "~æ ~-. t' ,'""0 ~ == 1'-'1/6 Ii;:iò"'.':::" IT1 (Endorsement Required) C~k: QP1NPO : Total Postage & Fees $ Jf .il/tf;- O~b; c:J c:J I'- Coil Inc. 5914 124th CT NE Kirkland, W A 98033 ...-..-..-....,...................... .00:-....-.........--..----. ¡r.....l<Wlbl.lb.... r-'I ,...:¡ [f"' IT1 r.J.11.~ll~oJ....IIIC.1j""'IT.]'..'j!-"iII".]'IIII...,¡q.¡."iI(,..\...........ij\I!_i~!-'i':O{.]I,~ ~. ~ LlfwF~lC I A L ltS E I ru 2-1.!": . , Postage $ Jj";;1IT 11T III: 0502 :"\ ~ '21') (~I .' \ t:JA.!~ \ 1.1/ \ c> I Postmark ¡.r.f¡5 ,~\ ~ Here c:J Restricted DeliVery Fee·~rk:cQP1NPO ~ (E::::~~~:~ ~ J/-.¿¡tfir 08/10k Winton C. Arnold Jr. and Alice Calvert 411 University St., Suite 1200 Seattle, W A 98104 r-'I CI c:J CI Certi1ied Fee Return Reciept Fee (Endorsement Required) / , ; ::1 c: c: ['" ---..---....................... ............. ---..- - ....... ..-",,,. l~:a¡t:¡,'I:ff;:L:.IIl.l.II..."Íi..n"U.Jt~.. U1 U1 CJ ",,- 11-·' ..:' I .., . .., =r rir.\I../'JIIl.,oJ"..¡I\C.J/I.1'lllaJ....'!-"i\1"..1'11II....('-I.í-"iI¡,.. .'!I:............/t,!-i·!-"!!o{·]"M :c I Rc.ØI6Ja hGI A L<;,tI'S'E U1 . --'. O' .. ru postage $ o;33""f:t¡Ñfr In:lf..,oZ ,...:¡ : ,. c c:J Certified Fee ~. Jij. ~: c:J &f'L \- C] Retum Reciept Fee .11.' "'¿',,'. (Endorsement Required) 7 - T ~ c:J Restricted Delivery Fee U1 (Endorsement Required) (T r-'I Total Postage & Fees g Postmark .;$.. Here "~ .nètf;;t-gplNF'O J 1..f-.4..t1l.-- os7ìõïo4 =r _ c:J . CI 1'-" $ The Erven Revocable Living Trust Melba C. Erven, Trustee 707 Hillcrest Ave. Roseville, CA 95678 .......-.........-.....-..... .............,....-....-...... ~.J.IÜ.'1.iàIJtin.Dl u.s. P~~t.ä~erviceTM C. ER~If!'~ MAILT: RECEIPT . I' - J. .. I '.&.. 1 .,. . . ., - . . ',. ru ...a CI ; ~>.,.."'.."..."".,.""..."..~"....'"'.".'''<~,.."..,.,.",.~<.,~ ~. AhQF:Ji:Ji: 19£31 A L ~S E". I : Postage $ Ü.J? G~'PíÐ: 0502 c:J Certified Fee ø ( c:J 2.30 <i : ~~ 1.75 \b,'x:"::' ~ (r~sgï::e':W~~i:::' CIèr:t(:" QPlNPO" ,...:¡ TotalPos\age&Fees $ 4.42 OB/l0/04 .~ =r c:J c:J I'- Mr. Steve Martinez US Dept of the Interior Bureau of Land Management 222 West 7th Ave. #13 Anchorage, AK 99513 ..--..-.....--................-. --.....-........--.-..-. It.J~.I..."'1wrtlf(.]IL.. o <0 [T'" , . " . 1'1·. I , m· ~ ~ r~·l·~¡~·ii~ptl':Ö;¡AiIL\·'·'·'·'·U:S·JIE I U1 . ,~~ LIt..{-.o.~;\ ~'50';'''- ru Postage $ tl'.~ r . .." .;:;~ ~'~~~6:'-) r=I t); 41'\ . .-~ \ o Certified Fee tJA-'" Jf1V c;? \ o p05Ìmar!< o Retum Reciept Fee Jj, .""flI- ¿r·.· Here ,5') (Endorsement Required) ,. .~ " ., Clerk:~QF'lNPO>.'~r' . Restricted Delivery Fee . (Endorsement Required) T_~I ð.......+___ O. C~e ct. JþAA 08710¡.o4 1 David R. Cottis 35670 Hummingbird Lane Squaw Valley, CA 93675-9715 ---------.........--.. -1 .....-.......-----..--. .j .JII."l-it.i'r"'if'llJ.: e- U1 e- m ~ i"';:Q"F"Ërë'ï"A"L~":';>':š"'~~, I Postage $ 0.37 ~ T IIi: 05æ \ r=I 'ü . \ g Retum ::::: 2.30 <~ .~ostmal1< )) ) (Endorsement Required) 1.75' .y,. ('.. Here/ "_,. ;.,..,..- .'1~_. .. // Restricted Delivery Fee Clerk:~.QP1NPO / (Endorsement Required) ---......-..."'!--............ D i'J-·' ..., ., '"' ~ " . II - ~.....\t.H..y.\n.II...jf-ill:.III..'.'l>l.!-il(,..,...\,~.~" . 'r' "'.,0( 'I",M -nr:.,-.r~ti't C II ~ I A m/.~ - . ~.( æ 9~«7 ~''"" . ~ ':- . . p~~ge '$ ..... o,..ð'f .6NIT I~Ö502\ : certified Fee ~'l: j /) postmark!! t:) ReCiept Fee / .1-;f=,£' ..J:!!Ire J t:) f\et\.l~nt Required) . ',,",' t:) lEndorsaltl aliVeI"}' Fee ciêrk: ~'1NPO o Restrict~~t Required) \J1 let'dorsS ~ \ postage & Fees $ .,-oW Medema Family Trust James D. & Millie Medema, Trustees p. O. Box 70109 Fairbanks, AK 99707-0109 ~8/10/04 Total Postage & Fees $ 4.42 08/10/04 Harold Kravik 3020 E. Main St., # E-44 Mesa, AZ 85213 ... ..-,-_......."'.- -_....- --. ~..-_.._---_...---..--_. ...-.......----..---........ ,r.J..rlJ..."ilJ.l.UlIbJ.r U1 m D""'..,,- II~'I ,., ., m ~;i'J..I"1I¡'j'¡""lljr.]jll"I¡(.]'.'jf-ilr'IIIII'''¡>liI-itþ''j''''''''''''"'f-i~I-i!'¡:.J''~ ~ I T~ii ¡¡ , .. I A ~:~ Sf: I ru Postage $ ~ð7f/·}jf(¡T ~D: '0502 '\. P-'!.liP J ;-;t6 Certified Fee .,' '", Postmark .~ ) Here '..;: .) / ~Yti~;MQP1NF'(í --..,~~ Return Reclept Fee (Endorsement Required) Restricted Delivery Fee (Endorsement Required) Total Postage & Fees $ ft¡ ~ P-.. Barbara Dimock 4093 220th Place S.E. Issaquah, W A 98027 08/10/04 .........----............---....-. ...........--..........-----. ~.bJ.....L;ulr..~llIu- I. . . os a . . , ., R I~D MAILTf~ REC~.PT. . ,-,,- II..' ".L" .., - . - ...- . .-. o ru ?"- m ~¡.]II.r:1I¡'ii]".III¡.J/II"\~['lla'/~itr.III."'¡i]'F-i!(~'" ....','..,'''''~i.F-'I!.¡.JI'~ ~ I p¡Qlf doC I A L r ~ 1 E I ru Postage $ 9$( /~~-~O~-{) . 8 Certified Fee ). ';!,~^ I ./q "< \ o ~~. ~ark o (End:~~~~eæ::::i~ / '(/.6\ ,~ Here o Restricted Delivery Fee \ Cle?f:: QPlNPO U1 (Endorsement Required)' ", ~' ~ Total Postage & Fees $ J{.~ ~,// ::r- o o I"- Jason M. Burgess 3346 E. Toronto Drive Phoenix, AZ 85044 .---.... -..--.-.. ----_..- ...............-------..-. 1.I.w.-t.liu....,.1.11 u.s. Postal ServiceTM CERTIFIED MAILM RECEIPT , . ". . ".' . I '..., ..," . - ... - . . '. - . ..lJ o ?"- m IT" ~;¡.]II'¡¡I¡'¡o""II'['J/II"'I['lla'JI.-il.'III"'''¡i]'F-il(~1."·"""'·""~i,&~'¡.II'~ ~I FQrAiEd9G71 A L 1 E I ru Postage $ ')~ T ID:}p502 M -.LJ <, o Certified Fee ~ iiD ~ : o '" ~.postmark o (Endo~=i~ /ì.."!f5 ~~o ,y Here o Restricted Delivery Fee . ~fd::,:, QPlNPO U1 (Endorsement Required) ~ ~ $ / ',r(. ('"of) 08/107ò4 Total Postage & Fees /' ~ ;;r O· o 1"-' William G. Stoecker PO Box 71230 Fairbanks, AK 99707 --------..-------.... ----------------. ,t_1.11J..'itilr...ir,1Ik u.s. Postal ServiceTM CERTIFIED MAILM RECEIPT , . ,,- . ".' . I "...., ..,..'. _ ..... . . .,.. Certified Fee Return Reciept Fee (Endorsement Required) o Restricted Delivery Fee U1 (Endorsement Required) ~ Total Postage & Fees $ ,4·4tL 08l10;~4 The Donald and Nola Dippel Trust Nola B. Sanders Trustee 359 Gean St. Mesquite, NY 89027 ;;r 01 01 I"- i ..........---...................---. ......-____..__......__...4 II'JIIII. J..'1 ~'" r-t. ì'1.)JJ.... ?"- m I"- · . " - .." - . , /. / m ~ 1¡·]II~Q:¡·~i¡T;~:·JII....¡i].F-il(~I·'·'··..·U~i·S·]I~ ru Postage $ p¡::¡- U~ 05()2~ M Certified Fee "".2" ~,~ )9 o ~~JKJV (~r ~.<$) § Return Reclept Fee I; ~r, ~(, "l:!eYè~cP (Endorsement Required) - 7'-0 . ."' - ~ (:n:r=e~W~~i~ Cle,,"~ QP1NPO 0 ~ Total Postage & Fees $ ~,.'f!! 08l~ j~<l. ::r- o o I"- Charles E. Cole 406 Cushman Street Fairbanks, AK 99701 ...-.....-..........-.......-.----. --....................------. ~.1.1.......'i'..J.¡Iooi~4 u.S. Postal ServiceTM ' . · lED MAILTM RECEIPT . . ,,- . ".' ., "i' I ..,. . . ,.' .. . .,O'. Certified Fee Return Reciept Fee (Endorsement Required) o Restricted DerlVery Fee U1 (Endorsement Required) m M Total Postage & Fees ~ Edgar Boyko Estate Georgie Lee Boyko Executor 3020 S. 5th Ave., Pocatello, Id. 83204 ::r- 0& o I"- 'Bi or .-..-----................... .......................--..... 'ëi -m ft'I..'"\iI.'("Ir.lJ.l-.~ u.S. Postal ServiceTM . lED MAILTM RECEIPT I~ . : '" ~ - O'._... . . . . 'i!~ 1'1 . . , i." . , . .. . o C'J o ~ r "":~"""'¡':'€,'i'~ï"A"l"":ïÇs'''M : Postage $ ~?J¡1- ~:, ~;2 :~ § CertifK!d Fee ;.. '1.~ (f I ~~ark \ o (End:r:~~éÅ:r~i~~ I ~:;¡"Ø\;~2}\ ,,<&y~ Herel, o Restricted Delivery Fee "C, t~",,~,:_9~'1NP~ U1 (Endorsement Required) J fi - ~ $ I I.J~l~ O~~> Total Postage & Fees -,-. ....." '~ ::r- o o I"- .Gregory C. Taylor, Esq. (representing Harry 1. HilI, Deceased) Jerrnain, Dunnigan & Owens 3000 A St., Suite 300 Anchorage, AK 99503 -......,-----..................... ...__.................____..__4 :af.I....J......UU,uI.l.! I. . . os a ervl· TM , ,. II~ III.~D., ~.A.IL, ;rM .R, E. C.E.IF... . . "... <tJ .JJ. ["- I11li.].,r,I\'I~".III'.]illl'\It.]I"'I!-ill.']IIIII'''I~.!-il(~\.'''''''''''"I!-i'!-'I!oi.]I~ - ~ Q t;. ç IACq~Jl JJ:S E I ~ ~I .. ,.n~~7~ " "~ï ~ '~~' - ~~: 0502 "'\ , ' . \ ,....:r A~í()/I~' \ D Certified Fee ,,, Ie! . .:/ , g Return Reciept Fee I; ~ :; ~~':'~'::rkØ! !!? . (Endorsement Required) ':ffV ~ _ D Restricted Delivery Fee C.·.l"~ QPINP(.1} ~ (Endorsement Required) .~. .' ' ,....:r $ t/--'i~ O~ Total Postage & Fees .::t" D D ["-" William Harry McDonald 6640 Jollipan Court Anchorage, AK 99506 ...---......----..--....... .----...-----------. t.I.."...."'t.UIlÜl.JJ,I u.s. Postal ServiceTM CERTIFIED MAILTM RECEIPT . ,.".' II.'., ',., .," . -....-, .... ru cO ["- ~ i·'·~Q;Ë;F¡£·rA"i..l:~'·'''·m·'''š'~ ~ Ii l!J-:1 , n: 0502 ,\ Postage $ 'i'r::¡ T 1"... V ~. ,....:r Certified Fee "1 ,., .Jl. D ~ . "~~ -'~ D 17"- iL.ViI Y "f""'U"~ g Return Reciept Fee /11:-5 \,?;:.. <~ Here (Endorsement Required) . "f ~ \" D RestrictedDetiveryFee 'k; QP11-J,.. 0 U1 (Endorsement Required) , I" ti' u ';:) ~ $ 4,r:tr'Y'- 08/10, iJ. Total Postage & Fees .::t" D D ["- " John K. Garvey Revocable Trust R,H. Garvey Bldg., Suite 1050 300 W. Douglas Ave. Wichita, KS 67202-2911 ..---.....---..-------. .---..--------...---. r.l.'IJ..;til[titl,.IÜ." u.s. Postal ServiceTM CERTIFIED MAllTM RECEIPT , . II" . """ ., "...., . I .. . .. ..... . . "... ::r .::t" ["- 111 ri.]..r,I\'I~".llj'.Jill"\¡[.]la'j!-iI4l'1111II'''I'¡.!--I(~la'...·........,!-i.!-'I!oi.]I'~ ~ Üd;),yliAi 'L ~J¡3A l JJ-S E I : Postage $ (¡,.jj~1/~ :~502h) D CertiliedFee ~'"? / "if c-..~ 1 D .::.. _ ' ~ark D Return Reciept Fee I i ~ ...... H (Endorsement Required) .J."'fl';i,J ~') ere C? I D RestrictedDeliveryFee Cletf: QP1N¡;~~ ' ~ (Endorsement Required) $ 4t//?- 08..)~ ~ Total Postage & Fees .::t" DSë D ["-"& or "ë¡, HV A Royalties Attention: Harold Van Amem 733 North Ocean Boulevard Delray Beach, FL 33483 ......................---... ..---......---..---. 1 IJd..i:4.tr-ti1e1JL" . -,. ., "TM ' C·ER h~ . M '_TM RECEIPT " ,.,,- . 11.'., ...., ., - . .. ...... .". ,...:¡ 111 D (¡ ~ j'·'··"'·"···""·:i;''i",·ol.¡,.''''." 'L:'.,':·..·'''·š·'M Postage :, \ çP ,....:rD Certified Fee 1\ .;.-J.n ì ,~'ö: ; ~;N ,1!Østm8lk ; g Return Reclept Fee I J""'$'" ".:§þ Here 0 (Endorsement Required) .,.; 'I.' " D Restricted Delivery Fee Cl~t~~J...1;!P1NF'O ': LIl (Endorsement Required) ',~ _ / n1 ~ 4.42 08/10/04 ,....:r Total Postace & Fees iD .::t" Cook Inlet Region, Inc. D Attention Kirk McGee, VP D ["- PO Box 93330 Anchorage, AK 99509-3330 .--.....-...........,................. ,.........--...................-... I.. lCel.rtl:iUUelU.J,1:' u.s. Postal Serv;ceT~ CERTIFIED MAllTM RECEIPr · . ".. " /1." ., ...., ..,,, ..... ... . . .... Certified Fee f128b / .1:/!f) Return Reciept Fee (Endorsement Required) D Restricted Delivery Fee U1 (Endorsement Required) 111 ,....:r Total Postage & Fees $ .::t" D-:! D ["- - ~ , '( Polaris Fund L. P. 400 Seaport Court, Suite 250 Redwood City, CA 94063 ....-..-....,..--....--..,... .---......-................. .. ¡ ,~.I·I..."t(.ìU....u.ük. u.s. Postal ServiceTM . lED · T"· ç IPT ..,,~ /I." .,. 1~~1l.; -'11- . .. ....... .... ,....:r U1 ["- 111 ~;¡.J..r,t\'.~".lli!.Jill"j¡!'JI"'jfl!C'IIIIll"'I.~~!-iH~I.'""""""I!--~J.'I!oi.]U~ ~ I wQTñA~,.ITC7LloA L USE I ~ ~-: $ ,,:!'! Ú+: i\I':~502 D t::fIC~ I, P~ D Return Raelept Fee ~ r", H (Endorsement Required) I. ; ......,,-,' ere D RestrictedDeliveryFee a:. ,.,~~ QP1N!....O U1 (Endorsement Required) _ ~. , n1 /y~ ./\) ,....:r $ Ll. ,IL,n .' ¥Ok Total Postage & Fees - r; rr-- . ." .::t" D D ["- Limestone Oil & Gas Company 4501 Nassau Wichita Falls, TX 76308 .......--.....-.......-......-.... .........-----......-...-....... IhJdhl.."it.IJ..iI.Ji,I-... ..D I'- ..D I.E} <~.. . -. . ..., ... CERTIFIED MAIL RECE' .. 0 . (Domestic Mail Only; No Insurance Coverage Provided) FAIRBANKS, AK 9~~07 Postage $ .0,1)- Certified Fee ). '!..J() Return Receipt Fee / 1~J:' (Endorsement Required) .1.'1 í.3) Restricted Delivery Fee (Endorsement Required) er- a ::r rrJ " " . . \ ! i tpostmark (/) j ,,\~. \ '.\ t:, Here !t j '\ :'0: "'; ci€'r'"k~QP1N· v 0/ ~/ ::r a a a a ,....::¡ U} Sen ru /Á¢1- 08/10/04 Total ÞO$:hIOA & Fees ~ "Biý Enea Tekna Investments Attn: Mathew Gavora PO Box 70021 Fairbanks, AK 99707 -------------- ----~--------- ,....::¡ "sire a orF a I'- a ;.111-..'1.11'1..4[-1,1;' u.s. Postal ServiceTM . . , '. CER~IFI~D MAILM . F 1fT . . " . " . . I ...." .., - . - ..... . . '." ...n I"- ...n fT\ IT"' I ~I ru ;¡.J..r;:¡II'I'¡".IIIí.]/II~IIT'JI.'lmt4l:.111"'''I,¡.!-it(~\.·''''1"IA'\: 'o!'Í.~" " , . AtQRÃ,E 19G31 L ; ~.,~">. I 4 {-/ ~ '~'\, Postage $ ("c , m:r ID: 0 ..:,,- \ I Luí '...:" 4 .?!Z.'" : 0\ ... ~. fA"I 'd.. . ,', \ N'" ~mark I .1 ~S ~.~Here Cl e'Fl:;:) f)PlNF'O ,...:¡ D D D Certified Fee , j ,:) i ':~ï" I .'v~: '/ Return Reciept Fee (Endorsement Required) D U1 Restricted Delivery Fee fT\ (Endorsement Required) ,...:¡ 4JkJ- 08/10/04 Total Postage & Fees $ =r D Sell D I"-'SbË orF 'ëii} William D. Renfro Estate 3940 Arctic Blvd., Suite 103 Anchorage, AK 99503 ..-------._-_... -----...-------. 11 I ih"it.iUti(t.J,1:' u.s. P~~täI ServiceTM ' CERTtt!ŒD MAlbM RECEIPT , . II 4 . ",' ., . 1..' 4 I 4 - . . ..' - . . .", ru ,...:¡ co fT\ ~.]...r;:¡II"'¡""'I\(.J/II!'\!t.1'.'I~i1t:.III"'I¡'¡.!-il(""1."1""""A'~i'!-'"!!'¡.11'~ ~I FQAiE,6< hG.)1 U;{)~.. I ru Postage $ 0/8 1-- u~~ '1K 0502 ~~ 8 CertilKKJ Fee /l?-.~O~!,,·" ~~ \ D~mark I j D (End=~~:~~ir~) /1·116 'í,~}'Here ; D Restricted Delivery Fee Clerk: .Qf'1NPO / ~ (Endorsement Required) ~.ff :L08/1Ò/01f ,...:¡ Tn'''' Pnstaoe & Fees S; =r_ D 5 D I"- '~ , 'ë Richard E. Wagner P. O. Box 60868 Fairbanks, AK 99706 ...-------------. ...--..---...------..... 'II à.. ~.""..-tI"'ÞÜÞli¡':- er- ..D -D U1 '. , . os a - . , - CERTIFIEr 1AIL RECEIPT ' (Domestic Mail Omy; No Insurance Coverage Provided) MERêfF: n~LANIi, WA 980i¡(J ~~1 ;) 3.ft> I¡~ er- a ::r rrJ Postage $ Certified Fee ::r a a a Return Receipt Fee (Endorsement Required) Restricted Delivery Fee (Endorsement Required) Total postage & Fees _ $ I/. ~ 08/10/04 a ,....::¡ U1 - ru .--_. ----_..----~--- r-=I a a I'- Lab Properties Inc. 5919 77th Avenue SE Mercer Island, W A 98040 .- ----_.._-~.._..---_. ø:~r.IIIII.¡..;U1lr'"iliill' u,s. P.R~t~l.servjceTM CE~ft~IE'D MAILTM RÉCEIPT , . ". . ",' . '!' I .. I .. . .. ~... . . '", IT"' ru ~ ~ ~ ii·]~~~;li~/,Hï~~~·ïl..Äþii~\··..'·"U~iS·],~ ru Postage $ o,a1 UNIT Ip: 1)~J~L9 9?:",- M (, ,',j \'- ~ Return::::: tJ.z1f; /i~~)~\ \ D (Endorsement Required) I ¡ ~ ' uJ \ Here',~';)," (j) 'TaV \ <..?\"- il ~ (lfnd=~e~f~~i~ Clert,;r;.QF'lNF'iÏ , ~~ ,...:¡ Total Postage & Fees $ J.f¡,,'fY- 08/10~4 '=7 ~ D~ D I"- ' 1 j SPC LLC Attn: K. Battley Managing 500 L Street, Suite 302 Anchorage, AK 99501 ~1.rt"";...I...¡...1ä.. .....-.--....-.............-. .---.....-..--.....---... . - U.S. ~~Å~ervjceTM ð'EÂTÎFU:I> II · · ECEIPT. · . ". . 'j ~. ,., 'JII! .~ Ii;, ..' . - ... . . ".~. Ul D E:() fT\ Ir' 1·;t·l..r;:¡~~,I~~~·'·C·]/¥~:'=~¡¡[t~,Y"'",~r.1~1.'''¡'¡~J-it('''\.'''''''''''AI~i~Þ'"!!'Í·J1E,', ~" I"- t:'A'Ì'-t.;>1ID,·, .-'( ;;q~&'7 ill ,m U1 ' .' - ..11I\;J" "m .' .' 't-t.. ~ . ru Postage $ O;-ß:¡' ~f1I: 05Q2 g __::: ~'!!1.t!"-,.~~ D (Endorsement Required) l¡.w!~ / ~- flere ('" \ D Restñcted Delivery Fee ': '\~,\clef"',r" QPHlpr1 :/) } ~ (:::~::::~::::~ S; 441Ft~~~04" v . ::r >~~-~ D Se, D I"- '56 or 'ëñ James L. Thurman & Leta Thurman 925 Aurora Drive Fairbanks, AK 99707 ----------.....--. -......-...----..---. ~ Jld......U..Utotl[t].J..... .. . "!. -, - TM CER .'~ . . MAILM RE '::IPT , . " . J.. , . i.. I . I . . - .. - . . ., - , . rú ::r IT" m ~ ~"''';Q''&¡;;:¡''ë'¡;¡~'i:'''''lj'Š'''M : Postage $ ¡5rf LlNIT;P: 0502 '-~ g Certified Fee "2:~ 1> (!{../.'..~... . ~]'~ ,.~' o Retum Reciept Fee I""=:...-- () Postmark . ~ (Endorsement Required) J. ~ ~ , <:t... Here JJ ~ Restricted Delivery Fee Cler~.F\þ..~·..Q.\f'1NPO ß/rtCi) m (Endorsement Required) '1\ '. . -;- r-'I Total Postage & Fees $ LJ,~08í10!Ò4.~ \) ::r o o £'- Mary H. Hale 3157 D Road Grand Junction, CO .. .....",- - ..,.......- ...................... ...........-......-..........-.... glSoy..- ~1'2il 1t·)·I.J..;tlll.(-tI'.)~", m cO ...n ,.,,- u..·' ,., ~ ~~.]lG·~;;~lIël"·'·ç"~':~·i·A"L'·,·,,·;·tš·"M Lf"I, ):m1~ù@.:1,. AR ~:tm .~~ ru Postage $ r¡¡.j 1/ ~ 11: 05\,~ r-'I ' ,. I~ '. o Certified Fee ~ "')~!n{ ~'(j' \ g (End:r:~'::~~:¡::lf~i J .~;fð'· \" /~.~.~:rk)æ o RestrictedDeliveryFee .C,~.~:J1.P.~ Lf"I (Endorsement Required) Ÿ:) . ~ $ ßI.¿'),~~~ Total postage & Fees ~ ~ ::r o ' Sent '. o £'- -Siriié or PC -ëitÿ;: Robert L & Deanna Persons PO Box 403 Girdwood, AK 99587 III!I -. u.s. Postal ServiceTM CERTIFIED MAILTM RECEIPT , . ,,_ . ".' ., . i.' ..,.. . - ...' - . , 0, - , Retum Reclept Fee (Endorsement Required) o Restricted Delivery Fee Lf"I (Endorsement Required) m r-'I -.......~., ,- It tt {jg;,J- 08/10/04 Total Postage & Fees $ ::r oSëi o £'-°Siiì or -ëïtj John_ M. Robinson 9333 Memorial Drive Suite 203 Houston, TX 77024 ..........~..................... .................---....-. ....'1W.loi~ JI .. .. . CERTIFr ') MAl LTM RECEIPT , . ,,- . 1'1. ., 0 i..' ., - . . ø'· . . ., - , IT" IT" £'- m IT" ~;-.]...['II¡'l~ '·.III¡·]jlll'l¡¡·JI"·H-il..II"'''¡~·¡'il('''I.'''''''''''IlI¡'j~¡'"!I'¡'JI'~ ~I sAQfi'7~IAL USE I ru Postage $ 0.;:,'51 UNIT ID: 0502 r-'I g Certified Fee ~~.¡() o Retum Reclept Fee 4/ frI Postmark (Endorsement Required) /1, ?!i <1& Il1re . o Restricted Delivery Fee Cl L ~~ Lf"I (Endorsement Required) er.::: . PH"",', :t ~ $ , I lf~" ~,~ ~fòro Total postage & Fees ,It :lL" 0 (pf. ::r o o £'- Carolyn L. Shogrin PO Box 29450 Santa Fe, NM 87592-9450 ,..<Þ............<Þ............_.....,... ............-..............-.......... r .... "_ . _: ... June 2002 _ . - "'.,. - -. - - U.S..p-.~~~e~~fL:M RECEIPT æ. " . JJ ..' ., . i·' #, - . .. .... . . ., - , £'- r-'I o ::r ~ r";ø¡'¡¡;ë"ï7~'''l;¡;Š';M Postage $ ,('84-/ ~ ,050?; 8 Certified Fee ~ ...2.n í' " . _ø.~~:,ð> o 0"- .~ ~\:= \ o Retum Reclept Fee tIzr- ...,~ark i (Endorsement Required) ) .1~ ,S)'" Here /;? ~ (rndsg:~~f~~~i~i clèrk: QP1NP6~ m ~ ,/ r-'I Total Postage & Fees $ l/:~8Î~'-' /" ::r o o £'- Kreielsheimer Foundation (representing Leo T_ Kreielsheimer, Deceased) 10 Harrison St., #302 Seattle, WA ~' q)f/tJí .......................................-,.. ~...................................._- k,,·b.L"i.Ü'lltt.ttd.i1.:; _........,.....,.._..,·_,...._'·'·7'..-".., u.s. Postal ServiceTM CERTIFIED MAllrM RECEIPT , . ,,- . JI _. ., ".t.., ., - . - ..... . . ',., ...D m cO m ~ r··'·:""''"·i:in'~'''~··ï..¡i:'·''·''''ijß1M : Postage $ vði1 !JÑJT'~ í§2~ \ g ~:;; ~~ .;:)jJ$' o Restricted Delivery Fee Cle....L:-.·~~'1N,p" _ Lf"I (Endorsement Required)' "tlr , _ ~ Total Postage & Fees $ 1f'4«f¡-.- 08/10/04 ::r _ o $e, o £'--~ or -ëi. Jack H. & Helen E. Richardson 3511 A Andree' Drive Anchorage, AK 99517 ......-......................... -.................-............ I ·1.1."til..u."'iI")ñ..~ e e I:() ru a- rn ~ 1¡·]·,r;JI¡'/~"."¡¡.]jllr.I¡[I'Il'/~ill"·ïl·Aitl'~':¡-i.t.'f['¡.]IË I ~ c,...,,"":' ;:;:(~,C/ ... Or' " Postmark o Re\UmRecieptFee 1."1..C <;:"" : Here (Endorsement Required) ,.. ~ V', , " o Restñcted Delivery Fee ,.J ì:;- ."/ ~ (Endorsement Required) $ J I.LI 2- '~T Total Postaae & Fees Mary T. Brooks 415 Flat Top Sheep Ranch Carey, Id JJJ2'O 13320 u.s. Postal Sen'ceTM . lED ~ILTM RECEIPT , . " - 'J ... . I ..., .., - . . .., - . . '.,. .:T 01 o 1"-1 --..,.......-...---...---.... ï ....-----------........ I .... IJIIII.J,."1UUtUl.Jak :~ e e TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Alaska Oil and Gas Conservation Commission In the Matter of the Application of Forest Oil Corporation for a well spacing exemption And exception to the provisions pertaining to Drilling Units and Well Spacing pursuant to 20 AAC 25.055 ) ) ) ) ) ) ) VERIFICATION OF FACTS AND AFFIDAVIT OF JIM ARLINGTON Jim Arlington, being first duly sworn, upon oath, deposes and states as follows: 1. My name is JIM ARLINGTON. I am over 21 years old and have personal knowledge of the matters set forth herein. 2. I am the Land Manager for the operator, Forest Oil Corporation (Forest). 3. I am knowledgeable and fully informed concerning the facts associated with the application of Forest Oil Corporation for a well spacing exemption and exception to the provisions pertaining to drilling units and well spacing pursuant to 20 AAC 25.055 as they pertain to the proposed drilling of the West Foreland #2 gas well ("WF #2"). 4. I have assisted in preparing and did submit to the Alaska Oil and Gas Conservation Commission ("AOGCC") on behalf of Forest Oil Corporation the completed application requesting an exemption from the provisions of 20 AAC 25.055 for the drilling of the West Foreland #2 gas well in the West Foreland Field and hereby assert that all the facts contained therein are true to the best of my knowledge. 5. I have prepared, at the direction of the AOGCC, a personal notice of the public hearing scheduled to be held at 9:00 am on August 26, 2004 by the AOGCC concerning Forest's application for a well spacing exemption for the WF #2 which also contains Forest's drilling plans and proposal for allocation of production from said well. 6. I assert that I supervised the preparation of two separate lists of royalty owners known by Forest as of August 10,2004; one list for federal lease A-035017 and one list for State of Alaska lease ADL-359112, both of which are attached hereto. 7. On or about August 10, 2004, I caused a copy of the attached personal notice regarding Forest's application for an exemption from the provisions of 20 AAC 25.055 for the WF #2 to be to be mailed via United States certified mail to the names of all royalty owners contained on the two lists attached to this affidavit. I further assert that a copy of said notice, both lists and proof of mailing each personal notice to all parties on both lists was also mailed by United States certified mail to the AOGCC on or about the same date. Subscribed and sworn to on August 10, 2004. ~~imArlinglOn STATE OF ALASKA ) ) ss. THIRD JUDICIAL DIS1RICT ) ....{... On this /Oday of August 2004, before me, the undersigned, a Notary Public duly commissioned and sworn, appeared Jim Arlington, personally known to me, to be the person whose name is subscribed to within the Verification of Facts and Affidavit. \\\\\\11"'1/11:1 ,\\ ,.HO"'~ c'-' ~~ · · *"!4If ~ .$ V· "'A ....4' ~ :::::t¡¡.~r r. ~ :: ct· 0 ; 0 · .c(~ -::t:. ~ .~- ::: c.>.~; " · C'1,):: ~ ...-: . P, ,e'" · v:::::- ~ .. cu. .;;I_.~ ~ . . . . . ~ '~ ~I/ 81'ATE 0 ~~ II/J"",,,\\\\~ Witness my hand and official seal. ~~ Notary Public, State of Alaska My Commission Expires: /0-' - ':> y RE: Further Questions On the Forest APD . . Subject: RE: Further Questions On the Forest APD From: Bill Penrose <bill@fairweather.com> Date: Mon, 09 Aug 200409:35:29 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> CC: RLSmith@forestoi1.com Tom, Thanks for the correction on the disposal well designation. On the casing pressure tests, the APD package you received should have contained a Casing Pressure Test page (the one right after the MASP calculations) that indicates casing test pressures of 2300 psi for the surface casing and 3800 psi for the production string. Hopefully this is what you need. Also, Roy Smith and I are aware and agree that the BOP test pressure will be 5,000 psi and that the test interval will be 7 days. I'm still working on getting a description of the 3-ram stack to submit. I anticipate that'll happen in the next few days. Regards, Bill -----Original Message----- From: Thomas Maunder [mailto:tom maun~~~@admin.state.ak.us] Sent: Tuesday, August 03, 2004 2:27 PM To: Bill Penrose Subject: Re: Further Questions On the Forest APD Bill, I have returned to examining the WF #2 permit application. Just one small note in your response, the disposal well is West McRU #4. There are a lot of calculation sheets regarding the casing pressure tests, but no pressure value (that I could find) is ever given. What are the planned casing pressure tests?? As we spoke, 5000 psi will be the initial pressure test due to the rig move. What pressure is Forest proposing on subsequent tests?? Also, at this time it is likely that the BOP test interval would be 7 days. Call with any questions. Tom Thomas Maunder wrote: Bill, Thanks for your response to my questions. Further to our discussion on number of rams, I have looked at permit applications for wells similar to WF #2 using your planned rig. With similar calculated MASPs the stack was equipped with 3 rams (blind and 2 pipe) . You should examine the assessment/decision regarding 2 rams versus 3. Also, casing rams are required when running casing. Forest plans to run a string of 7 " and 7-5/8". How is it proposed to provide the ram coverage?? Tom Maunder, PE 10f3 8/31/2004 11 :57 AM RE: Further Questions On the Forest APD . . AOGCC Bill Penrose wrote: Tom, The answers to your questions are written below each of the questions you submitted... 1. What are the hole sizes and casing sizes?? There are at least 3 different combinations presented. On the 401 sheet surface combination is 17-1/2" and 13-3/8", this works. Production casing looks like a combination of 7-5/8" and 7" in 9-7/8" hole. This works too. In the Baker Hughes directional work, they list 14-3/4" hole and 10-3/4" casing. In the MI paperwork, they show 17-1/2" hole and 10-3/4" casing. All combinations work, but are not consistent. Answer: Use the casing and hole sizes indicated on the 401 and supporting data sheets. The directional work and mud program were done while those parameters hadn't been set yet but are still valid even though the hole and casing sizes have changed. 2. Would you please include the cement slurry/volume information. Answer: The requested information is attached. Note that the volume calculated for the 7" string is calculated on it being set in an 8-1/2" hole. The cement formulation is valid, but the cement volume shown on the 401 should be used as it's been modified to the planned 9-7/8" hole. 3. How will drilling waste be handled?? I presume they will use what disposal wells and "pit" they have over there, but we do need a "statement" as to what is planned. Answer: Waste mud will be injected down the RU #4 disposal well while the cuttings will be placed in the permitted DWMA cells located nearby. 4. It appears that logs are only planned for the production hole, although the logging sheet really isn't clear. Is run 1 at TD?? How high does Forest intend to have the tools "on"?? Answer: There's only one logging run planned for WF #2 and it'll be when the well reaches TD. We're in the process of looking to see if the WF #1 has logs to surface. Having been drilled in 1961, it's doubtful. If there is no WF #1 log to surface, then the logging run in WF #2 will log the entire suite from TD to the surface casing shoe, then continue logging out to surface with only the gamma rayon. 5. What is the proximity to WF #1?? Do you have a traveling cylinder plot?? Answer: At the surface, the wells are 40' apart. However, WF #1 only had single shot surveys run when it was drilled in 1961 which indicated no great inclination control. Forest Oil is in the process arranging for a directional survey to be run in WF #1 after which a proximity plot/traveling cylinder will be generated and the WF #2 directional program adjusted, if necessary, to bump the new we 1 1 bore 20f3 8/31/2004 11 :57 AM RE: Further Questions On the Forest APD . . a safe distance away from WF #1. Please let me know if you need additional information. Regards, Bill 30f3 8/31/2004 11 :57 AM . . 267'~ 1'-13 t~L/ þ,-J~ "2- Contact Record Contact Art Saltmarsh PTD / Project No. 2-d/- /7"3 Category Information Request Sub.iect Mud log requirements Date 7/26/2004 Start Time 9:04:03 AM End Time 9:25:46 AM Description West Foreland 2: twin of WF1, but WF 1 was drilled in 1961 and has no mudlog. Tell him they will need to record one beginning at base of conductor. Notes 1.5 miles from west mcArthur River field. No shallow gas there. Tell him still. need log from base of conductor down. Telephone Email 868-2141 Å --c.... TU~¿::''' 31,1004 Page I of I .... . . @ FOREST OIL CORPORATION .J 1 0 dYC cfl&øøt - 99':u;w. 700 Q9tru:~a!løj Qxf/aJka !l9501 (907) 2,'i8-8600 · (907) 2,'i8-86Of (~x) August 30, 2004 RECEIVED AUG 3 02004 Alaska Oil & Gas Cons. Commission Anchorage Mr. John Nonnan, Chair Alaska Oil and Gas Conservation Commission 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 RE: Modified Application for Pennit to Drill: West Foreland #2 Dear Mr. Nonnan, Per the request of Mr. Tom Maunder, please find enclosed a modified Fonn 10-401 which indicates revised surface and bottom hole locations for the subject well. The modified locations result from a new as-built survey of the West Forelands Pad and its attendant facilities. In addition, the approximate spud date of the WF #2 has been changed to September 10,2004. If you have any questions or require additional infonnation, please contact Roy Smith at (303) 864-6159 or Bill Penrose at 258-3446. sincerelY,... /). .,.' / ð ~",A AVo. /i:;/¿' 7e<l ~¿;íl.øn ei~ _ Ted Kramer Alaska Production Manager enclosure · STATE OF ALASKA . ALASKA Oil AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 11 b. Current Well Class: Exploratory U Development Oil U Multiple Zone [2] Stratigraphic Test D Service D Development Gas [2] Single Zone D 5. Bond: Blanket [2] Single Well U 11, Well Name and Number: Bond No. RLB0001940 ($200,000) WF #2 6. Proposed Depth: 12. Field/Pool(s): MD: 10,649' TVD: 9,445' 7. Property Designation: A-035017 (surface) & ADL-359112 8. Land Use Permit: 13. Approximate Spud Date: Salamatof Native Association, Inc. Sept. 10,2004 9. Acres in Property: 14. Distance to Nearest ADL-359112 = 2,155 acres Property: -293' @ 9,400' 10. KB Elevation 15. Distance to Nearest Well (Height above GL): 25 feet Within Pool: -2,SSO' @ 9,400' 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4,224 psi Surface: 3,311 psi Setting Depth Quantity of Cement c.f.orsacks 1 a. Type of Work: Drill [2] Redrill D Re-entry D 2. Operator Name: Forest Oil Corporation 3. Address: 310 K Street, Suite 700, Anchorage, Alaska 99501 4a. Location of Well (Governmental Section): Surface: SS6' FSL, 571' FEL, Sec. 21, TSN, R14W, SM Top of Productive Horizon: 9,150' TVDss; 10,351' MD @ 9,400' Sand Total Depth: 1354' FNL, 1139' FEL, Sec. 21, TaN, R14W, SM 4b. Location of Well (State Base Plane Coordinates): Surface:x- 190452 y- 2475582 Zone- 16. Deviated wells: Kickoff depth: 5,305 Maximum Hole Angle: 47 AK-4 feet degrees 18. Casing Program: Size Casing 20" 13-3/S" 7 -5/S" Specifications Hole )-<6/5 \ West Foreland Top Bottom MD TVD 145' 145' 3,000' 3000' 3,000' 3000' 10,649 9,445 (including stage data) Driven 3416 cu ft lead, 762 cu ft tail NIA 1206 cu ft Class G Weight Condo 61# 29.7# 29# Grade Coupling Length MD TVD 120' 25' 25' J-55 BTC 2,975' 25' 25' P-110 Hydril521 2,975' 25' 25' N-SO LTC 7,649' 3,000' 3,000' 17-1/2" 9-7/S" 9-7/S" 7" 19. Total Depth MD (ft): PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Structural Conductor Surface Intermediate Production Liner Length Size Perforation Depth MD (ft): Cement Volume MD TVD Perforation Depth ND (ft): Time v. Depth Plot U Shallow Hazard Analysis L1 Drilling Fluid Program [2] 20 AAC 25.050 requirements D Date Contact Filing Fee ~ BOP Sketch ~ Property Plat D Diverter Sketch [2] 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature a4-~ ßg /Õ~ ~d N,;<.""è~ Phone (907) S6S-2137 Date --- Commission Use Only Permit to Drill IAPI Number: . . permit Approval I J0 / / see .co.. ver letter for other Number: dO\"'\ - \ 4 ~ 50- p;!> - JOS L{'ð - OÙ Date: q / / 0 '-1 requirements. Conditions of approval: Samples required Yes D No ~ Mud log required Yes .if No D Hydrogen de measures Yes D No ~ Directional survey required Yes '~NO D Other: 5000 Ç>";\.\~'\\" '? ~"".)~ . 1¡ ~ '-\00 . r-" ~C),,~~s-\\~~r"t\ ~ \ CJG'(> BY ORDER OF Approved by: . THE COMMISSION 20. Attachments: Printed Name Ted Kramer Drilling Program ~ Seabed Report D Title Alaska Production Manager Date: rj~ v ORIGINAL Submit inDuplicate @ July 29,2004 . . FOREST OIL CORPORATION .'110 dYC 032Jr-eer. cfl:ÆÆW 700 QS2tnckJr.{;{;!1<:' Qxfla6ka~ c9.9501 (907) 2,)8-86'00 · (907) 258-86'01 (ŒØa.r) Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Drill: West Foreland #2 Dear Mr. Norman, Forest Oil Corporation hereby applies for a Permit to Drill an onshore development gas production well, the West Foreland #2, in the West Foreland Field on the west side of Cook Inlet. A surface use agreement exists with the Salamatof Native Association, Inc. ,/ for this work. The anticipated spud date of the WF #2 is approximately September 1,2004. ./ The well will be drilled from the existing West Foreland pad, immediately adjacent to the West Foreland #1 well. After driving a 20" conductor, a 17-1/2" hole will be drilled to 3,000'MD/TVD where 13-3/8" surface casing will be set and cemented to surface. A 9- 7/8" hole will then be directionally drilled to 10,649'MD/9,445'TVD and 7" production ./ casing will be set and cemented after which a dual 2-3/8" gas production completion will be installed. - Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) 2) 3) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). Fee of$100.00 payable to the State of Alaska per 20 AAC 25.005 (c) (1). A directional plat showing the well's proposed surface and bottomhole locations per 20 AAC 25.050 (c) (2). Directional plots and proximity calculations in accordance with the requirements of20 AAC 25.050. Diagrams and descriptions of the diverter and BOP equipment to be used as required by 20 AAC 25.035 (a)(I) and (b). A complete proposed casing program is attached as per 20 AAC 25.030. The drilling fluid program, in addition to the requirements of 20 AAC 25.033 are attached. A copy of the proposed drilling program is attached. Forest Oil does not anticipate the presence of H2S in the formation to be / encountered in this well. However, H2S monitoring equipment will be functioning on the rig at all times during drilling and completion operations. Since this well is a deðm~ l~ Ã rd logging will be performed. 4) 5) 6) 7) 8) 9) 10) . . Mr. John Norman Page 2 11) A Summary of Drilling Hazards is attached. 12) The following are the designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) Roy Smith, Alaska Drilling Manager (303) 864-6159 2) Geologic Data and Logs (20 AAC 25.071) Art Saltmarsh, Geologist 868-2141 If you have any questions or require additional information, please contact Roy Smith at (303) 864-6159 or Bill Penrose at 258-3446. Sincerely, FOREST OIL CORPORATION -d ~/7~ Ted Kramer Alaska Production Manager enclosures nD'G !~L_ 1 a. Type of Work: 2. Operator Name: . STATE OF ALASKA .. . SKA OIL AND GAS CONSERVATION C~ISSION PERMIT TO DRILL 20 AAC 25.005 11 b, Current Well Class: Exploratory U Development Oil Stratigraphic Test D Service D Development Gas 5, Bond: Blanket [] Single Well D Bond No. RLB0001940 ($200,000) 6. Proposed Depth: MD: 10,649' / 7. Property Designation: A-035017 (surface) & ADL-359112 8. Land Use Permit: 13. Approximate Spud Date: Salamatof Native Association nc. I Sept. 1, 2004 9. Acres in Property: 14. Distance to Nearest ADL-359112 = 2,155 Property: -293' @ 9,400' 10. KB Elevation 15. Distance to Nearest Well (Height above GL): 25 feet Within Pool: -2,SSO' @ 9,400' feet / 17, Maximum Anticipated essures in psig (see 20 AAC 25.035) degrees' Downhole: 4,2 psi'¡ Surface: 3,311 psi Se g Depth Quantity of Cement c.f.orsacks Drill l..::J Redrill U Re-entry D Forest Oil Corporation 3. Address: 310 K Street, Suite 700, Anchorage, Alaska 99501 4a. Location of Well (GovernmentaIgection): Surface: ,¡ SSO' FSL, 631' FEL, Sec. 21, TSN, R14W, SM .I Top of Productive Horizon: 9,150' TVDss; 10,351' MD @ 9,400' Sand Total Depth: 1365' FNL, 1105' FEL, Sec. 21, TSN, R14W, SM 4b. Location of Well (State Base Plane Coordinates): / Surface:x- 190391 y- 2475578 Zone- 16. Deviated wells: Kickoff depth: 5,305 Maximum Hole Angle: 47 18. Casing Program: Size Casing 20" Hole 17-1/2" 9·7/S" 9-7/S" 13-3/S" 7 -5/S" 19. Total Depth MD (ft): Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Specifications Top Bottom MD 145' 3,000' 3,000' 10,649 7" Weight Condo 61# 29.7# 29# D 25' ~' ..z_f.ø ~,OOO' Grade Coupling J-55 BTC P-110 Hydril521 N-SO LTC Length TVD: 9,445' v D M pie Zone [] [] Ingle Zone D me and Number: West Foreland (including stage data) Driven ../ 3416 cu ft lead, 762 cu ft tail NIA ./ 1206 cu ft Class G Junk (measured): MD TVD TVD 145' 3000' 3000' 9,445 Filing Fee L:J BOP Sketch L:J Property Plat Diverter Sketch [] 21. Verbal Approval: Commission Re esentative: 22. I hereby certify that the foregoin IS true and correct to the best of my knowledge. Drilling Program L:J Seabed Report D Perforation Depth TVD (ft): Time v. Depth Plot U Shallow Hazard Analysis LJ Drilling Fluid Program [] 20 AAC 25.050 requirements D Date Contact 20. Attachments: Printed Name Ted Kramer Title Alaska Production Manager Signature ~ Phone (907) S6S-2137 Commission Use Only .-///3 IAPI Number: . _ .. LI. I Permit Approval Number: 7, 50- 1.::53 2D5'72-c:x:J Date: Conditions of appr al: Other: Samples required Hydrogen sulfide measures D No D D Nog Mud log required Directional survey required Yes Yes BY ORDER OF o :< t G 1 NT" EMMISSION Form 10-401 Revised 12/2003 Date: Date 1/2-Ø c¡ I See cover letter for other requirements. Yes D Yes 1Ç No No D D Submit inDuplicate . . CASING DESIGN WORKSHEET: DRILLING CASING FIELD: #REF! LEASE: West Foreland WELL: 2 (WHEN CSG SET): CASING SIZE: MUD WEIGHT: 13.375 in. 9.3 ppg SHOE DEPTH: 3000 rvD J 3000 MD / 1) GAS GRADIENT {NAGYIYOUNG CORRELATION} (0.161 · S. G.) + (0.0032 · pore pressure) - (260/ (depth {tvd}» Note: Depth = tvd of next casing point (AT NEXT SHOE): Gas specific gravity = Mudweight = Formation Pressure = Depth = Gas Gradient = 0.60 9.6 8.6 9445 0.0966 S. G. (AT NEXT SHOE) ppg (AT NEXT SHOE) (ENTRY IS CARRIED OVER FROM INPUT ON PROD SHEET CELL 87) ppg (AT NEXT SHOE) tvd (AT NEXT SHOE) (ENTRY IS CARRIED OVER FROM INPUT ON PROD SHEET CELL E6) psilft 2) MASP CALCULATIONS USED FOR BURST CONSIDERATIONS A) MASP 1 = Pore Pressure - 2/3 weight of gas column - 1/3 weight of column of mud Pore Pressure = 4224 psig Shoe Pressure = 3601 psig MASP 1 = 2045 psig B) Shoe fracture pressure - weight of gas column {for shoe breakdown} Fracture Gradient = F.G. Safety Factor = Formation Backup = Fracture Pressure = MASP 2 = 12.40 ppg (AT THIS CSG SHOE) {using Matthews & Kelly or Eaton Chart} 1.00 ppg (ATTHISCSG SHOE) {to insure shoe breakdown} 9.00 ppg (ATTHISCSG SHOE) {for burst backup - suggest native fluid @ 9 ppgJ 2090 psig 1801 psig 1o1o1o MASP USED IS THE LESSOR OF MASP 1 AND MASP 2 1o** MASP = 1801 psig C) Burst load at casing shoe = MASP + Hydrostatic pressure to shoe - backup pressure Shoe Burst Load = 686 psig 3) COLLAPSE LOAD = DUAL FLUID HYDROSTATIC (i.e. cement behind pipe) w/8.6 ppg SW for BACKUP Lead Cement Density = 11.40 ppg Tail Cement Density = 15.80 ppg Collapse = 665 psi (ASSUMES 2/3 LENGTH IS LEAD CEMENT AND 1/3 IS TAIL - NEITHER SETS UP) 4) TENSILE LOAD Casing Weights Considered: A) 61.00 #/ft Load = 156,977 Ibs B) 61.00 #/ft Load = 156,977 Ibs 5) DESIGN LOADS A)Burst Loads Shoe Design Burst (Shoe Burst Load * 1. 755 psig Surface Desig n Burst (MASP · 1.1) = 1981 psig B) Design Collapse (Collapse· 1.1) = 732 psig C) Tension, Body = Tensile Load" 1.5 A) 61.00 #/ft Load = 235,466 Ibs B) 61,00 #/ft Load = 235,466 Ibs . . D) Tension, Joint = Tensile Load * 1,8 A) 61,00 #/ft B) 61.00 #/ft Load = Load = 282,559 Ibs 282,559 Ibs CASING DESIGN WORKSHEET: DRILLING CASING FIELD: #REF! LEASE: West Foreland WELL: 2 CASING SIZE: MUD WEIGHT: 13.375 in. 9.3 ppg SHOE DEPTH: 3000 TVD 3000 MD 6) DESIGN LOADS VS. RATING Note: Safety Factor (SF) = Rating IActual Case A WEIGHT: GRADE: THREAD: 61.00 #/ft J-55 BTC ACTUAL DESIGN RATING S.F. FOREST REQ'D SF -------------- -------------- ------------------------- ---------- -------------- -------------- ------------------------- ---------- BURST 1801 1981 3090 1.72 1.2 COLLAPSE 665 732 1560 2.34 1.1 TENSION,BODY 156977 235,466 962,000 6.13 1.5 TENSION,JOINT 156977 282,559 1,025,000 6.53 1.8 Case B WEIGHT: 61.00 #/ft GRADE: J-55 THREAD: BTC FOREST ACTUAL DESIGN RATING S.F. REQ'D SF -------------- -------------- --------------- ---------- ---------- -------------- -------------- ------------------------- ---------- BURST COLLAPSE TENSION,BODY TENSION,JOINT 1801 665 156977 156977 1981 3090 1.72 1.2 732 1560 2.34 1.1 235,466 962,000 6.13 1.5 282,559 1,025,000 6.53 1.8 2 If Case A enter 1, if Case Benter 2 Date: 06-Jul-Q4 . . CASING DESIGN WORKSHEET: PRODUCTION CASING FIELD: #REF! LEASE: West Foreland WELL: 2 (WHEN CSG SET): CASING SIZE: MUD WEIGHT: 7,000 in. 9.3 ppg SHOE DEPTH: 9445 TVD 10649 MD 1) GAS GRADIENT {NAGYIYOUNG CORRELATION} (0.161 * S. G,) + (0.0032 * pore pressure) - (260 I (depth {tvd})) Note: Depth = tvd of next casing point (AT NEXT SHOE): Gas Specific Gravity = Mudweight = Formation Pressure = Depth = Fracture Gradient = Gas Gradient = 0.60 S.G. (AT NEXT SHOE) 0.0 ppg (AT NEXT SHOE) (ENTRY IS CARRIED OVER FROM INPUT ON LlNER1 SHEET CELL 87) 8.6 ppg (AT NEXT SHOE OR HERE IF td) 9445 tvd (AT NEXT SHOE) (ENTRY IS CARRIED OVER FROM INPUT ON LI~':ER1 SHEET CELL ES) 16.40 ppg (ATTHISCSGSHOE) 0.0966 psilft 2) MASP CALCULATIONS USED FOR BURST CONSIDERATIONS A) Pore Pressure - weight of gas column Pore Pressure = Shoe Pressure = Including GG MASP = 4224 4224 3311 3311 psi (AT TD, SINCE PROD CSG Will SEE MASP FROM TD FOR A LINER CSG PlAN) psig / psig 01 vi B) Burst Load at casing shoe = MASP +(packer fluid-backup)(.052)(TVD) Back-up = 9 ppg (suggest 9 ppg for Max Load, or else use actual formation pres~ Packer Fluid weight = 9 ppg (higher packer fluid weights cause higher loads) Burst Load = 3311 psig 3) COLLAPSE LOAD = DUAL FLUID HYDROSTATIC (i.e. cement behind pipe under mud) WITH NO BACKUP Cement Density = 16.40 ppg (assumes single density tail cement - worst case) Estimated Cement Top = 6800 tvd For au »>>>>>> 9 MW or form p~ Collapse = 1124 psi 4) TENSILE LOAD Casing Weights Considered: A) B) 33.70 #/ft 29.70 #/ft Load = Load = 307,839 Ibs 271,300 Ibs 5) DESIGN LOADS A) Burst Loads Shoe Design Burst (Shoe Burst Load * 1.2) = Surface Design Burst (MASP * 1.2) = 3974 psig 3974 psig 1236 psig Load = 461,759 Ibs Load = 406,951 Ibs Load = 554,110 Ibs Load = 488,341 Ibs B) Design Collapse (Collapse * 1.1) = C) Tension, Body = Tensile Load · 1.5 A) 33.70 #/ft B) 29.70 #/ft D) Tension, Joint = Tensile Load · 1.8 A) 33.70 #/ft B) 29.70 #/ft · . CASING DESIGN WORKSHEET: FIELD: #REF! LEASE: West Foreland WELL: 2 CASING SIZE: MUD WEIGHT: 7.000 in. 9.3 ppg 6) DESIGN LOADS VS. RATINGS Note: Safety Factor (SF) = Rating I Actual Case A WEIGHT: GRADE: THREAD: 29.00 #/ft N-80 LTC ACTUAL DESIGN -------------- ------------- -------------- ----------- ---------- -------------- ------------- -------------- ----------- ---------- 01::("'\'1"'\ C't: f"U....'-.t( iJ vi SURFACE BURST 3311 3974 SHOE BURST 3311 3974 COLLAPSE 1124 1236 TENSION,BODY 307839 461,759 TENSION,JOINT 307839 554,110 Case B WEIGHT: 29.00 #/ft GRADE: N-80 THREAD: LTC ACTUAL DESIGN -------------- ------------- -------------- ------------- BURST 3311 3974 SHOE BURST 3311 3974 COLLAPSE 1124 1236 TENSION,BODY 271300 406,951 TENSION,JOINT 271300 488,341 SHOE DEPTH: RA,TING 8160 8160 7020 676,000 597,000 RATING S.F. 2.46 2.46 6.25 2.20 1.94 S.F. 9445 tvd 10649 md FOREST OIL 1.2 1.1 1.1 1.5 1.8 FOREST OIL REC'D SF -------------- ----------- ---------- -------------- ----------- ---------- 8160 8160 7020 676,000 597,000 2.46 2.46 6.25 2.49 2.20 2 If Case A enter 1, if Case Benter 2 Date: 06-Jul-04 1.2 1.1 1.1 1,5 1,8 . Csg Dsgn . CASING DESIGN I __________ Field: Development _______u_____~13EAlBlock: #REF! I Lease: West Foreland Well Number: 2 -.-.------ --..-.---- -_._-----~-- CasinQ Specifications 0.0. (in) Weight (lb/ft) Grade Connector Type I.D. (in) Drift (in) Burst (psi) Collapse (psi) Tension Body (kips) Tension Connector (kips) MD Shoe Depth (ft) TVD Shoe Depth (ft) ---_.__...._--_.._._---~,._---~._-_. -- ---_....__._-~_._----_.------ ----_._-._--_._-----~-.~~~ CasinQ Loads ------'.---- Surface or TaL Burst (psi) Shoe Burst (psi) Collapse (psi) Tension (kips) -..-.------..-------+- ---------.---..-------..-- ------------~ DesiQn Factors ---.----.----------.---------- Surface or TaL Burst Shoe Burst Collapse Body Yield Connector Yield PfUm"ig o øfitUng -713 o o o l~tjllJlÏiJH 0.00 #DIV/O! #DIV/O! #DIV/O! #DIV/O! o o o o o o o o o o o [)~¡U!6g 1 3 3/8 61 J-55 BTC 12.415 12.259 3090 1560 962 1025 3000 3000 ef9~Q#t¡9ijfi~ºøt6f:@pfº(JJ..6b2þfºal..6f3"f>r~l..,nf4 7 0 0 0 0 29.7 N-80 LTC 6.184 6.059 8160 7020 676 597 10649 0 0 0 0 9445 0 0 0 0 Þh'~"'#tiºrî 3311 3311 1124 271 .fí"-óâl.l#liijR 2.46 2.46 6.25 2.49 2.20 ...fi~ºªt6r·1 #DIV/O! #DIV/O! o o firøåtrlf1 #VALUE! #V ALUE! #VALUE! #V ALUE! #VALUE! -~------~-- Surface Burst pressure is at the top of each section. -- --~::=-~~~~~-~==~_===E~::~~::~::···-· ·~:~:~~~f----:-~-=--~-t~ ---------------- I ~ - t:~:~ ~~~ -- ~ ~~~ [)tilli6gU 1801 686 665 157 UdOiÔg 1.72 4.50 2.34 6.13 6.53 1 WC 112 No 1 APD SFH for MMS.xls P..øØI#jl"2 #DIV/O! #DIV/O! -13385 o el"Sðt.rit2 #VALUE! #VALUE! #V ALUE! #VALUE! #VALUE! PÎ"ø(Jl..,ijf4 #DIV/O! #DIV/O! o o PI',()ðt.6"~ #VALUE! #VALUE! #VALUEI #VALUE! #VALUE! -- PrøC:lI..I#4 #DIV/O! #DIV/O! o o ~----_..._-_.- PÎ"Ødl..nl'4 #VALUE! #VALUE! #VALUE! #V ALUE! #VALUE! --_._----~--,._._----- ---'--.._._~ ----..- -------~-------- . . MASP ----~- I MAXIMUM ANTICIPATED SURFACE PRESSURE Example calculations are for 2nd casing string. --~----- I ' =-iº:_P!~OffSe~_~~~ = ____ 9.3 ppg E. From Offset Wells = 0.60 ppg F. From Offset Wells = 8.6 ppg G. (C)(F)(0.052)= 4224 psi H. Average Fluid Gradient based on Nagy/Young correlation. ==~ G-(C/3)(D)(0.052)-(2*C/3)(H) for drilling c~ 2094PSi ______ºjC)(H) for production casing I I i J. Fracture gradient based on Matthews and Kelly Method or Eaton Chart. --TK~-(J+fO)(0.052)(B)= I 2090 psi --l-CK--(H)(B);---r------ 1801 psi ------¡-M.- Lesser of I or L = 1801 psi -~-~------~._,-~ Field: Development AREA/Block: #REF! Lease: West Foreland Well Number: 2 A. Casing (in.) B. Setting Depth (RKB rvD ft.) C. Depth of Next Casing (RKB rvD ft.) D. Max. Mud Weight @ Next Shoe(ppg) E. Specific Gravity I I F. Maximum Formation Pressure (ppg) G. Maximum Formation Pressure (psi) H. Fluid Gradient (psi/ft) I I. Surface Press. Neglecting Shoe(psi) J. Fracture Gradient at Shoe (ppg) I K. Fracture Pressure at Shoe (psi) L. Surface Press. With Shoe Frac.(psi) M. MASP (psi) -~--- ---~-- l:::::::q9iij¡i::Ulirmç!tpi9ª~ii.P'" ·.fW9~fÄ6*j.¡~>pi9~Î.Mfg .·p"9ØWjrªf'f~ª..fÄ6t4 o 13.375 7 0 0 0 0 o 3000 9445 0 0 0 0 3000 9445 9445 0 0 0 0 9.3 9.3 0.0 0.0 0.0 0.0 0.0 0.00 0.60 0.60 0.60 0.60 0.60 0.60 o 8.6 8.6 9 0 0 0 o 4224 4224 0 0 0 0 -0.0867 0.0966 0.0966 0.0000 0.0000 0.0000 0.0000 -310 2094 3311 0 0 0 0 0.0 12.4 16.4 0.0 0.0 0.0 0.0 o 2090 8546 0 0 0 0 -_._~ o 1801 7634 0 0 0 0 -310 1801 3311 v #DIV/O! #DIV/O! #DIV/O! #DIV/O! -- ---..-----.- ~~----- -._-~----------------_._.- ~~-_.._.._-----~-~.~ -,---- -.-.--.--.----.-.....- 1 we 112 No 1 APD SFH for MMS.xls . . Csg Test CASING TEST PRESSURE =-~~±- =~-----~----- Field: Development ~--_..- - AREA/Block: #REF! --'----Lease: West Foreland ~__",_..._---L.-_____ Well Number: 2 -----T--- -------Î----------------- I Tie Back? (y/n> n n n n ¡:¡;¡i¡¡çiø.#.f¡:::¡¡:¡ iijji§ø.¡_¡i:::~rf.lí.9.çiji¡;¡ ¡¡fiiªYJiimM¡¡3ig@j¡:µijf¡î. )~imtµijt:ª¡ ¡ifflf.i¡fOi;º-b4 -_.._-_._---~ A. Casing (in.) 0 13.375 7 0 0 0 0 B. Setting Depth (TVD ft.) 0 3000 9445 0 0 0 0 C. Depth to Next Casing (TVD ft.) 3000 9445 9445 0 0 0 0 D. Mud Weight @ Casing T.D. (ppg) 0 9.3 9.3 0 0 0 0 E. Casing Burst Pressure (psi) I 0 3090 8160 F. 70% Casing Burst Pressure (psi) 0 2163 57~ 0 0 0 0 G. 70o/û Burst.. (~v1\^I=PorePres) Diff (psi) 0 2116 5565 n ^ 0 0 v v MASP (psi) + SOOps; I 1.90 ~ " H. 3811 ' *0 *0 *0 *0 I. PROPOSED CASING TEST (psi) 200 2300 3800 **864 **0 **0 **0 I I ~ Example CjlCulations are fOí second ¡asing str . D. From Offset Wells (Mud Wt csg run in) 15.4 ppg G. F - (D - 9.0ppg) ( B * 0.052) I 2116 psi H. Max. Anticapated Surface Pressure Calculation + 500psi 2301 psi I I I I _._-----~----------- I Enter 1 if Prod Pkr is to be set inside Prod Csg, 2 if to be set inside Liner 1 (Upr Liner), -----~_._-~ and 3 if to be set inside Liner 2 (Lwr Liner) 2 --..------------~----r-.---~-- , ___....__,_,___..______m.____._________ o .. Liner Top MD (ft) = 0 TVD (ft) = 0 PP (ppg) = 0 (back-up pressure) ----. Maximum Pressure at Top of Liner: I ________= Max.:X~~mation Pressure - Hydrostatic Pressure Inside - Outside Backup Pressure for Case 1 = MASP + Packer Fluid Hydrostatic Pressure Inside - Outside Backup Pressure for Case 2 or 3 3311 psi ~- I o psi Liner Top Masp + 500psi I ** Liner Lap Test: = (Previous Casing Shoe Frac Gradient - Mud Weight @ Lnr depth) (Previous Csg Shoe TVD) (0.052)+500 psi --_=~~==-==~r~ - I ___+.£~~_~ure_~xerted on the 0 0 " Leak Off Test: i =(Liner Shoe Expected L.O.T. - Mud Weight @ liner depth)( Liner Top TVD)(0.052) =~]J;r&II.!'''Ip>-~_ - -~-±yressure ~xerted on the _ 0 0 Liner Lap Test: ¡ = Lwr Liner Lap Test + (Mud weight @ TD - Mud Weight @ Upr liner depth)(Upr Liner top TVD)(0.052) -psi ~_ ¡ I - -- ---------~-------J- : i nO n-f-Uner-Top---------r-- =-=f.!~t=:::n~=~¡b~~P 1:) =-~--=~~-=---- -- _ __~*~aXimum Pressure atTop of Liner (or @ _!D if a Tieback): __ ---- I = Max. Formation Pressure - Hydrostatic Pressure Inside - Outside Backup Pressure for Case 1 or 2 ..------- ~-_.'._.~ ___~_·_·__·.n_ ._--_..~--- -- --~--_..,._----~- o " Liner Top o o 9 o " Lin~....!op_ o -.---..----- o -- --.-"--.---.----,- --.----- 9 .------- 1 WC 112 No 1 APD SFH for MMS.xls . . Csg Test ::: MASP + Packer Fluid Hydrostatic Pressure Inside - Outside Backup Pressure for Case 3 psi I psi Liner Top Masp + 500psi =~:=~_**1iner ~~I~s~~:r ~asing test if a Tieback): I _____~_@_,,~_(P~:vio~s Casing Shoe Frac Gradient - Mud Weight @ TD) (Previous Casing Shoe TVD) "'%""".-HjWlliÞ.-& . ~-l¡ÆI.i(!' 'mwl'iJlWíj¡'ø pSI -- ..-J-~~--_.u._.__. i I . t'--~"--T- u__._~--~_-_~ I I-~ I Enter 1 i! Pro~kr is to be set inside Prod Csg, 2 if to be set inside Liner 2 o o " Liner Top MD (ft) = 0 TVD (ft) = 0 PP (ppg) ~ 0 (back-up 'pressure) __:.Maximum Pressure at Top of Liner: ::: Max. Formation Pressure - Hydrostatic Pressure Inside· Outside Backup Pressure for Case 1 ::: MASP + Packer Fluid Hydrostatic Pressure Inside - Outside Backup Pressure for Case 2 . I I I I #DlV/O! pSI ~__~___ 0 psi Liner Top Masp + 500psi ---~;;:_Li'~¿~-;- Test: I ::: (Previous Casing Shoe Frac Gradient - Mud Weight @ TD) (Previous Casing Shoe TVD) (0.052)+500 psi ~===-~ °lpSi - j I I I I Enter 1 if Prod Pkr is to be set inside Prod Csg, 2 if to be set inside Liner I f 1 _...._~-_._-~~ " Liner Top o -.. -_.~-------- MD (ft) = 0 TVD (ft) = 0 PP (ppg) = 9 (back-up pressure) * Maximum Pressure at Top of Liner: ::: Max. Formation Pressure - Hydrostatic Pressure Inside - Outside Backup Pressure for Case 1 ::: MASP + Packer Fluid Hydrostatic Pressure Inside - Outside Backup Pressure for Case 2 =:_~=~=~o-' PSL~ i o psi Liner Top Masp + 500psi I --_._--,._-~-~.._.- -..-..- --~----'------"-'----~ --.------ ** Liner Lap Test: ::: (Previous Casing Shoe Frac Gradient· Mud Weight @ TD) (Previous Casing Shoe TVD) (0.052)+500 psi o I, psi I (apd!024-apd!N28)*0.052*apd!L24 )+500) I I ---I i I I I I Enter 1 if Prod Pkr is to be set inside Drlg Lnr, 2 if to be set inside Prod Liner ==-~~::=--=--=~:-T ~_==~ 1 ---------0· i" Liner Top -----¡¡ID- (ft) = ¡ 0 -.-.--.------ I TVD(ft) = I 0 !,PJppg)t-:~::=-----'-9- (back-up ,pressure) !* _~a.xill1uIl1Pr~s~LJr..E!_~!2()p of Liner: _ I ! i ::: Max. Formation Pressure - Hydrostatic Pressure Inside - Outside Backup Pressure for Case 1 . - -r u-;';MASP~-Pa~k~-;:-Fi~ïd-Hydrostatic Pr~~~~~lnside - Outside Backup-Pressure for Case 2 1 WC 112 No 1 APD SFH for MMS.xls --------,--- -~._--- ----,----- _._~-~--------_.- --- . . Csg Test ~:_=~-===--~-~:===_ Liner Top Masp + 500psi I ~ ---I.. Liner Lap Test: -- ----+-------- --------- = (Previous Casing Shoe Frac Gradient - Mud Weight @ TD) (Previous Casing Shoe TVD) (0.052)+500 psi __no_______ I I I I I o psi ---..-.--"- -~~._---~.- 1 WC 112 No 1 APD SFH for MMS.xls Forest Oil corpor. Field: AREA/Block: Lease: Well Number: RKB: 25' WD: 0' Development #REF! West Foreland 2 9.3 ppg Mud 8.6 ppg Pore Pressure 12.4 ppg Fracture Gradient 12.4 ppg Shoe Test 9.3 ppg Mud 8.6 ppg Pore Pressure 16.4 ppg Fracture Gradient na ppg Shoe Test PROPOSED WELLBORE SCHEMATIC Surface Location: Bottomhole Location: . ¿ L . Roy Smith July 6, 2004 880' FSL, 631' FWL of Section 21, T8N, R14W 3941' FSL & 1109' FEL Section 21, T8N, R14W . ~ 120 ft md 1 20 ft tvd IPiPe 0.D.20 in. I Wall ( t) Grade B Oft Top of Cement (Surf) Bit Size 171/2in. 3000 ft md Pipe O.D. 13318 in. 3000 ft tvd Weight 61.0 Iblft Grade J-55 Coupling BTC 7000 Top of Cement (Prod) Bit Size 97/8 in, 10649 ft md Pipe O.D. 7 in. 9445 ft tvd ./ Weight 29.7 Ib/ft Grade N-80 Coupling LTC . . Cement CEMENT DESIGN Field: Development AREA/Block: #REF! Lease: West Foreland Well Number: 2 Lead Tail Cmt Cmt Casing Hole Casing Planned Total Size Size J.D. MD T.O.C.(ft) OHE (sxs) (ft3/sx) (ft3) (ft3) (ft3) 20 22.650" 120' 13 3/8" 1 7 1/2" 12.415" 3000' A' 100% 650 1.17 762 3416 4178 7 9 7/8" 6.184" 1 0649' 7000' 25% 1050 1.15 1206 0 1206 0 0.000" A' A' 0% 0 0.00 0 0 0 0.000" 0 0 0 0 0.000" a' 0 0 0 0 0.000" 0' 0 0 0 7/26/2004 MP 9901 Scoping Max Load APD C-S-P-L 1-L2 RVSD STEVE Page 1 . . Drilling Program Field: #REF! Lease: West Foreland Well: 2 Rig Name: TBD Rig Type: Land STEP 1 2 3 A .. 5 6 7 8 OPERATION Drive 20" to ±120'. Mobe rig to location. Rig up & Nipple up divèrter & test. Drill 17 1/2" hole to ±3,OOO'MD/TVD. Condition hole. Rün & cement 13 3/8" eündüctür casing. NU BOPe. Test per APD. Drill out and perform shoe test to 12.4 ppg. Drill 9 7/8" hole to ±5,500'MD/TVD and begin directional drilling. Drill to ±10649'MD/9,945'TVD. Condition hole and log evaluate. Run & cement 7 " production casing. . SERVICES SINGLESHOT GYRO MUL TISHOT GYRO OR TELEDRIFT MAGNETIC SINGLESHOT MAGNFTIr. MUL TISHOT C.MWD (DIR ONLY')- MWD (DIR-GR/Res) MWD (Dir TPLE COM) MWD (DIR-GR) Paleo Samples GEOLOGIST: ELOG QVGJ ~.. Tri .leCOMBO C SWC's LSS-GR FMS-DIPMTR 1 ST RU N 2ND RUN Triple COMBO SWC's MRIL DIPOLE SONIC LOGGING PROGRAM . REMARKS NONE. NONE. NONE. To tie in for Directional Work from 3000' to surface Production Hole'./ NON!:::. NONE NONE NONE. Art Saltmarsh RUN FAX 1 NO 1 NO NO NO NO NO NO NO NO 3ND RUN Trip~COMBO NO SWC's NO FMI NO DIPOLE SONIC NO Special logs (Hi Res DIN, 3-Dex Vert Res NO DART NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO NO HOME PHONE OFFICE PHONE 907-868-2141 REMARKS Possibly---' pc::r:.'; ,~\ <r \Jt \)\ NOTE: FAX MWD LOGS & MWD MORNING REPORTS DAILY TO OFFICE FAX: 303-814-1712 SPECIAL INSTRUCTIONS: SAMPLES (If taken): Send to: SWC's (If taken): Send to: OTHER WORKING INTEREST: . . WEST FORELAND #2 DRILLING HAZARDS SUMMARY 17-112" Hole 113-3/8" Casine Interval EVENT Broach of Conductor Gas Hydrates Sticking BHA in Coals Hole Swabbing/Tight Hole on Trips Lost Circulation 9-7/8" Hole / 7" Casine Interval Event Sticking BHA in Coals High ECD and swabbing Barite Sag Differential Sticking Abnormal Reservoir Pressure Lost Circulation RISK LEVEL Low Low / Moderate Moderate Low Risk Level Moderate Moderate Low Low Low J Low Mitieation Strateev Monitor cellar continuously during interval. If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, additions of Lecithin. Control drill through coals. Frequent reaming and trips through coals until sticking tendency abates. Circulate hole clean prior to trip. Proper hole fill (use of trip sheets), pumping out of hole as needed. Prevent by keeping hole clean. If losses occur - reduce pump rates and mud rheology, use LCM Mitieation Strateev Control drill through coals. Frequent reaming and trips through coals until sticking tendency abates. Condition mud prior to trips. Monitor ECD's while drilling across pay intervals. Pump and rotate out on trips as a last resort. Good drilling practices as documented in well plan. Periodic wiper trips. Do not leave pipe static for extended period of time Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, increased mùd weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Reduced pump rates, mud rheology, LCM. @ 3,000' MD KOP 5,500' BUILD TO 440 & HOLD TO TD TD Wellbore Name West Foreland#2 (8) Well Name West Foreland#2 Slot Name \¡VF#2 Installation Name West Forelands Pad #1 Field Name West Foreland Created By Comments . Forest Oil Corp.,WF#2 West Forelands Pad #1, West Foreland,West Cook Inlet, Alaska I Created 17 -Aua-2004 I Government ID I Grid Northina 2475581.6250 I Latitude 1 N60 45 53.5586 I Grid Eastina 1190452,3700 I Eastina 191000.2193 I Northina 2474680.5740 I Eastina 191000.2193 I Northina 2474680.5740 . PROPOSAL LISTING Page 1 Wellbore: West Foreland#2 (8) Wellpath: WF #2 Verso #8 Date Printed: 17 -Aug-2004 I Last Revised 17 -Aua-2004 I Last Revised 30-Apr-2004 I Lonaitude 1 W454 43 52.3930 I North 88- --" 1 O.;j<!N f'l_ BAKER HUGHES INTEQ lEast 5-1 --W' I { .;j{ I Coord Svstem Name I North Aljanment AK-4 on NORTH AMERICAN DATUM 1927 datu~ True I Coord Svstem Name I North Alianment AK-4 on NORTH AMERICAN DATUM 1927 datu~ True 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 90.0ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 349.58 degrees Bottom hole distance is 3092.24 Feet on azimuth 349.42 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated e . Forest Oil Corp.,WF#2 West Forelands Pad #1, West Foreland,West Cook Inlet, Alaska PROPOSAL LISTING Page 2 Wellbore: West Foreland#2 (8) Well path: WF #2 Verso #8 Date Printed: 17-Aug-2004 r'i. BAKER HUGHES INTEQ Wellpath Report MD[ft] Inc[deg] Azi[deg] TVD[ft] Vertical North[ft] East[ft] Station Station Dogleg Vertical Station Comment Depth SS Position(Grid Position(Grid [deg/10 Section[f North) East) Oftl tl 0.00 0.00 0.00 0.00 -90.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 Tie on 100.00 0.00 0.00 100.00 10,00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 20.000in Casinq 200.00 0.00 0.00 200.00 110.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 300.00 0.00 0.00 300.00 210.00 O.OON O,OOE 2475581.63 190452.37 0.00 0.00 400.00 0.00 0.00 400.00 310.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 500.00 0.00 0.00 500.00 410.00 O,OON O.OOE 2475581.63 190452.37 0.00 0,00 600.00 0.00 0.00 600.00 510.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 700.00 0.00 0.00 700.00 610.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 800.00 0.00 0.00 800.00 710.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 900.00 0.00 0.00 900.00 810.00 O,OON O.OOE 2475581.63 190452.37 0.00 0.00 1000.00 0.00 0.00 1000.00 910.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 1100.00 0.00 0.00 1100.00 1010.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 1200.00 0.00 0.00 1200.00 1110.00 O.OON O.OOE 2475581.63 190452.37 0.00 0,00 1300.00 0.00 0.00 1300.00 1210.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 1400.00 0.00 0.00 1400.00 1310.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 1500.00 0.00 0.00 1500.00 1410.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 1600.00 0.00 0.00 1600.00 1510.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 1700.00 0.00 0.00 1700.00 1610.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 1800.00 0.00 0.00 1800.00 1710.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 1900.00 0.00 0.00 1900.00 1810.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 2000.00 0.00 0.00 2000.00 1910.00 O.OON O.OOE 2475581.63 190452.37 0,00 0.00 2100.00 0.00 0.00 2100.00 2010.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 2200.00 0.00 0.00 2200.00 2110.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 2300.00 0,00 0.00 2300.00 2210.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 2400.00 0.00 0.00 2400.00 2310.00 O.OON O.OOE 2475581.63 190452.37 0.00 0,00 2500.00 0.00 0.00 2500.00 2410.00 O,OON O.OOE 2475581.63 190452.37 0.00 0.00 2600.00 0.00 0.00 2600.00 2510.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 2700.00 0.00 0.00 2700.00 2610.00 O.OON O,OOE 2475581.63 190452.37 0.00 0.00 2800.00 0.00 0.00 2800.00 2710.00 O.OON O.OOE 2475581.63 190452,37 0.00 0.00 2900.00 0.00 0.00 2900.00 2810.00 O.OON O.OOE 2475581.63 190452.37 0.00 0,00 3000.00 0.00 0.00 3000.00 2910.00 O.OON O.OOE 2475581.63 190452.37 0.00 0.00 Begin Nudge, 10 3/4in Casing, End of Hold 3100.00 2,00 45.00 3099.98 3009.98 1.23N 1.23E 2475582.83 190453.64 2.00 0,99 3200.00 4.00 45.00 3199.84 3109.84 4,93N 4.93E 2475586.43 190457.43 2,00 3.96 3250.00 5.00 45.00 3249.68 3159.68 7.71N 7.71E 2475589.13 190460.28 2.00 6.19 End Nudqe. End of Build/Turn 3300.00 5.00 45,00 3299.49 3209.49 10.79N 10.79E 2475592.13 190463.44 0.00 8.66 3350,00 5,00 45.00 3349.30 3259.30 13.87N 13.87E 2475595.13 190466.60 0.00 11.14 Beqin Drop, End of Hold 3400.00 4.00 45.00 3399.15 3309.15 16.65N 16.65E 2475597.83 190469.45 2.00 13.36 3500.00 2.00 45.00 3499,01 3409.01 20.35N 20.35E 2475601.43 190473.25 2.00 16.33 3600.00 0.00 0.00 3598.99 3508.99 21.58N 21.58E 2475602.63 190474.51 2.00 17.32 End Drop, End of Drop/Tum 3700.00 0.00 0.00 3698.99 3608.99 21.58N 21.58E 2475602,63 190474.51 0.00 17.32 3800.00 0.00 0.00 3798.99 3708.99 21.58N 21.58E 2475602.63 190474.51 0.00 17.32 3900.00 0.00 0.00 3898.99 3808.99 21.58N 21.58E 2475602.63 190474.51 0.00 17.32 4000.00 0.00 0,00 3998.99 3908.99 21,58N 21.58E 2475602.63 190474.51 0.00 17.32 4100.00 0.00 0.00 4098.98 4008.99 21.58N 21.58E 2475602.63 190474.51 0.00 17.32 4200.00 0.00 0.00 4198.98 4108.99 21.58N 21.58E 2475602,63 190474.51 0.00 17.32 4300.00 0.00 0.00 4298.98 4208.99 21.58N 21.58E 2475602.63 190474.51 0.00 17.32 4400.00 0.00 0.00 4398.98 4308.99 21.58N 21.58E 2475602.63 190474.51 0.00 17.32 4500.00 0.00 0.00 4498.98 4408.99 21.58N 21.58E 2475602.63 190474.51 0.00 17.32 4600.00 0,00 0.00 4598.98 4508,99 21.58N 21.58E 2475602.63 190474.51 0.00 17.32 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 90.0ft above Mean Sea Level) . Vertical Section is from O.OON O.OOE on azimuth 349.58 degrees Bottom hole distance is 3092.24 Feet on azimuth 349.42 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated e . Forest Oil Corp.,WF#2 West Forelands Pad #1, West Foreland,West Cook Inlet, Alaska PROPOSAL LISTING Page 3 Well bore: West Foreland#2 (8) Wellpath: WF #2 Verso #8 Date Printed: 17-Aug-2004 r'i_ BAKER HUGHES INTEQ Wellpath Report MD[ft] Inc[deg] Azi[deg] TVD[ft] Vertical North[ft] East[ft] Station Station Dogleg Vertical Station Comment Depth SS Position(Grid Position(Grid [deg/10 Section[f North) East) Oft1 t1 4700.00 0.00 0.00 4698,98 4608.99 21.58N 21,58E 2475602.63 190474.51 0.00 17.32 4800.00 0.00 0.00 4798.98 4708.99 21.58N 21.58E 2475602.63 190474.51 0,00 17.32 4900.00 0.00 0.00 4898.98 4808.99 21.58N 21.58E 2475602.63 190474.51 0.00 17.32 5000.00 0.00 0.00 4998,98 4908.99 21.58N 21.58E 2475602.63 190474.51 0.00 17.32 5100.00 0.00 0.00 5098.98 5008.99 21.58N 21.58E 2475602.63 190474.51 0.00 17,32 5200.00 0.00 0.00 5198.98 5108.99 21.58N 21.58E 2475602.63 190474.51 0.00 17.32 5300.00 0.00 0.00 5298.98 5208.99 21.58N 21.58E 2475602.63 190474.51 0.00 17.32 KOP. 3DJ Kick off Point 5400.00 2.00 348.95 5398.97 5308.96 23.29N 21.25E 2475604.35 190474.22 2.00 19.07 5500.00 4.00 348.95 5498.82 5408.82 28.43N 20.24E 2475609.51 190473.35 2.00 24.30 5600.00 6.00 348.95 5598.44 5508.44 36.98N 18.57E 2475618.11 190471.91 2.00 33.02 5700,00 8.00 348.95 5697.69 5607.69 48.94N 16.24E 2475630.12 190469.89 2.00 45.20 5800.00 10.00 348.95 5796.45 5706.45 64.30N 13.24E 2475645.55 190467.30 2,00 60.84 5900.00 12.00 348.95 5894.61 5804.61 83.02N 9.58E 2475664.37 190464.14 2.00 79,92 6000.00 14.00 348.95 5992.04 5902.04 105.10N 5.27E 2475686.55 190460.41 2.00 102.41 6100.00 16.00 348.95 6088.63 5998.63 130.50N 0.31E 2475712.07 190456.12 2.00 128.29 6200.00 18.00 348.95 6184.25 6094.25 159.19N 5.30W 2475740.90 190451.27 2.00 157,53 6300.00 20,00 348.95 6278.80 6188.80 191.14N 11.54W 2475773.01 190445.88 2.00 190.08 6400,00 22.00 348.95 6372.15 6282,15 226.32N 18.41W 2475808.35 190439.94 2.00 225.91 6500.00 24.00 348.95 6464.20 6374.20 264.66N 25.90W 2475846.88 190433.46 2,00 264.98 6600.00 26.00 348.95 6554.83 6464.83 306.14N 33.99W 2475888.55 190426.46 2.00 307.24 6700.00 28.00 348.95 6643.92 6553.92 350,69N 42.70W 2475933.32 190418.93 2.00 352.63 6800.00 30,00 348.95 6731.38 6641.38 398.27N 51.99W 2475981.13 190410.90 2.00 401.11 6900.00 32.00 348.95 6817.09 6727.09 448.82N 61.86W 2476031.92 190402.36 2.00 452.61 7000.00 34.00 348.95 6900.95 6810.95 502.27N 72.30W 2476085.63 190393.34 2.00 507.06 7100.00 36.00 348.95 6982.87 6892.87 558.56N 83.29W 2476142.19 190383.83 2.00 564.42 7200.00 38.00 348.95 7062.73 6972.73 617.62N 94.83W 2476201.54 190373.86 2.00 624.59 7300.00 40.00 348.95 7140.44 7050.44 679.38N 106.89W 2476263.60 190363.43 2.00 687.51 7400.00 42.00 348.95 7215.90 7125.90 743.77N 119.47W 2476328.29 190352.56 2.00 753.11 7500.00 44.00 348.95 7289.03 7199.03 810.70N 132.54W 2476395.55 190341.25 2.00 821.31 7600.00 46.00 348.95 7359.74 7269.74 880.10N 146.09W 2476465.28 190329.53 2.00 892.01 7627.04 46.54 348.95 7378.43 7288.43 899.28N 149.84W 2476484.55 190326.30 2.00 911.55 EOC. End of Buildrrurn 7700.00 46.54 348.95 7428.62 7338.62 951.25N 159.99W 2476536.77 190317.52 0.00 964.50 7800.00 46.54 348.95 7497.40 7407.40 1022.49N 173.90W 2476608.36 190305.49 0.00 1037,08 7900.00 46,54 348.95 7566.19 7476.19 1093,73N 187.81W 2476679.94 190293.46 0.00 1109.67 7978.24 46.54 348,95 7620.00 7530.00 1149.47N 198.70W 2476735.94 190284.05 0.00 1166.45 TQt#1 WF#2 8000.00 46.54 348.95 7634.97 7544.97 1164.97N 201.73W 2476751.52 190281.43 0,00 1182.25 8100.00 46.54 348.95 7703.75 7613.75 1236.21N 215.64W 2476823.10 190269.40 0.00 1254.83 8200.00 46.54 348.95 7772.54 7682.54 1307.46N 229.55W 2476894.69 190257.37 0.00 1327.41 8300.00 46.54 348.95 7841.32 7751.32 1378.70N 243.47W 2476966.27 190245.34 0,00 1399.99 8400.00 46.54 348.95 7910.10 7820.10 1449.94N 257.38W 2477037.85 190233.31 0.00 1472.58 8500.00 46.54 348.95 7978.89 7888,89 1521.18N 271.29W 2477109.44 190221.28 0.00 1545.16 8600.00 46.54 348.95 8047.67 7957.67 1592.42N 285.21W 2477181.02 190209.24 0.00 1617.74 8700.00 46.54 348.95 8116.46 8026.46 1663.66N 299.12W 2477252.60 190197.21 0.00 1690.32 8800.00 46.54 348.95 8185.24 8095.24 1734.90N 313.03W 2477324,19 190185.18 0.00 1762.90 8900.00 46.54 348.95 8254.02 8164.02 1806.14N 326.95W 2477395.77 190173.15 0.00 1835.49 9000.00 46.54 348.95 8322.81 8232.81 1877.38N 340,86W 2477467.35 190161,12 0.00 1908.07 9100.00 46.54 348.95 8391.59 8301.59 1948.62N 354.77W 2477538.94 190149.09 0.00 1980.65 9200.00 46.54 348.95 8460.38 8370.37 2019.86N 368.69W 2477610.52 190137.06 0.00 2053.23 9300.00 46.54 348.95 8529.16 8439.16 2091.10N 382.60W 2477682.10 190125,03 0.00 2125.81 9400,00 46.54 348,95 8597.94 8507.94 2162.34N 396.51W 2477753.68 190113.00 0.00 2198.40 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 90.0ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 349.58 degrees Bottom hole distance is 3092.24 Feet on azimuth 349.42 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . Forest Oil Corp.,WF#2 West Forelands Pad #1, West Foreland,West Cook Inlet, Alaska PROPOSAL LISTING Page 4 Wellbore: West Foreland#2 (8) Wellpath: WF #2 Verso #8 Date Printed: 17-Aug-2004 r&l. BAKER HUGHES INTEQ Wellpath Report MD[ft] Inc[deg] Azi[deg] TVD[ft] Vertical North[ft] East[ft] Station Station Dogleg Vertical Station Comment Depth SS Position (Grid Position(Grid [deg/10 Section[f North) East) Oft] tl 9500.00 46,54 348.95 8666.73 8576.73 2233.58N 410.43W 2477825.27 190100,97 0.00 2270.98 9516.39 46,54 348.95 8678.00 8588.00 2245.26N 412.71W 2477837.00 190099.00 0.00 2282.87 Anomaly A WF#2, Anomaly A WF#2 2-Jul-04. End of Hold 9600.00 46.54 348.95 8735.51 8645.51 2304.82N 424.34W 2477896.85 190088.94 0.00 2343.56 9700.00 46.54 348.95 8804.29 8714.29 2376.06N 438.26W 2477968.43 190076.91 0.00 2416.14 9800.00 46,54 348.95 8873.08 8783.08 2447.30N 452.17W 2478040.02 190064.88 0.00 2488.72 9900.00 46.54 348.95 8941.86 8851.86 2518.54N 466.08W 2478111.60 190052.85 0.00 2561.31 10000.00 46.54 348.95 9010.65 8920.65 2589.78N 480.00W 2478183.18 190040.82 0.00 2633.89 10100.00 46.54 348.95 9079.43 8989.43 2661.03N 493.91W 2478254.77 190028.79 0.00 2706.47 10200.00 46.54 348.95 9148.21 9058.21 2732.26N 507.82\^J 2478326.35 190016.76 """ 2779.05 v.vv 10300.00 46.54 348.95 9217.00 9127.00 2803.51 N 521.74W 2478397,93 190004.73 0.00 2851.63 10400.00 46.54 348.95 9285.78 9195.78 2874.75N 535.65W 2478469.52 189992.70 0.00 2924.22 10500.00 46.54 348.95 9354.56 9264.56 2945.99N 549.56W 2478541.10 189980.67 0.00 2996.80 10600.00 46.54 348.95 9423.35 9333.35 3017.23N 563.48W 2478612.68 189968.64 0.00 3069.38 10631.48 46.54 348.95 9445.00 9355.00 3039.65N 567.86W 2478635.21 189964.85 0.00 3092.23 TD WF#2. 7 5/8in CasinQ. End of Hold 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 90.0ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 349.58 degrees Bottom hole distance is 3092.24 Feet on azimuth 349.42 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated · e Forest Oil Corp.,WF#2 West Foreland, West Foreland,West Cook Inlet, Alaska PROPOSAL SUMMARY Page 2 Wellbore: West Foreland#2 (7) Wellpath: WF #2 Verso #7 Date Printed: 2-Jul-2004 "&1. BAKER HUGHES INTEQ 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 90.Oft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 351.13 degrees Bottom hole distance is 3098.52 Feet on azimuth 351.13 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated PROPOSAL SUMMARY Page 3 Wellbore: West Foreland#2 (7) Wellpath: WF #2 Verso #7 Date Printed: 2;;~/ / East[ft] /// Dogleg / [deg/100ft] 0.00 O.OON//' O.OOE 0.00 /" 5304.65 O.OON/ O.OOE 0.00 7397.09 897.2fN 140.14W 2.00 7620.00 »52.72N 176.93W 0.00 867~' 22~ 351.47W Q,OO ~' 351.0~4~5.00 3061.44N f /~¿) ,,'i///~ .".<~~ / ,.'/ /1" ..- /" /' ,/..~ / . e Forest Oil Corp.,WF#2 West Foreland, West Foreland,West Cook Inlet, Alaska Wellpath Report MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] 0.00 5304.65 7650.65 7977.00 0.00 0.00 46.92 46.92 0.00 351.12 351.12 351.12 9525.96 351.13 46.92 10649.30 46.96 477.90W r&l. BAKER HUGHES INTEQ 0.00 Vertical Section[ftl 0.00 Tie on 0.00 KOP 908.08 End of Build 1146.46 Tgt#1 WF#2- 2-Jul-04 2277.78 End of Drop/Turn & Anomaly A WF#2 2-Jul-04 3098.52 End of Build/Turn & Tgt TD WF#2 2-Jul-04 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 90.0ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 351.13 degrees Bottom hole distance is 3098.52 Feet on azimuth 351.13 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . Forest Oil Corp.,WF#2 West Foreland, West Foreland,West Cook Inlet, Alaska Comments MD[ft] TVD[ft] 5304.65 5304.65 7650.65 7397.09 7977.00 7620.00 9525.96 8678.00 10649.30 9445.00 North[ft] O.OON 897.21 N 1132.72N 2250.50N 3061.44N East[ft] Comment O.OOE KOP 140.14W EOC 176.93W Target #1 351.47W Anomaly A 477.90W TD (Target)ß I Hole Sections Diameteí Ic.~... Of..C:UL I c.~... o&.alL ~"',...oi+ OLCU L nn] MD[ft] TVD[ft] North[ftl 24.000 0.00 0.00 143/4 100.00 100.00 97/8 3000.00 3000.00 . PROPOSAL SUMMARY Page 4 Wellbore: West Foreland#2 (7) Wellpath: WF #2 Verso #7 Date Printed: 2-Jul-2004 J&i. BAKER HUGHES INTEQ 1::........1 L_,", ~,;.;....... \NeHbore ~IIU I::IIU vldll TVD[ft] North[ft] East[ft] 100.00 O.OON O.OOE West Foreland#2 (7) 3000.00 3000.00 O.OON O.OOE West Foreland#2 (7) 10649.30 9445.00 3061.44N 477.90W West Foreland#2 (7) Casinas Name Top Top Top Shoe Shoe Shoe Shoe Wellbore MD[ftl TVD[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] 20" 0.00 O.OOE 100.00 100.00 O.OON O.OOE West Foreland#2 (7) Conductor 10 3/4" 0.00 O.OON O.OOE 3000.00 3000.00 O.OON O.OOE West Foreland#2 (7) Casing 7 5/8in 0.00 O.OON I O.OOE 10649.30 9445.00 3061.44N 477.90W West Foreland#2 (7) Casing Taraets Name Anomaly A WF#2 2-Jul-04 Tgt TD WF#2 2-Jul-04 Tgt#1 WF#2- 2-Jul-04 East[ft] TVD[ft] Latitude Longitude Easting Northing Last Revised 225 . 0 351.47W 8678.00 N60 465.6687W151 440.7026 190099.00 2477837.00 2-Jul-2004 N 61 .44 477 .90W 9445.00 N60 4ti3.6543W151 443.2488 189994.00 2478651.00 2-Jul-2004 N 1132.72 176.93W 7620.00 N60 464.6614W151 487.1881 190244.00 2476715.00 2-Jul-2004 N 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 90.0ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 351.13 degrees Bottom hole distance is 3098.52 Feet on azimuth 351.13 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ¡;;: ~ -500 N II E o ..... CD -æ o (J') 500 - - CD ~ J: - C. CD C ca (.) :e 5000 CD > CD ::J ~ l- I V 8500 10000 . Oil Corp. Slot: WF#2 Well: West Foreland#2 Wellbore: West Foreland#2 (7) . Forest Location: Field: Installation: West Cook Inlet, Alaska West Foreland West Foreland o Jl 1000 TARGET DATA MD Ine Azi TVD North East Name 9526 46.92 351.13 8678 2250 -351 Anomaly A WF#2 2..Jul-04 190099.00 East: 2477837.00 North Position / / j l 103/4" Casing - 0.00 Inc. 3000.00 Md. 3000.00 TV.....D. .~'ìNr C'\, ~ ,;AnomalY A WF#2 2-Jul-0 ~/ ,~ / 00'\ ,/ / 1/ / 1500 7977 46.92 351.12 7620 1133 -177 Tgt#1 WF#2-2..Jul-04 10649 46.96 351.15 9445 3061 -478 T9tTD WF#2 2..Jul-04 2000 2500 3000 3500 4000 4500 5500 D, 0.00 VS 6000 KOP - 0.00 Inc, 5304.65 Md, 5304.6 4,00 8.00 12.00 16.00 20.00 24.00 28.00 32.00 6500 7000 Scale 1 em = 125 ft -1000 -750 Tgt#1 WF#2 - 2-Jul-04 7500 EOC - 46.92 Inc. 7650.65 Md, 7397,09 TVD. 908.08 VS Target#1 . 46.92Inc, 7977.00 Md. 7620.00TVD, 1146.46VS 46.92 Surface 0.00 N 0.00 E 8000 9000 Anomaly A - 46.92 Inc, 9525,96 Md, 8678.00 TVD, 2277.78 VS 9500 ~ TD (Target) - 46.96 Inc, 10649.30 Md. 9445.00 TVD. 3098.52 VS -500 -0 500 1000 1500 2000 2500 3000 3500 Scale 1 em = 250ft Vertical Section (feet) -> Azimuth 351.13 with reference 0.00 N, 0.00 E from WF#2 East (feet) -> -500 -250 ì \' Tgt TO WF#2 2-Jul-04 '&1. BAKER HUGHES INTEQ 3500 3250 3000 2750 2500 2250 2000 ^ I 1750 Z 0 ;:¡. :::r 1500 ;; (\) - - 1250 1000 750 500 250 en C) ID iD o C) 3 II ..... -250 I\) 01 ~ Created by : Planner T Jones Date plotted: 2..Jul-2004 Plot reference is West Foreland#2 (7). Ref wellpath is WF #2 Verso #7. Coordinates are in feet reference W F#2. True Vertical Depths are reference Ri9 Datum. Measured Depths are reference Rig Datum, Rig Datum: Datum #1 Rig Datum to Mean Sea Level: 90.00 ft. Plot North is aligned to TRUE North. . M' SW~CQ I . .,"" .<,,';;¡,'~ø"'· -«--:=:"';7;;~~:~;$~j;.,. . ,.:'., . Mud Proposal "West Foreland #2" Cook Inlet Nabors 129 MUD PROPOSAL for: West Foreland #2 Cook Inlet, Alaska Rig: Nabors 129 Prepared by Pat Young MI-SWACO Project Engineer Phone: 907-274-5533 E-mail: pyounq@midf.com RevieWed 'by Mark Dick - MI-SWACO Project engineer Phone: 907-274-5047 Roy Smith Drilling Engineer E-mail: mdick@midf.com Approved by E-mail: Roy Smith [RLSmith@forestoil,coml (Approve if assumptions are correct and the drilling fluids program is consistent with well objectives) Prepared by: Pat Young Last Revision: 07/27/04 Signature Signature: Signature: Confidential Mi SWACQ"".iß;;;'" , ~~~·';;;~~~:;':~~~~f~¡~~i:.e~'d'!;;j'>" . Mi SWACtt'~Ä~~?> _·_·~::~,:_'~:;:;;:~á~~q,;;y Casing Size (in) 24 13.375 100' - 3,000 3,000'- 10,682' Completion 5% KCI Hole Si%e (in) Casing Program 24 17.5 9.875 . Mud Proposal "West Foreland #2" Cook Inlet Nabors 129 Prepared by: Pat Young Last Revision: 07/27/04 Mud W~ight (Ib/gal) 9.2-9.5 9.5 ,/ 9.0 8.7 v Casing and Fluid Summary Depth MD (ft) TVD (ft) Mud System $19,800 $213,397 $6,120 Total Fluid and Engineering Cost 100 100 DRIVEN 3,000 3,000 SPUD 10,682 9,440 VERSA-DRIL $3,375 @5days $11,475@17days $2,700@4days $23,175 $181,697 $8,820 Engineering cost reflects J Engineer at Confidential .00 day' for days. $23,175 $224,872 $223,692 $223,692 Mi SWACQ..."++··..,,. . -~,_·,:;>~;t;-;~~~¿~7l;$J};J1j%f;Yiþ' . Mi SWACQ~;~~, ._-,,:~:-:,;~~~~~~1f#~- . '_<C·_",.. -·c·.....:>:.....;.>. .'-". :,' ....!.- ,', " ~ .,'.' Mud Proposal "West Foreland #2" Cook Inlet Nabors 129 Prepared by: Pat Young Last Revision: 07/27/04 Section 2 - Challenges I Potential Problems Hole Cleaning Recommendations · Low-shear rate viscosity "LSRV" values (6 and 3 rpm) has a greater impact on hole cleaning than yield point, in addition to providing barite suspension under dynamic as well as static conditions. Optimize rheology to increase hole cleaning efficiency of fluid (Adjustment of Yield Point and 6 rpm readings). · Rheology and Hydraulics calculations will be run daily by the field engineers and the mud properties will be adjusted as needed to maximize hole cleaning. ~ Use the highest practical annular velocity to maintain geed hole cleaning. Annular velocity provides the upward impact force necessary for good cuttings transport. · Control drill to manage difficult hole cleaning situations. Penetration rates determine the annular cuttings load. Keep cuttings concentration less than 5% (by volume) in order to minimize drilling problems. Sweep Recommendations: · M-I SWACO does not recommend the use of sweeps unless hole conditions dictate the necessity. · Hi- Vis sweeps are recommended to use if needed (for straight hole sections). The volume should be enough to cover at least 200-300 annular volume of the open hole. The recommended rheology of the sweep would have the Yield Point in the 35-40 range and the 6 RPM readings in the 15-20 range. · Low viscosity sweeps are another option for deviated hole sections. · The need to pump LCM sweeps will be dictated by hole conditions. Bit/BHA Balling Recommendations · The drilling rate should be controlled to keep the concentration of cuttings in the annulus below 5%. · Short trips should be made as necessary to minimize buildup of cuttings in areas of hole washout. · During trips, the BHA can accumulate cuttings that will potentially ball it. Recommend circulating for a short period to circulate up any formation that may have adhered to the BHA or bit during the trip. · Bit balling was observed on W. McArthur River #7 it is recommended that sweeps with 7-10% by volume of Drilzone be used if this is encountered. Confidential Mí SWACCp,:,"£'.;;y ;_--:~.;~;~;:;rt:~~~t;,~¡-;~¿,~:"""" . Mi SWACJ;t~;~~>- .~~c::~::;:;:!~~~$~. . -.- >.> .'.,,- i- . ; ~ Mud Proposal "West Foreland #2" Cook Inlet Nabors 129 Prepared by: Pat Young Last Revision: 07/27/04 Section 2 - Interval Discussions (100'- 3,000') Depth Interval 17 %" Surface Hole (100-3,000) run 10 %" csg. Drilling Fluid System Fresh Water Spud Mud Key Products MI Gel, Gelex, Caustic, DUO-VIS, Tannathin, Barite,Drilzone Solids Control Shakers, Centrifuge, and Magnets Large gravel sizes can cause hole-cleaning problems. Sticky clays can slow ROP from bit and BHA balling. ~w._I-I-:_- :- 4.l-e _I_y_ __u _1_- 1-- - ___1-1_- ~ CU.lUIII!::I1I1 UI ""ICI ~ IIIClY ClI~U UIt: CI t-'IUUIlt:III. Potential Problems Interval Drilling Fluid Properties Mud Wt. (ppg) FLOW LINE Initial 9.0-9.5 +-200 45-70 NC <1500 9.0-9.5 Recommended Solids Control Equipment De-Sander Initial Spud with 84's/84's, Gather data on flow rates, ROP's, and fluid loss. Change screens accordingly Run continuously @ 75' of head minimum. Recommend %" Apex's if available. Gather data to determine discharge rates and weight. Run continuously @ 90' of head minimum. Recommend 1/2" Apex's. Gather data to determine discharge rate and weight. Run as needed to control weight at or below 9.5 Ib/gal. Shaker Screens Mud Cleaner/De-Silter Centrifuge Confidential Mi SWAC~::'_,;;~;'jW <":"2_:::~:::~:"_:'~::'~:~.:~~~:~¿~)~v,~\\, . . Forest Oil Corp.,WF#2 West Forelands Pad #1, West Foreland,West Cook Inlet, Alaska PROPOSAL LISTING Page 5 Wellbore: West Foreland#2 (8) Wellpath: WF #2 Verso #8 Date Printed: 17-Aug-2004 r&l. BAKER HUGHES INTEQ Comments MDrftl ITVDrftl 3000.00 I 3000.00 3250.00 I 3249.68 3350.00 I 3349.30 3600.00 I 3598.99 5300.00 5298.98 7627.04 7378.43 7978.24 7620.00 9516.39 8678.00 10631.48 9445.QO Eastfftl O.OOE 7.71E 13.87E 21.58E 21.58E 149.84W 198.70W 412.71W 567.86W Northrftl O.OON 7.71N 13.87N 21.58N 21.58N 899.28N 1149.47N 2245.26N 3039.65N Comment Beqin Nudqe End Nudqe Beqin Drop End Drop KOP EOC Tqt#1 WF#2 Anomalv A WF#2 TD WF#2 Hoie Sections Diameter Start Start Start Start End End End End\nEast[ft] Wellbore [inl MDfftl TVDfftl North[ftl Eastfftl MOfftl TVOfftl Northfftl 24.000 0.00 0.00 O.OON O.OOE 100.00 100.00 O.OON O.OOE West Foreland#2 (8) 143/4 100.00 100.00 O.OON O.OOE 3000.00 3000.00 O.OON O.OOE West Foreland#2 (8) 97/8 3000.00 3000.00 O.OON O.OOE 10651.19 3053.69N 570.60W West Foreland#2 (8) Casings Name Top Top Top Top Shoe Shoe Shoe Shoe Well bore MOrftl TVOrftl Northrftl Eastfftl MOrftl TVOfftl North[ftl Eastfftl 20.000in Casinq 0.00 0,00 O.OON O,OOE 100.00 100.00 O.OON O.OOE West Foreland#2 (8) 10 3/4in Casinq 100.00 100.00 Q.OON O.OOE 3000.00 3000.00 O.OON O.OOE West Foreland#2 (8) 7 5/8in Casinq 0.00 0.00 O.OON O.OOE 10651.19 9458.56 3053.69N 570,60W West Foreland#2 (8) ITargets Name Northfftl Eastfftl TVOfftl Latitude Lonqitude Eastinq Northinq Anomaly A WF#2 2245.26N 412.71W 8678.00 N60 46 15.6687 W151 44 0.7026 190099.00 2477837.00 2-J ul-04 Tgt#1 WF#2 - 1127.48N 238.18W 7620.00 N60 46 4.6614 W151 43 57.1881 190244.00 2476715.00 2-Jul-04 Tgt TO WF#2 3056.20N 539.13W 9445.00 N60 46 23.6543 W151 44 3.2488 189994.00 2478651.00 2-Jul-04 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Datum #1 90.0ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 349.58 degrees Bottom hole distance is 3092.24 Feet on azimuth 349.42 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated rl:íi. BAKER HUGHES INTEQ Scale 1 em = 10 ft -160 -140 -120 -100 . . Forest Oil Corp. location: West Cook Inlet, Alaska Field: West Foreland Installation: West Forelands Pad #1 Slot: WF#2 Well: West Foreland#2 Wellbore: West Foreland#2 (8) -80 -20 East (feet) -> o -60 -40 I West Foreland #1/ 9200 8300 7400 6800 6200 5600 4700 4100 2900 2000 500 ~. 6200 \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ J // / 3200 ~ 500 20 40 5900 5600 3500 ...,,<:YO:"- , .,,(.";l"'.""~~' ¡"'if.. ~ .~~'. ,/,"."',. . ~_'·t \~~:.!~; Created by: Planner Date plotted: 17 -Aug-2004 Plot reference is West Foreland#2 (8). Ref wellpath is WF #2 Verso #8. Coordinates are in feet reference WF#'2.. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Oatum. Rig Datum: Oatum #1 Rig Datum to Mean Sea Level: 90.00 ft. Plot North is aligned to TRUE North. 60 100 140 80 120 320 300 280 260 240 220 200 180 160 ^ . Z 0 140 ;:¡. ::r - ;' 120 !. - 100 80 60 40 20 (f) 0 (") ¡» CD (") -20 3 II ..... 0 -40 ;::I:' "íill BAKER HUGHES INTEQ . Scale 1 em = 100 ft -1800 -1600 -1400 -1200 -1000 . Forest Oil Corp. Location: Field: Installation: West Cook Inlet, Alaska West Foreland West Forelands Pad #1 Slot: WF#2 Well: West Foreland#2 Well bore: West Foreland#2 (8) -800 -600 East (feet) -> -400 ~oo 0 400 200 ¡west Foreland#21 0 \ \ \ \ 9200 8900 8600 8300 8000 7700 Created by : Planner Date plotted: 17-Aug-2004 Plot reference is West Foreland#2 (8). Ref wellpath is WF #2 Vers, #8. Coordinates are in feet reference WF#2. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to Mean Sea Level: 90.00 ft. Plot North is aligned to TRUE North. 600 800 1400 1000 1200 3400 3200 3000 2800 2600 2400 2200 2000 1800 ^ . Z 0 1600 ;¡ ::r - ¡- MOO !. - 1200 1000 800 600 400 (f (") 200 Q) ãi (") 0 3 II .... 0 0 -200 ;::> - - 0 LO -500 C\ II E ü 0 Q) ro ü (J) 500 1000 1500 2000 2500 3000 - 3500 - Q) .æ - .s:: 4000 - Co Q) C 4500 C'O (.) :e 5000 Q) > Q) 5500 ::J a.. l- I V 6000 6500 7000 7500 BOOO B500 9000 9500 10000 . . f&i. BAKER HUGHES INTEQ A 20.000in Casing Forest Oil Corp. Location: West Cook Inlet, Alaska Field: West Foreland Installation: West Forelands Pad #1 Slot: WF#2 Well: West Foreland#2 Well bore: West Foreland#2 (8) Created by: Planner Date plotted: 17 -Aug-2004 Plot reference is West Foreland#2 (B). Ref wellpath is WF #2 Verso #8. Coordinates are in feet reference WF#2. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Oatum: Datum #1 Rig Oatum to Mean Sea Level: 90.00 ft, Plot North is aligned to TRUE North. East (feet) -> Scale 1 em = 100 ft -800 -600 -400 -200 o 200 j L TO WF#2 \. Tgt TO WF#2 2-Jul-04 10 3/4in Casing Begin Nudge 4.00 End Nudge Begin Drop End Drop PLOT NORTH IS ALIGNED TO TRUE NORTH KOP 4.00 8.00 DLS: 2.00 deg/1 OOft 16.00 / 20.00 24.00 28.00 32.00 38.00 42.00 46.00 EOC Tgt#1 WF#2 - 2-Jul-04 Tgt#1 WF#2 Anom"yA WF#2 2-J~'Y A WF#2 " TO WF#2 . Tgt TO WF#2 2-Jul-04 3200 3000 2800 2600 2400 Anomaly A WF#2 Anomaly A WF#2 2-Jul-04 2200 2000 1800 ^ I 1600 ~ ::+ :T 1400 ;; CD - - 1200 1000 800 600 400 200 (J) (") End Drop ID Begin Drop KOP ã) l End Nu~e ./ 0 Begin Nu ge ì í (") 1 0 3/4in Casing 3 20.000in Casing II I -200 0 [ 0 ;::. Tgt#1 WF#2 - 2-Jul-04 . -500 -0 500 1000 1500 2000 2500 3000 3500 Seale 1 em = 250ft Vertical Section (feet) -> Azimuth 349.58 with reference 0.00 N, 0.00 E from WF#2 . . Forest Oil Corp. WF #2 Verso #8, West Foreland#2 (8) WF#2, West Forelands Pad #1 CLEARANCE LISTING Page 1 Date Printed: 17-Aug-2004 West Foreland, West Cook Inlet, Alaska rji. BAKER HUGHES INTEQ Ellipse separations are reported ONLY if BOTH wells have uncertainty data Ellipse error terms are CORRELATED across ties between tools of the SAME CLASS Cutoff is calculated on CENTRE to CENTRE distance Summary data uses Closest Approach clearance calculation for all minima Hole size/Casinç¡s are NOT included Hole size/Casinç¡s are NOT subtracted from Centre-Centre distance Ellipses scaled to 2.00standard deviations. Closinç¡ Factor Confidence limit of 99.80% Errors on Ref start at Slot Permanent Datum (0.00) Report uses Revised: (D-C)/E Factor Calculation Wellbore Name 'vA.Jest Fûreland#2 (8) I Created I 17 -Auq-2004 I ;:s~ ~:~~~~ I I I -f"\U\..l-¿'UU~ Well Name West Foreland#2 I Government ID I Last Revised 30-Apr-2004 Slot Name WF#2 I Grid Northino 12475581.6250 I Grid Eastino 190452.3700 I Latitude N60 45 53.5586 I Lonoitude W151 43 52.3930 I North 886.32N lEast 571.37W Installation Name West Forelands Pad #1 I Eastino I Northino 191000.219~ I Coord Svstem Name I North Alionment 2474680.574~ AK-4 on NORTH AMERICAN DATUM 1927 datu~ True Field Name West Foreland I Eastino I North ino 191000.2191 I Coord Svstem Name I North Alionment 2474680.574~ AK-4 on NORTH AMERICAN DATUM 1927 datu~ True Clearance Summary Offset Offset Offset WellName Wellbore Slot Offset Structure Minimum Distance 1ft] MD[ft] Diverging Ellipse From[ft] Separation 1ft] 1649.96 5700.0C Ellipse MD[ft] Clearance Factor Clearance MD[ft] West Foreland #1 West Foreland #1 WF#1 West Forelands Pad #1 31.80 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 90.0ft 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) Casings Included Prepared by Baker Hughes Incorporated . . Forest Oil Corp. CLEARANCE LISTING Page 2 r&l. WF #2 Verso #8, West Foreland#2 (8) Date Printed: 17 -Aug-2004 BAKER HUGHES WF#2, West Forelands Pad #1 West Foreland, West Cook Inlet, INTEQ Alaska Clearance Data 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] Ideal Iftl 0_00 0.00 O.OON O.OOE West Foreland 0.09 0.09 1.05S 39.99W -91.5 38.17 #1 100.00 100.00 O.OON O.OOE West Foreland 100.51 100.51 0.59S 39.31W -90,9 37.48 #1 200.00 200.00 O.OON O.OOE West Foreland 200.40 200.39 0.06N 38.08W -89.9 37.02 #1 300.00 300.00 O.OON O.OOE West Foreland 300.27 300.25 0.31N 37.16W -89.5 36.10 #1 400.00 400.00 O.OON O.OOE West Foreland 400.23 400,21 0.43N 36.49W -89.3 35.43 #1 500.00 500.00 C.CON D.OOE \^Jest Foreland 500.1 9 500.17 O.48N ~r n"':l\AJ on ... 34.86 oJio..J.õ;JLVV -UV'.L #1 600.00 600.00 O.OON O.OOE West Foreland 600_15 600.12 0.46N 35.45W -89.3 34.39 #1 700.00 700.00 O_OON O.OOE West Foreland 700.10 700.0e 0.41N 35.17W -89.3 34.11 #1 800.00 800.00 O.OON O.OOE West Foreland 800.13 800.11 0.38N 34.95W -89.4 33.89 #1 900.00 900.00 O.OON O.OOE West Foreland 900.15 900.12 0.63N 34.61W -89.0 33.56 #1 1000.0e 1000.0e O.OON O.OOE West Foreland 1000.12 1000,0£ 0.94N 34.26W -88.4 33.21 #1 1100.0C 1100.0e O.OON O.OOE West Foreland 1100.0e 11 OO,O~ 1.19N 34.03W -88.0 32.99 #1 1200.0e 1200.0e O.OON O.OOE West Foreland 1200.1< 1200.11 1.66N 33.83W -87.2 32.81 #1 1300.0e 1300.0e O.OON O.OOE West Foreland 1300.19 1300.1€ 2.24N 33.39W -86.2 32.40 #1 1400.00 1400.0e O.OON O.OOE West Foreland 1400.07 1400.0:3 2.90N 33.01W -85.0 32.07 #1 1500.0e 1500.0e O.OON O.OOE West Foreland 1500.08 1500.0~ 3.69N 32.81W -83.6 31.95 #1 1600.0e 1600_0e O.OON O.OOE West Foreland 1600,O~ 1600.01 4.53N 32.57W -82.1 31.82 #1 1649.9€ 1649.9€ O.OON O_OOE West Foreland 1650.0e 1649.96 4.96N 32.49W -81.3 31.80 #1 1700.0e 1700.0e O.OON O.OOE West Foreland 1700.0e 1699_9€ 5.43N 32.46W -80.5 31.85 #1 1800,Oe 1800.0e O.OON O.OOE West Foreland 1800.0L 1799.98 6.14N 32.45W -79.3 31.96 #1 1900.0e 1900.0e O.OON O.OOE West Foreland 1900,0< 1899.99 6.95N 32.31W -77.9 31.99 #1 2000.00 2000.0e O.OON O,OOE West Foreland 2000.01 1999.9~ 8.15N 32.10W -75.8 32.05 #1 2100.0C 2100.0e O.OON O.OOE West Foreland 2100_0e 2099.9:3 9.32N 31.95W -73.7 32.21 #1 2200.0C I O.OOE West Foreland 2199.9:3 2199.8€ 10.33N 32.00W -72.1 32.56 2200.0C O.OON #1 2300.0C 2300.0e O.OON O.OOE West Foreland 2299_ge 2299.82 11.54N 32.12W -70.2 33.07 #1 2400.0C 2400.0e O.OON O.OOE West Foreland 2400.01 2399,92 12.65N 32,051 -68.5 33.40 #1 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 90.0ft 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) Casings Included Prepared by Baker Hughes Incorporated . . Forest Oil Corp. CLEARANCE LISTING Page 3 J&I. WF #2 Verso #8, West Foreland#2 (8) Date Printed: 17-Aug-2004 BAKER HUGHES WF#2, West Forelands Pad #1 West Foreland, West Cook Inlet, INTEQ Alaska Clearance Data 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] [deal rftl 2500.0C 2500.0C O.OON O.OOE West Foreland 2499.92 2499.82 13.39N 32.13W -67.4 33.74 #1 2600.0C 2600.0C O,OON O.OOE West Foreland 2600.02 2599.9~ 14.14N 32.17W -66.3 34.08 #1 2700.0C 2700.0C O.OON O.OOE West Foreland 2699.97 2699.8e 14.69N 32.20W -65.5 34.33 #1 2800.0C 2800.0C O.OON O.OOE West Foreland 2800.11 2800.01 15.20N 32.18W -64.7 34.52 #1 2900.0C 2900.0C O.OON O.OOE West Foreland 2900.1e 2900.0e 15.76N 31.87W -63.7 34.49 #1 3000.0C 3000.0C O.OON O.OOE West Foreland 3000.21 3000,11 16.34N 31.30\i\l -62.4 34.24 #1 3100.0C 3099.9E 1.23N 1.23E West Foreland 3100.11 3100.0C 17.07N 30.71W -108.6 34.93 #1 3200.0C 3199,8< 4.93N 4.93E West Foreland 3200.11 3200.0C 17.83N 30.14W -114.8 36.64 #1 3250.0C 3249.6e 7.71N 7.71 E West Foreland 3249.99 3249.8e 18.23N 29.76W -119.2 38.19 #1 3300.0C 3299.49 10.79N 10.79E West Foreland 3299.79 3299.67 18.69N 29.45W -123.8 40.28 #1 3350.0C 3349.3C 13.87N 13.87E West Foreland 3349.59 3349.4e 19.13N 29.19W -128.0 42.66 #1 3400.0C 3399.1 e 16.65N 16.65E West Foreland 3399.4e 3399.32 19.48N 28.98W -131.4 44.98 #1 3500,OC 3499.01 20.35N 20.35E West Foreland 3499.4< 3499.32 20.07N 28.42W -135.3 48.04 #1 3600.0C 3598.99 21.58N 21.58E West Foreland 3599.39 3599.2E 20.86N 27.82W -90.8 48.68 #1 3700.0C 3698.99 21,58N 21.58E West Foreland 3699.2e 3699.1e 21.70N 27.44W -89.9 48.29 #1 3800.0C 3798,99 21,58N 21,58E West Foreland 3799.21 3799.07 22.59N 27.21W -88.8 48.07 #1 3900.0C 3898.99 21.58N 21.58E West Foreland 3899.09 3898.95 23.53N 27.18W -87.7 48.07 #1 4000.0C 3998.99 21.58N 21.58E West Foreland 3999.01 3998.8E 24.52N 27.34W -86.6 48.28 #1 4100.0C 4098.99 21.58N 21.58E West Foreland 4099.02 4098.87 25.54N 27.51W -85.4 48.52 #1 4200.0C 4198.99 21.58N 21.58E West Foreland 4199.12 4198.ge 26.36N 27.51W -84.4 48.59 #1 4300.0C 4298,99 21.58N 21.58E West Foreland 4299.0L 4298.8e 27.48N 27.51W -83.1 48.71 #1 4400.0C 4398,99 21.58N 21.58E West Foreland 4398.99 4398.82 28.75N 27.66W -81.7 49.03 #1 4500.0C 4498.99 21.58N 21.58E West Foreland 4499.0E 4498.8E 30.04N 27.71W -80.3 49.28 #1 4600.0C 4598.9' 21.58N 21.58E West Foreland 4599.07 4598.8E 31.62N 27.60W -78.5 49.46 #1 4700.0C 4698.9' 21.58N 21.58E West Foreland 4698.9< 4698.7~ 33.25N 27.64W -76.7 49.85 I #1 4800.0C 4798.9l 21.58NI 21.58E West Foreland 4799.04 4798.82 34.71 N 27.68W -75.1 50.25 #1 I All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 90.0ft 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) Casings Included Prepared by Baker Hughes Incorporated . . Forest Oil Corp. CLEARANCE LISTING Page 4 r&l. WF #2 Verso #8, West Foreland#2 (8) Date Printed: 17 -Aug-2004 BAKER HUGHES WF#2, West Forelands Pad #1 West Foreland, West Cook Inlet, INTEQ Alaska Clearance Data 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] Ideql Iftl 4900.0C 4898.9S 21.58N 21.58E West Foreland 4898.9~ 4898.72 36.31 N 27.65W -73.3 50.66 #1 5000.0C 4998.9S 21.58N 21.58E West Foreland 4998.77 4998.53 37.82N 27.98W -71,9 51.43 #1 5100.0C 5098.9S 21.58N 21.58E West Foreland 5098.97 5098.73 38,65N 28.39W -71.1 52.08 #1 5200.0C 5198.9S 21.58N 21.58E West Foreland 5198.91 5198.66 39.27N 28.72W -70.6 52.59 #1 5300.0C 5298.99 21.58N 21.58E West Foreland 5299.01 5298.7E 40.02N 29.01W -70.0 53.11 #1 5400.0C 5398.9€ 23.29N 21.25E \^v'est Fûíeland 5399,O€ 5398.82 40.88N ",n. """AI ...59.7 52.52 "''''.u I vv #1 5500.0C 5498.82 28.43N 20.24E West Foreland 5498.72 5498.4E 41.82N 29.29W -63.9 50.58 #1 5600.0C 5598.4< 36.98N 18,57E West Foreland 5598.31 5598.0< 42.39N 30.02W -72.6 48.17 #1 5700.0C 5697.6S 48.94N 16.24E West Foreland 5697.37 5697.1C 42.76N 31.12W -86.3 47.03 #1 5800.0C 5796.4~ 64.30N 13.24E West Foreland 5796.33 5796.0~ 43.11 N 32.29W -103.6 49.49 #1 5900.0C 5894.61 83.02N 9.58E West Foreland 5894.63 5894.34 43.63N 33.37W -120.9 57.56 #1 6000.0C 5992.0< 105.10N 5.27E West Foreland 5992.5~ 5992.2~ 44.48N 34.44W -134.9 71.73 #1 6100,OC 6088.63 130.50N 0.31E West Foreland 6089.6E 6089.36 45.51 N 35.08W -145.4 91.34 #1 6200.0C 6184.2~ 159.19N 5.30W West Foreland 6186.0E 6185.7~ 46.73N 35.45W -152.9 115.71 #1 6300.0C 6278.8C 191.14N 11.54W West Foreland 6281.07 6280.75 48.08N 35.53W -158.3 144.35 #1 6400.0C 6372.1 ~ 226.32N 18.41W West Foreland 6373.87 6373.54 49.15N 35.72W -162.2 177.29 #1 6500.0C 6464.2C 264.66N 25.90W West Foreland 6467.27 6466.93 50.09N 36.74W -164.9 214.13 #1 6600.0C 6554.8:: 306.14N 33.99W West Foreland 6559.5~ 6559.1 S 51.48N 37.63W -166.9 253.99 #1 6700.0C 6643.92 350.69N 42.70W West Foreland 6650.2E 6649.8S 53.11 N 38.07W -168.7 296.95 #1 6800.0C 6731.3E 398.27N 51.99W West Foreland 6738.6E 6738.27 54.88N 38.22W -170.0 343.01 #1 6900.0C 6817.0S 448.82N 61.86W West Foreland 6823.6< 6823.2:: 56.42N 38,08W -171.2 392.44 #1 7000.0C 6900.9~ 502.27N 72.30W West Foreland 6905.8:: 6905.42 57.46N 37.86W -172.1 445.44 #1 7100.0C 6982.87 558.56N 83.29W West Foreland 6989.5E 6989.1 E 58.38N 38.05W -172.8 501.53 #1 7200.0C 7062.73 617.62N 94.83W West Foreland 7065.61 7065.1 S 59.08N 38.45W -173.3 560.66 #1 7300.0C 7140.4< 679.38N 1 06.89W West Foreland 7147.4~ 7147.0:: 59.51 N 38.66W -173.8 622.93 #1 7400.0C 7215.9C 743.77N 119.47W West Foreland 7230.02 7229.5E 60.86N 38.82W -174.3 687.07 #1 All data is in Feet unless otherwise stated Coordinates are from Slot and TVDOs are from Rig ( Datum #1 90.0ft above Mean Sea Level) Reference MOos are from Rig, Offset MO's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (10) Casings Included Prepared by Baker Hughes Incorporated . . Forest Oil Corp. CLEARANCE LISTING Page 5 '&1. WF #2 Verso #8, West Foreland#2 (8) Date Printed: 17 -Aug-2004 BAKER HUGHES WF#2, West Forelands Pad #1 West Foreland, West Cook Inlet, INTEQ Alaska Clearance Data 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] [deal [ftl 7500.0C 7289.03 810.70N 132.541J1J West Foreland 7302.6£ 7302.25 62.29N 38.96W -174.6 753.63 #1 7600.0C 7359.7i 880.10N 146.091J1J West Foreland 7370.71 7370.25 63.39N 38.94W -174.9 823.04 #1 7627.0~ 7378.43 899,28N 149.841J1J West Foreland 7389.65 7389.1 £ 63.64N 38.90W -175.0 842.3C #1 7700.0C 7428.62 951.25N 159.991J1J West Foreland 7438.5C 7438.0~ 64.20N 38.76W -175.3 894.61 #1 7800.0C 7497.4C 1022.49t\ 173.901J1J West Foreland 7508.4€ 7507.9S 64.98N 38.54W -175.7 966.36 #1 79ÛÛ,ÛC 7566.1 S 1û93.73i\' 187.81W West Foreiand 7578.65 7578.1f 65.79N 38.45Vv -i76.û i038.ûE #1 8000.0C 7634.97 1164.97t\ 201.731J1J West Foreland 7648.42 7647.9i 66.60N 38.52W -176.3 1109.7ê #1 8100.0C 7703.75 1236.21 t\ 215.641J1J West Foreland 7716.11: 7715.7C 67.35N 38.67W -176.5 1181.52 #1 8200.00 7772.5< 1307.46t\ 229.551J1J West Foreland 7782.17 7781.6ê 67.86N 39.15W -176.7 1253.4i #1 8300.0C 7841 .32 1378.70t\ 243.471J1J West Foreland 7849.11 7848.62 68.14N 39.95W -176.8 1325.55 #1 8400.0C 7910.1 C 1449.94t\ 257.38W West Foreland 7911.8< 7911.34 68.28N 40.68W -176.9 1397.82 #1 8500.0C 7978.8S 1521.18t\ 271.29W West Foreland 7970.57 7970.07 68.08N 41.38W -177.0 1470.47 #1 8600.0C 8047.67 1592.42t\ 285.211J1J West Foreland 8038.55 8038.0~ 67.52N 42.28W -177.1 1543.43 #1 8700.0C 8116.4€ 1663.66t\ 299.12W West Foreland 8127.63 8127.11 67.44N ' 43.47W -177.2 1615.8€ #1 8800.0C 8185.2i 1734.90t\ 313.031J1J West Foreland 8210.4C 8209.87 68.23N 44.61W -177.3 1687.6C #1 8900.0C 8254.02 1806.14t\ 326.951J1J West Foreland 8273.95 8273.41 68.95N 45.40W -177.3 1759.23 #1 9000.0C 8322.81 1877.38t\ 340.861J1J West Foreland 8335.17 8334,62 69.37N 46.06W -177.4 1831.2C #1 9100.0C 8391.5S 1948.62t\ 354.77W West Foreland 8393.8i 8393.29 69.39N 46.73W -177.5 1903.5ê #1 9200.00 8460.37 2019.86t\ 368.691J1J West Foreland 8483.3C 8482.75 69.61 N 47.97W -177.5 1975.8i #1 9300.0C 8529.1€ 2091.10t\ 382.601J1J West Foreland 8556.6S 8556.12 70.44N 48.88W -177.6 2047.4ê #1 9400.0C 8597.9< 2162.34t\ 396.511J1J West Foreland 8623.0< 8622.46 71.25N 49.10W -177.7 2119.17 #1 9500.0C 8666.73 2233.58t\ 410.431J1J West Foreland 8686.83 8686.25 71.91 N 49.05W -177.8 2191.0~ #1 9516.3S 8678.0C 2245.26t\ 412.711J1J West Foreland 8698.21 8697.63 72.01 N 49.04W -177.8 2202.82 #1 9600.00 8735.51 2304.82t\ 424.341J1J West Foreland 8750.0C 8749.42 72.40N 48.93W -177.8 2263.0e #1 9700.0C 8804.2S 2376.06t\ 438.261J1J West Foreland 8818,75 8818.17 72.80N 48.90W -177.9 2335.25 #1 9800.0C 8873.0e 2447.30t\ 452.171J1J West Foreland 8892.7j 8892.16 73.31 N 49.05W -178.0 2407.33 #1 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 90.0ft 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) Casings Included Prepared by Baker Hughes Incorporated . . Forest Oil Corp. WF #2 Verso #8, West Foreland#2 (8) WF#2, West Forelands Pad #1 CLEARANCE LISTING Page 6 Date Printed: 17-Aug-2004 West Foreland, West Cook Inlet, Alaska r&l. BAKER HUGHES INTEQ Clearance Data 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] rdeQ] fft] 9900.0C 8941.8E 2518.541\ 466.08W West Foreland 8955.57 8954.9E 73.74N 49.33W -178.0 2479,3S #1 10000.0C 9010.65 2589.781\ 480.00W West Foreland 9027.7£ 9027.2C 74.08N 49.77W -178.1 2551.55 #1 10100.0C 9079.42 2661.031\ 493.91W West Foreland 9116.9E 9116,3E 74.93N 50.44W -178.1 2623.37 #1 10200.0C 9148.21 2732.261\ 507.82W West Foreland 9188.7S 9188.17 75.87N 51.13W -178.2 2694.9- #1 10300.0C 9217.0C 2803.511\ 521.74W West Foreland 9245.7E 9245.15 76.51 N 51.78W -178.2 2766.61 #1 10400.0G 9285.71: 2874.75N 535.65Vv \^/est Fore!and 9266.0C 9265.39 7ê.67N 52.03\^J -178.2 2838.9C #1 10500.0C 9354,5E 2945.991\ 549.56W West Foreland 9266.0C 9265.39 76.67N 52.03W -178.2 2912.7E #1 10600.0C 9423.35 3017.231\ 563.48W West Foreland 9266.0C 9265.39 76.67N 52.03W -178.2 2988.15 #1 10631.41: 9445.0C 3039,651\ 567.86W West Foreland 9266.0C 9265.39 76.67N 52.03W -178.2 3012.17 #1 Offset Well bore Survey Tool Programs I MDfft] Well I Wellbore I Survev Name d Survev Tool I Error Model West Foreland #1 West Foreland #1 Gvro<0-9266'> 9266.0 Level Rotor Gvro Standard All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 90.0ft 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) Casings Included Prepared by Baker Hughes Incorporated . . Well bore Name West Foreland#2 (7) I Created 2-Jul-2004 PROPOSAL SUMMARY Page 1 Wellbore: West Foreland#2 (7) Well path: WF #2 Verso #7 Date Printed: 2-Jul-20 r&l. BAKER HUGHES INTEQ Forest Oil Corp.,WF#2 West Foreland, West Foreland,West Cook Inlet, Alaska Well Name West Foreland#2 I Government ID I Last Revised ,30-Apr-2004 101-.. ~IUL Name WF#2 I Grid Northing I Grid Easting 2475578.0000 190391.0000 lEast 632,62W Installation Name West Foreland Easting No . 191000.2193 (@ 74680.5740 ~ /:orthing 0.2193 2474680.5740 Coord System Name North Alignment AK-4 on NORTH AMERICAN DATUM True t/ 1927 datum Field Name West Foreland Coord System Name North Alignment AK-4 on NORTH AMERICAN DATUM True 1927 datum 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 90.0ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 351.13 degrees Bottom hole distance is 3098.52 Feet on azimuth 351.13 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . Mi SWACQ~{~j~4¢" _m_<:~~~-;;~;~Z'~'/'f¡· . '~)<:':}i>',',. /'::<>""";'_::;1/:«'; ." " . ",;,,) ", ~ ". Mud Proposal "West Foreland #2" Cook Inlet Nabors 129 Prepared by: Pat Young Last Revision: 07/27/04 Section 2 -Interval Discussions Interval: 1 00' - 3,000' Continued Recommended Initial Spud Mud Formulation Soda Ash M-I Gel 0.2 Ib/bbl 20 Ib/bbl (Add to the make-up water and allow to hydrate as long as is possible prior to drilling) add prior to spud to increase the funnel viscosity to 150-200 sec/quart. 0.5 Ib/bbl. for alkalinities As needed for rheological properties As needed for rheological properties. Gelex Caustic Duo-Vis Tannathin Surface Interval Treatment Procedures · Gravel may cause hole-cleaning problems. If larger than normal gravel is encountered be prepared to increase funnel viscosity from 200 - 250 sec/qt. Have GELEX available for an immediate response to this issue. · Maintain flow rates of at least 500 gpm and stay below an effective 150 ft/hr ROP to ensure hole cleaning. Reduce pump rates immediately if packing off occurs. · Adjust rheology, ROP, pipe rotation speed (60 - 80 rpm), pipe running speeds and pump rates as needed to balance hole cleaning and ECD. · Drill ahead watching for wellbore instability problems. Any fluid weight adjustments should be performed in 0.1- 0.2 Ib/gal increments if absolutely necessary. · Sticky clays can slow ROP from bit and BHA balling. Add Drilzone (at 1 - 2%) and Nut Plug (as allowed by MWD tools) to minimize clay to metal sticking only if needed. · To help ensure good cement to surface after running the casing condition mud to a funnel viscosity of + /_ 55 - 100 sec/qt (YP at 15 - 17) prior to cementing the casing. Have water on hand to ensure the desired rheologies can be achieved. · Recommend after reaching TO make short trip and go to a one pit system. Dispose of all excess waterbase mud except for number one active. · Drill out 13 3/8" casing with waterbase mud and perform F.I.T. then displace to Versadril. Confidential Mi SWACQ!:è:%~Z;jjW -,<_·:_':.'::';:~':~~t~-~:~~~~~,::~~t¡,'}1¿' . Virtual Hydraulics Modeling r=J GeOlll!try MD/TW(ft) CsglHQa On: 10cA, \:::=a2'.00( I ..- 22.00( ~.';:S ~.~ ¡ ~ ~ , L- , -, , : It é ¡ "", ~ ~ .~ 3000 17·1/2 Confidential VIRTUAL HYDRAU UCSB> SnapShot ©1996-2002 M· l.L.c.. PJI ~ghls ~erved Depth 1ft) Densly (1bJga~ 9r 94 \ 96 9( 500 ECD 1()(x) 1500 ESD 200) 2500 ;CD-I-Cu' 3(0) 3500 ~ ... ,. . .... ~ ..... 10.0 ¡ ~ LS;'P yp . Mud Proposal "West Foreland #2" Cook Inlet Nabors 129 wo: 3000 1VD: 3000 Bit Size: 17.5 il\ Dale: &':JOI2OO4 Prepared by: Pat Young Last Revision: 07/27/04 Oparakr: Faest Oil Well Nan.: W. Faela1d#2 Locatioo: CW< irJe! Camy: AV(ftIrrin) HoleCleanlnd 62 ~5IVG G F PI Q1 Ann \ PV,VP.LSVP Terrp(°F) 10 2¡' M '¡' (0 6~ ,6f , \ DS :J Pressure Loss (%) o 25 50 75 "';"¡;", n..;&c:t....,.. ~;;¡¡_...~ , 100 DRILLfoIG FWD Water-Based Mud M.GWelltt 9.21tig11 Tes/Temp 120·F SYSTEM DATA RaovRaie 6OO~in RoP 751t111" RPM 120 r¡tn WOB 5 Klb 1FA .94 in' PR~RELQ$$(p$Q McxIfied PotærLaw DriB S!r~ 220 Máø" 350 Bit 350 BitOn'OIf 20 And... 42 SuiaœEqjp 19 U·TLl:ePre5$ 49 TØaiSysÉItI 11J51 ESD ECD <C1k CsgShœ 9.29 9,47 9.79 1D 9.31 9.58 9.811 VfD{. Veion 2.7 File ..FtÆS1W!.Mœ Mi SWACC,.tr'r,w ,,-----~,_""'__~~~"::~£it~f:'£~:g~;~~:r:¡~-;p;';-,c> . . Mi SWACI;t¡;~(,Ø'" "__~_':::::~~~,;f~~~~ffi'};;>'f< .,. Mud Proposal "West Foreland #2" Cook Inlet Nabors 129 Prepared by: Pat Young Last Revision: 07/27/04 Section 2 - Interval Discussions Interval: 100' - 3,000' Continued Virtual Hydraulics - Hole Cleaning Model ~ Hole Cleaning I --+--- '. ' i i~ , --........ ROP 50. ftlhr ROP 100. ftlhr ROP 150. ftlhr ROP 200. ftlhr 1.000 Ipoor Hole iClea~ing I , -... 0.750 >< C) "C .5 C) .5 0.500 r:: ctI ~ (.) C) Õ :c 0.250 I ¡Fair Hole ?Iean¡n i ! ! I i -r--- I i I ¡ .--- , : I i i i i I I Holel CleaLing I i I I r' ~ I T-t--. --¡- ¡ ,I --+-- l -- ! ---r--- I j: ¡ . i I ---+--.l...- ¡ -. j '~', i r - ! ~! ¡! ',~ ___-L_~~+--i-=~~~ry-GoodiHoie¡c,eaning i----~---t--+-t---+---; I ~ ! i Ii : Ii! ! 1 Iii I ¡ ----L ...-j....- ....L--L-------- ..- -·--f---t-t-------+--i--r---j------!---+---t----i-- 380.0 400.0 500.0 I I 600.0 700.0 VIRTUAL HYDRAULICS® Flow Rate (gal/min) - ¡-- Confidential Mi sWAcg~;;;;~;~'#i '-. '.-..~"' "','-"'~~:;:S:;'._:;;;~:~;_,$09" . . Mud Proposal "West Foreland #2" Cook Inlet Nabors 129 Prepared by: Pat Young Last Revision: 07/27/04 Section 3 - Interval Discussions (3,000 - 10,682') Depth Interval 3,000' - 10,682' 97/8" Production hole run 7 In. casing Drilling Fluid System 70 /30 VERSDRIL (MAP CO 200) Key Products MAPCO 200,Versamul, Versacoat, HRP, Lime ,IMG-400, CaCI2, Barite Solids Control Shakers, Desander, Mud Cleaner, Centrifuge Adequate hole cleaning, Hole integrity, Screen blinding, Well bore breathing/loss c:ir~.ulation Interval Drilling Fluid Properties Potential Problems 3,000- 10,682 9.2 -9.5 38-50 15-18 15-20 6-8 70:30 30,000 >500 Recommended Initial Mud Formulations for making Of Versadril MAPCO 200 IMG 400 Lime VERSACOAT HF VERSAMUL CaCI2 Barite HRP Water (bbl) 0.620 bbl. 4.0 Lbs. 5.0 Lbs. 2.5 Lbs. 7.0 Lbs. 33 Lbs. 71 Lbs. 0.75 Lbs. 0.261 Bbl. Confidential Mi SWACQ.'?;";;'fi' --:~:-"~::-:;_'~:~~~;~~:i;~,;~~,-,!i"> . . Mud Proposal "West Foreland #2" Cook Inlet Nabors 129 Prepared by: Pat Young Last Revision: 07/27/04 Section 3 - Interval Discussions Direct Displacement Recommendation of Waterbase mud to Versadril · After running casing and circulating with waterbase, pump cement as per cement procedures. · Go to a one pit system and dispose of the remaining waterbase fluid. · Change out any rubber goods to diesel resistant products and begin building Versadril mud in number 2 and 3 pit. · Rig up catch pans, and any other necessary clean up equipment prior to displacement. Cuttings tanks etc. should be in place to capture cuttings, etc. Turn off or bullhead all water lines into pit room. · Flush out kill line from pit to stack with Mapco 200 if possible. · Flush and clean out pit system with Versdril. A total of 600 bbls. Needs to be made before displacement (288 bbls. In 10.75" csg.) · Pump a 40 bbl spacer consisting of VERSADRIL AND .75 LBS/BBL OF VERSA HRP FOLLOWED BY VERSADRIL. Pump at highest rate practical. Reciprocate pipe while displacing. Make sure bit is on bottom when leadinq edge of spacers and VERSADRIL exit bit. Calculate strokes and monitor returns at the flow line for oil mud returns. Electrical stability of the fluid can be used for the final confirmation of acceptable fluid purity · Once drilling has commenced and the VERSADRIL has been subjected to additional sheer adjust the screens sizes to a finer screen to reduce the amount and size of drill solids that accumulate in the system. Intermediate Interval Drilling Concerns · Hole Cleaning: Drilled formations may change the rheology of the mud - be prepared to treat the mud should this occur. Watch the drill rates. Adjust rheology and drilling criteria to match the hole cleaning needs. Effective ROP's above 150 ftlhr. should be carefully monitored due to the modeled poor hole cleaning that will occur at these rates. Confidential Mi SWACQ.s.w... ': _:'~_~::::~::~_-:2:~!:s~~~1~Ù}~~1~71~-i/i" . . Mi SWAC~~'¡¢;i'<P' ____~~:::::.:;:~;t;?!~~~f¡¡~P "::.:"';.:;:;;"" Mud Proposal "West Foreland #2" Cook Inlet Nabors 129 Prepared by: Pat Young Last Revision: 07/27/04 ~.. ~~,~ ';:.)/ -!- j:J' . ~ . Section 3 - Interval Discussions Interval: 3,000 - 10,682' Continued Wellbore Stability: Sloughing coals: Monitor hole conditions closely and inspect cuttings for indications of wellbore instability. · Minimize sliding in coals, minimize swab/surge~ · Drilling breaks may indicate the presence of coal, p/u off bottom and circulate out, if coals begin to be a problem spotting fracture sealing additives have proven to be successful. · Short trip as hole dictates. · Keep ROP below 150 ft/hr for hole cleaning and ECD values. · Upon reaching TD watch the bottoms-up cuttings closely. If the well does not readily cleanup or if there are any excess of torque, drag, pick-up or slack-off weights pump a high viscosity sweep and obseNe bottoms up again. · Monitor ECD to not exceed 0.7 Ib/gal over calculated. Sweep formulation: (if Needed) High Viscosity High Weight Sweep Formula 25 bbls of existing VERSAPRO drill-In fluid. VersaHRP - 0.5 Ib/bbl (allow to shear 20 minutes) Use Barite to increase mud weight by 2 Ib/bbl Production Interval Recommended Solids Control Equipment Shaker Screens De-sander Mud Cleaner/De- silter Centrifuge 175/140's or finer. XR Magnum Screens Not needed. As needed to control sand/silt, will help downstream equipment. Run as needed to control drill solids %, as well as mud weight. Confidential Mi S"Y~ÇQ~rt.;;!"Þ _ _ _ __nc'~_'~~:-::,_"y.._~'-___ . Mi SWACct~:~:i'4W - -~-::~;;;;~;$~'~ . Mud Proposal "West Foreland #2" Cook Inlet Nabors 129 Prepared by: Pat Young Last Revision: 07/27/04 Section 3 - Interval Discussions Interval: 3,000' - 10,862' Continued Recommended Lost Circulation LCM guidelines for VERSADRIL OBM The following lost circulation "Decision Tree" is recommended for use in the event that losses occur while drilling the horizontal production interval. It has been selected because of its' compatibility with base oil and ability to seal with minimal formation damage. These products are predominately acid soluble which will make any stimulated cleanup (if needed) much easier. LoslnR}luld while drl1linl( ~ Stop drilling and observe levels ~ Locate and stop losses I ~ Losses on surface 1r ~ Well flowing? - " Record shut in pressure. Kill the well ¡ Seepage losses < 10 bbl/hr ... Measure rate of loss ¡ I r Partial losses 1O~ 1 00 bbl/hr I ¡ Total loss ofretums 1 Spot pill: G-Seal 15 Iblbbl SAFE-CARS 40 10 Iblbbl SAFE-CARB 250 7 IblbbI Spot pill: Mica Med 7 Iblbbl MIX II Med. 10 Iblbbl G-8eal 20 Iblbb] SAFE-CARS 250 7 Iblbbl ---+I No success J---.,.. Spot pill: Mica Med 10 Iblbbl MIX II Med. 151blbbl Mix II Coarse 10lblbbl G-Seal 20 lblbb] SAFE-CARS 250 10 ¡blbbl Nut Plug Med 10 lblbbl ~ --- . ~l. No success i 1 NOTE: Check with the manufacturer of the mud motor prior to pumping any LCM Spot plug: Versa Pac or "Form-a" pill or Reverse Gunk or Cement No success -- ~_> "_.,_"____" ___.-,_,.,.....,..".....·~w_·"'~...''''=-r·',...",~~ Confidential Mi SWACQ$"'%" '·__~::_~,~~:_££~.::~;~~~iE:¿f'j:lÆ(~~~t;::Ùf;/iY . . ?:y-:~_/~>' ;~¡5 Mud Proposal "West Foreland #2" Cook Inlet Nabors 129 Section 3- Interval Discussions Interval: 3,000' - 10,682' Continued Virtual Hydraulics Modeling 9 7/8" hole section. Prepared by: Pat Young Last Revision: 07/27/04 r!Jj VlRTUALHYDRAULlCSID ND: 10682 ft Operal!r: Faestål SnaDShot lYD: 9500 ft Well Name: west Fae1an1'12 B~ Size: ~875 in. loca!!m west Cœk iñet . I ©I 996-2002 M-ll.l.C -All R9h~ "'''Ned Dæ: 6'1512004 Cardry: USA Geometry Depth Angle Density (lbIgaQ PV, VP,LSVP Temp (OF) AV(fthnin) Hole Clean Ind MD/TVD(fl) Cs9/HDa~~ (fI) 0 30 60 90 9.6 9.7 9.6 9.9 10.010.1 0 10 20 30 40 70 80 90 100 0 200 400 VG G F P ~ 300 10-314 300J - 9.950 ECD 4010 - fÌJXJ - 6(0) L ESD 7000 8000 \ 9000 ECD+CJ' 1??oo -- 11000 i- 12000 i __ Confidential ~ 2000 - PV - !!! ~ - VP -- LSYI' ., Pressure Loss (%) 25 50 75 100 1- DRILUNG FLUID VERSADRIL (MAPCO 200: !AdWei¡#t 95lb'gaI TestTemp 120'F SYSTEM DATA RaN RaIe 4S) gaIIm in ROP RPM WOB lFA 601Vtr 75 rpn 15KIb .75 in' PRESSU RE LOSS (psij Mocfied P 0Ner iJIw Drill Siring 1130 MåttIWiD 443/380 BII 322 BIIOn'Of 50 AIlÛUS 125 SItt!œECip32 U·TLb! Press 60 TaaJ Sysæm 2513 ESD ECD ofCLj Csg Stœ 9.M 9.96 10.08 m 9.67 9.92 10.04 VRŒI·VersiOß2.7 File - FCRESTWI.Mœ Mi SWACQ!¡~~1:J};iP - ·",~~-~~~-;~;~~~~;_:?"~;5i;:'-':;;¿'_-i~-'ic,,- . . Mud Proposal "West Foreland #2" Cook Inlet Nabors 129 Section 3- Interval Discussions Interval: 3,000' - 10,682' Continued Virtual Hydraulics -Hole Cleaning Model 1.000 0.750 >< (1) "C r:::: en r:::: r:::: 0.500' cu .!! (.) .!! o :J: 0.250 Confidential Hole Cleaning ~I......:. ì ! I i I : , I ¡ i I Prepared by: Pat Young Last Revision: 07/27/04 ROP 50. ftIhr ROP 100. ftIhr ROP 150. ftIhr ROP 200. ftIhr i~ ood Holel Clealing --+--, -- j~ I i ¡ I : --¡---ti--r-----I : ______L__L__ j Very Good! Holel Clea ling , ¡ ;, : i : I -~.-._~._-¡------------;~- 3~0.0 : VIRTUAL H YDRAU L I CS@ 400.0 500.0 Flow Rate (gal/min) I I I I i i , r--L ! ' T-+-- I I I I; !t----L-..! ] I i I ! I! ¡ I i , I I 600.0 700.0 ~ Mi SWACQ'Wi""<"'< ""':'~:-:~:'~;'~~~i~~t;t!t1>;~~:";~#!:;\F" . . Mi SWACCL~~~,w _ --:~:~:;~~i$'W~ Mud Proposal "West Foreland #2" Cook Inlet Nabors 129 Prepared by: Pat Young Last Revision: 07/27/04 Completion Operations VERSADRIL to Clear Brine Displacement Procedure The following recommendations are for displacing out oil base mud with 5% KCI brine. ~ While at the desired depth with drill pipe, pump the following spacers and brine at the highest pump rate practical 'vA,{hile aggressively rotating and reciprocating. ../ 10 bbls base Mapco 200 ../ 20 bbls viscosified 5%KCI brine (2.5 Iblbbl FLOVIS) ../ 50 bbls 5%KCI brine with 4 drums SAFE SURF O. ../ 25 bbls viscosified 5%KCI brine (2.5 Iblbbl FLOVIS) ~ Follow with base 5%KCI brine· ~ Save all VERSADRIL for storage and resale ~ Monitor pump strokes and returns carefully ~ Divert spacers and brine onto a vacuum truck Note: Do not stop pumping during the displacement. Clean-up Procedure The filter cake can be produced back when the well is placed on production. It is recommended to slowly put the well on production. A sudden and excessive flow back pressure drop may result in the detachment of the filter cake as a composite cohesive structure or "skin". Although this is not typical of oil base systems, large sheets and smaller shards of this "filter-cake skin" are carried to the production slotted liner surface during the initial production period, and this can and does result in plugging. Confidential Mi SWACQ9""<+/ - ~~ ~,,:·;::::~;~;,,;y;:~;r~;!-ifi~~~;Ji1'Ì'3/;j-- . Mi SWAr:g~~1~:~¢~'" .~___-:_c:~.~~'::::::~£~';~ßJ~i e t~~ Mud Proposal "West Foreland #2" Cook Inlet Nabors 129 Prepared by: Pat Young Last Revision: 07/27/04 Appendix 4 - Minimum Time to Circulate Prior To POOH No predictions are available for the rate at which cuttings are removed. Because the cuttings move more slowly than the circulating mud, it is essential that sufficient bottoms-up are circulated prior to tripping. A SINGLE BOTTOMS-UP IS NEVER ENOUGH! The minimum on bottom circulation time prior to tripping will be influenced by hole size, inclination and flow history (i.e. mud properties and flow rate). These factors will affect the height of any residual cuttings beds. Recent work by Exxon has indicated that the volume of cuttings left behind during normal drilling operations can be considerable. They recommend selection of bits/BHA's with large bypass areas to facilitate tripping out of the hole. Before tripping, monitor the shakers to ensure the cuttings return rate is reduced to an acceptable background level. The figures in the table below are guidelines based on simple slip velocity considerations and field experience: WELL INCLINATION RANGE 0° - 10° 10° - 30° 30° - 60° 60° + SECTION LENGTH FACTOR 13-1/2inch HOLE 9718 inch HOLE 6-112 inch HOLE 1.5 1.3 1.3 1.7 1.4 1.4 2.5 1.8 1.6 3.0 2.0 1.7 Procedure 1. Effective length = Section length x section length factor. 2 C· I t· t· L Effective Length B/U . Ircu a Ion Ime = x Measured depth at Bit 3. Since in practice not all of the section back to surface will be deviated at the same angle, the overall minimum circulation time prior to tripping should be apportioned in direct relation to the relative lengths of section at each angle. Confidential Mi SWACQ;~;~;~;;;;l" -~-;;,;;:;-;~~~:,;~~~;.,,;,þ . . 13 5/8" Annular s- ~ 13 5/8" Double Gate ~ ~ . 0 ~ 13 5'8" Mud Cross ~ ~ 13 5/8" Single Gate ~ r Kuukpik Drilling Rig 5 13 5/8" 5,000 PSI BOP Stack Drawn By: L Ross Date: 8/13/04 ( ~ . . Choke And Kill Lines and Valve on Kuukpik Rig 5 3" Mud Line from Mud Pumps to Rig Floor I Kiil Line Side Choke Line .Side u 52 - 2" 5,000 psi threaded valve = _ 2" 5,000 psi flanged hose = ~ ç- o co=r 52 co=r ~ = 2 1/16" 5,000 psi rated manual valve 2 1/16" 5,000 psi rated manual valve Drilling Spool _ 31/18" 5,000 psi Manual Valve. - 31/18" 5,000 psi Hydraulic Operated Valve 3" Flanged Choke Hose = To Choke Manifold inlet Kuukpik Drilling Rig 5 Choke and Kill Line Layout July, 2003 Drawn By L Ross . . 2 " To Shaker 3" Panic 3" To Gasbuster o 3 1/8,,0 0 2 1~"CB --"'(f) CÐ 2 7/16" o 0 JL o <3(=D=c:y '0 Y 2 1/16;' il+ 2 1/16" 0 ,,~ ~ œ œ,~ :::. / 0 3 1/8" Ü 0 /;:: ~"CÐ "0 CÐ N III ~~~r 2 1/16" A21/16" t Manual Choke t '----/~ Automatic Choke 2 1/16" Inlet Pressure Sensor 3" 3" 5,000 PSI Choke Manifold Kuukpik Drilling Rig 5 RED = 3 1/18" 5,000 PSI VALVES AND LINES Kuukpik Drilling Rig 5 BLUE = 2 1/16" 5,000 PSI VALVES Choke Manifold Drawn By: L Ross Date: 8/1/04 . . '\ / ---- ----- I I o Clœe 211/4" 2,000 PSI Annular O~ Ope. To Accumulator ~ L ~ ~ f1 16" Diverter Line 1 LJLJ LJ í 1 16" Hydraulic Operated Knife Valve 2" Drain Outlet o í I 21 1/4" Diverter Spool KuukpikOril6ngRig5 211f4"DiYelterSystem Drawn By: l Ross Date"8/13J04 ~X6" MUD MIX HOPPER ... , 6~" MUD MIX HOPPER ,~ .. 6· ~ DESIL TER , 6· 6r 5 x 6 CENTRIFUGALS 6' x t / .~J. .. o 6· x 8· ~; .. .. LEGEND -0-- CONCENTRIC REDUCER <B BOTTOM MUD GUN LOW PRESSURE lYPE - GATE VALVE )t AGITATOR ---fNJ- BUTTERFLY VALVE C/W FLANGES --Q- SUCTION VALVE, TEE lYPE ~K EQUALIZER OR SKIMMER ~ SUCTION VALVE, ELL lYPE NABORS ALASKA RIG 129 MUD SYSTEM SCHEMATIC NOT SHOWN ARE TANK CLEANOUTS SUMP SUCTION OR STEAM LINES WELL RETURNS 12t12. 8' ~ . ~ œ~ï"~ I TO SUMP . ~~O' ~~ lb· .. 6· ~, X "º,,-- 8· "-- º ~J. . ·X . .. .. .. , 8" FLOW LINES TO MUD PUMPS I TOTAL ACTIVE VOLUME = 1183 BbIS. TOTAL GROSS VOLUME = 1470 Bbls. ACTIVE EQUALS VOLUME TO BOTTOM OF MUD DITCH GROSS EQUALS VOLUME TO FULL HEIGHT OF TANK ( NOT INCLUDING TRIP TANK) I SHALE SHAKE~ rr-:HALE SHAKER L~J 6" M- ~~~~ ¡ 0' o 0 ·~O.~ ºl}{. ,,'. L ~J' 6· · ºv 6'^ r;¿ . n\ ~J. J J. FROM MANIFOLD 8· 36" MUD GAS SEPARATOR .. 6" x J' J" ~ TRIP TANK . . ~O FLARE .J .. e REF: HOOGSON INDUSTRIAL DESIGN lTD. DWG. ND. RJ052-OS .", 12:' 'WI' W oœc""",. ~~~r.N:l~f~~no=~OF Nobor3 Alaska DriHing Inc. 2525 C Street Suite 2DD ~j~02~~~ka 99503-2639 NABORS ALASKA RIG 129 MUD SYSTEM SCHEMATIC 18J BBl ACTWE SYSTEM ......BY I"EO BY ,_"BY I""· JOE ALSroN R SMITH PAUl. SMITH _ SCAI.£ HIA MWcrOBER DWC. NO. 129_oooJ SH1j of 1 "--..- . <. y r~{ ~ ] [fJt\7~ ~j~ NABORS ALASKA RIG 12~9E GENERAL ARRANGEMENT [J D D [J [J ! ì ~~~ I J~ £'0 ACCUMULATOR I HYDRIL GK ,_ __ _ 1/35/8" CL~ 50 OOPS I -...-.r-...J' FRfJM ACCUA/ULATOR 'ANNULAR r...1- - -- , I' I ~\ì-~-~ 13 5/8·-5000PSI FLANGES I--~j~j . I - OIVERTfR SPOOL \ I ! ' i ',__~~ ". '" " "'" .~~ . DIVERTER CONFRGURATHON 1. DNfRTER ANNUlAR NORMALLY OPEN. 2. VALVE NORMALLY CLOSED. .r H [J [= [~ ~-I¡t _= [J I [ -=. D D [J t:11\- ] ~ . .." m': "II' 'W' '!HIS IS" PROPRlEJAR'I' DESIGN or twIORS REPROOUC'fióN ¡m usE ór DE5IGN(SPERWISSI!It.£ON..'fIF"AIJ1HORIZEDIN Bl'twlQllSAlASKA. .11 Ncrbars AIœIrø s:~::o,~. 1f1 AHMOØNIW1UIc:...r 907- AlOÓko 99503-2639 '.'",r NABORS ALASKA RIG 129 1I1\.E GENERAL ARRANGEMENT 12' ONfRTER SYSTEM DAA'llH1'f'f ICH£èKEDfJ( 1~8'(, TOM REED . PAUL SMITH PAUL SMfTH """ N/A"" J/28/03"" NO. 129_0001 of , """""" , 5· 18" 5000# HYDRILR 13- 1'[ GATE: PREVENTO OOUBL "000# WP ~ '---------. . IJ-5/~Op5ANO BO T7i OM. ',·····'·~-'.¡;:JJjNGtD " 54" ··""Hf:f!;.!!.C",:""",..,,,..,,,.,, . ",........,"'........ ~ : ) 13 5/8" 5000#.GK" WP H~9:!L,5:~ WP 1351, TOP BY S~~~[fNGEO BOTTOM 13 51 ANNULAR BOP" HEIGHT = 51.25 . 9'-~" M~~J;~LJ' 5~tg;¡rf:p 2 GATE VALVE MANUA/l~L.r 50tg;jTf:p 2-1 GATE: VALVE HYDRAll"L. AC;yt#T[æp 3 1/16 10,0 - GAT[ VALVE 13-5/8" 5000# AOP./-rOM em TOP AND B FLAN MUD CRO~S C'foKE LINE) ONE (1) 4-1/;il¡~ (KILL LINE) It ONE (1) 3-;'LANGtD OUTLETS 5,000# API rJ KA RIG 129 NABORS AL~~NFlGURATION BOP STACK . ~~~F~') Q-r rf\ . OR us£ or - OESICNOF~~~~(~nt. ¡¡:.: ~ ~rss'fQi7 ONLY" '""" ~~~c~l~ ~.;9~:~-26J' AIasIII Mehoroglll, Nas I.lIlINabors__ '07-263-6000 ..." .- ALASKA RIG 129 "",,£Cr NABORS PREVENTfR '"" %i1t'lroNFlGURAI10N IREV. A .APPROVED BY PAUl.. sAlrrn cHtcKElirrr 'ITH s~ of 1 OAAWN BY TON I PAUL SM. I~. NO. 129_0002 . JOE. ALS. Dt.fE OCT 2003 <em N(A PfR MNlATfKJN OIl. REQU£ST IIODf11£I) BOP SOO< 760ECOJ A. J.A. ~ O!ScmPlJO' ~'IE m· ~ 8'C e e 0ø-6Y--'" , @ FOREST OIL CORPORATION R E eEl VE D ,)7 0 d!(cflbn?er - cflrülè 700 JUL 0 2 2004 QÇ>ÝnchoNJ('l'"" QÇ>l%vka .9.950-1 (9{}7) }',5/i-S6'()(i - (.9(J7) }',5/J-S6'(J1 (Ç0ar) Alaska Oil & Gas Coos. CommlSsmn July 2, 2004 t}OL\ - \ '-\ ~ Mr. Robert Crandall Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Hand-Delivered Re: Application for Well Spacing Exemption, West Foreland #2 (''WF #2") Well West Foreland Field; A-035019, ADL-359112 Dear Mr. Crandall: Forest Oil Corporation (''Forest'') by this letter hereby submits this application for approval to the Alaska Oil and Gas Conservation Commission ("AOGCC") and respectfully requests the AOGCC to issue an order exempting the West Foreland #2 well ("WF #2") from the drilling unit and spacing requirements of 20 AAC 25.055 as they pertain to the gas pool within the West Foreland Field. The West Foreland Field is defined by a discovery gas well, the WF #1, that was drilled as a straight hole on federal lease A-035017 in Section 21, Township 8 North, Range 14 West, Seward Meridian and completed on March 29,.1962 by Pan American Petroleum Corporation. The WF #1 is the only well in the West Foreland Field and has a surface location on the federal lease of879.5' FSL, 670.5' FEL, Section 21, T08N, R14W, Seward Meridian. The West Foreland Field gas reserves are contained within two oil and gas leases: (1) federal lease A-035017 and, (2) State of Alaska lease ADL-359112. State of Alaska lease ADL-359112 is presently one of two State of Alaska leases committed to the West McArthur River Unit ("WMRU") but has no producing wells located within its bOWldaries. All WMRU producing wells are oil wells located within State of Alaska Lease ADL-359111. Federal lease A-035017 is not committed to any state or federal unit and there are no plans to include this federal lease in any new or existing unit. Both leases are physically located in the Cook Inlet area near the West Foreland peninsula, approximately four miles south of the Trading Bay Unit Production Facilities. The surface estate within the bOWldaries of the federal lease is of mixed ownership between SalamatofNative Association, Inc., Alaska Natives and private individuals. The WF #1 pad is located on land owned by SalamatofNative Association, Inc. Forest has a comprehensive surface use agreement with SalamatofNative Association, Inc. that will allow use of this land to expand the WF #1 well pad, ifnecessary, to drill the WF #2. The WF #1 was drilled by the Pan American Corporation to a total depth of 13,500' MD & TVD in 1962. During the completion eight intervals were drill stem tested but only two sands demonstrated productive potential. Both sands are gas sands in the lower Tyonek interval; an upper sand, at 9334-50 ft MD (the ''9,200' Sand"), and a lower sand, at 9502-22 ft MD (the "9,400' Sand"). In 1984, an extended flow test of the 9,200' Sand produced 52.8 MMSCF of gas. The lower zone was plugged back and cUlTently only the upper zone is open in the WF #1 wellbore. To drill out the bridge plug in order to produce the 9,400' sand from the WF #1 would jeopardize production from the entire WF #1 wellbore. The WF #1 was shut-in Wltil April 2001 when Forest, the BLM and the Alaska Department of Natural Resources (''DNR'') executed a Compensatory Royalty Agreement ("CRA") to allocate production from the WF #1 between the federal lease and the State of Alaska lease. The CRA was required by the AOGCC pursuant to Conservation Orders No. 450 and 450-A granting a pennanent exception to the spacing requirements of 20 AAC 25.055 to allow production of gas from the WF #1 from any interval not deeper than 9,527' MD. The tenns of the CRA and Conservation Order No. 450B established an allocation of 58% to the federal lease and 42% to the State of Alaska lease of any gas production from any interval not deeper than 9,527' MD in the WF #1. This exception to the statewide spacing regulations is sought because the proposed bottomhole location of the WF #2 may be within 1,500' of a property line with a different landowner (i.e. the federal lease) and within 3,000' of a well capable of producing from the same pool (i.e. the WF #1). This exception to the statewide spacing regulations is necessary to optimize gas recovery from the Tyonek fonnation in the West Foreland Field. The proposed bottomhole location for the WF #2 will Page 1 of2 e e be updip from the existing WF #1 and near the common lease line separating the State of Alaska and federal leases. The proposed bottomhole location of the WF #2 for the 9,200' and 9,400' Sands will be in Section 21, T08N, R14W, Seward Meridian and east of the common lease boundary, as indicated on the enclosed maps. Because the WF #2 is proposed to be drilled into and produce from both of the lower tertiary productive intervals found in the WF #1, it is expected that the AOGCC will also require a CRA to be entered into and executed by Forest, the BLM and DNR as evidence of a pooling agreement prior to production from the WF #2. Forest has had several meetings with the BLM, the DNR and COO to discuss its plans for the WF #2 and its proposal to recommend that allocation of production between the federal lease and the State of Alaska lease from the same lower tertiary productive intervals as those found in the WF #1 be in the same percentages for the WF #2 as those established for the WF #1. All parties have indicated agreement to this approach. However, because there is a potential for producing intervals to be encountered in shallower sands, the CRA for the WF #2 will need to be restructured to accommodate this possibility and establish a pooling allocation percentage for these shallower sands. Consequently, Forest respectfully requests that the AOGCC grant an exception to the provisions of20 AAC 25.055 for the WF #2 based upon a proposed well path approximately descn'bed as follows: Feet From Feet From Feet From Target Depth MD TVDss X ASP4 Y ASP4 Sec 21 N/S Line Sec 21 E/W Line Lease line WF #2 surface 0 90' 190391 2475578 879.5' FSL 630.5' FEL 406' West WF #1 surface location from 1961 BLM log report 879.5' FSL 670.5' FEL 7,400' sand 7,540' -7,218' 190285 2476400 1,020' FSL 758' FEL 216' West 9,200' Sand 10,083' -8,968' 190047 2478241 1,781' FNL 1,043' FEL 242' East 9,400' Sand 10,351' -9,150' 190022 2478435 1,588' FNL 1,074' FEL 293' East TD 10,650' -9,355' 189994 2478651 1,365' FNL 1,105' FEL 339' East Pursuant to 20 AAC 25.055, enclosed is a plat showing the location of the WF #2, lease maps indicating well paths, where the proposed well is estimated to encounter productive intervals and all adjoining properties. In addition, a table is enclosed listing the parties entitled to receive notice of this application and an affidavit stating that the undersigned is familiar with the facts stated in this application and that the plat correctly portrays pertinent and required data.. The parties listed in the enclosed table have also been mailed certified copies of this application, including all enclosures. If there are any questions or should you need additional infonnation, please contact me at (907) 868-2112. Sincerely yours, FOREST OIL CORPORATION ~ Land Manager Enclosures Cc: CIRI BLM ADNR Page 2 of2 e e TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Alaska Oil and Gas Conservation Commission In the Matter of the Application of Forest Oil Corporation for a well spacing exemption And exception to the provisions pertaining to Drilling Units and Well Spacing pursuant to 20 AAC 25.055 ) ) ) ) ) ) ) VERIFICATION OF FACTS AND AFFIDAVIT OF JIM ARLINGTON Jim Arlington, being fIrst duly sworn, upon oath, deposes and states as follows: 1. My name is TIM ARLINGTON. I am over 21 years old and have personal knowledge of the matters set forth herein. 2. I am the Land Manager for the operator, Forest Oil Corporation (FOREST). 3. lam knowledgeable and fully informed concerning the facts associated with the application of Forest Oil Corporation for a well spacing exemption and exception to the provisions pertaining to drilling units and well spacing pursuant to 20 AAC 25.055 as they pertain to the proposed drilling of the West Foreland #2 gas well. 4. I have assisted in preparing and have reviewed the completed application submitted by Forest requesting an exemption ftom the provisions of20 AAC 25.055 for the drilling of the West Foreland #2 well in the West Foreland Field and hereby assert that all the facts contained therein are true to the best of my knowledge. 5. I have reviewed the plat and maps enclosed with the application and assert that they correctly portray the pertinent and required data. 6. Forest is the only operator of any wells within 3,000 feet of the well for which the exception contained in the application is sought. 7. On or about July 2,2004, pursuant to 20 AAC 25.055(d), I mailed the required notice of Forest's application for an exemption ftom the provisions of20 AAC 25.055 by sending a copy of the application by certified mail to the names of all owners, landowners and operators of all properties within 3,OOOfeet of the proposed well location and have attached this list as Exhibit "A" to this affIdavit. Subscribed and sworn to on July ~, 2004. STATE OF ALASKA THIRD JUDICIAL DISTRICT ~~~ ) ) ) ss. r"Ià On this ---.a: day of July 2004, before me, the undersigned, a Notary Public duly commissioned and sworn, appeared Jim Arlington, personally known to me, to be the person whose name is subscribed to within the VerifIcation of Facts and AffIdavit. \\'1111//1// \" _,~ C. Put. /// ~ ø-':. * · · .. · <~~ ~ ...,,, OTAb * Q- ..... ,,~ .f:J- *. -::. .... ...... - ::: .. -*-. . :: - .. . ....... ~*.. 8Eþ..\- :*:::: ...." . ~ "/~ · * . .. ... Ñ:-..' ///4?le Of ~\&#fì\\' //11/1/111" Wi~ess my hand and offIcial seal. ( ry~.œ~ Notary Public, State of Alaska· . .. . My Commission Expires: (5 Il I a e e EXHIBIT "A" To VERIFICATION OF FACTS AND AFFIDAVIT OF JIM ARLINGTON In the Matter of the Application of Forest Oil Corporation for a well spacing exemption and exception to the provisions pertaining to drilling units and well spacing pursuant to 20 AAC 25.055. West Foreland #2 well List of names of all owners, landowners and operators of all properties within 3,000 feet Name Attention Address City State Zip DNR, Division of Oil & Gas Chris Ruff 550 West 7th, Ste. 800 Anchorage AK 99501-3560 U. S. DOl, BLM Greg Noble 6881 Abbott Loop Rd. Anchorage AK 99507-2591 Cook Inlet Region, Inc. Kirk McGee 2525 C Street, Ste. 500 Anchorage AK 99509 T9N T8N e R14W ---":"":"-'l I I ~ TRACT: 2 e T9N PA I I I I I , - T8N L-:) c' ADL 3p911 2 FOREST OIL <';ORPORATION -,~_._--_._- 100% r - - T7N Fa land R14W TRACT BOUNDARY - - - UNIT BOUNDARY T7N OiL PA FOREST OIL CORPORATION Alaska Business Unit 1 :72000 o 1 L. o 5000 10000 FEET WEST McARTHUR RIVER UNIT and FEDERAL LEASE A-035017 2 KILOMETERS o , 2 STATUTE MILES 1 -..: 1~ = 6000' 1- LMS -- NAD2? ASP ZONE 4 I I"'" 1~N-2004 I I e e West Forelands Area Lease Map TaN, R14W, Seward Meridian W. McArthur River Unit Forest Oil ADL-359111 2 8 12 10 11 17 15 14 13 WMRU Forest Oil ADL-359112 20 22 23 24 "~~.._~.- 29 28 -- 26 25 32 Cook Inlet Bluff 33 35 36 1" = 1 mile Lease Map - Surface Location '~'., A e 1 Mile e ~ Tar~ TD ',:> 9Ÿ55 l, =-- L ~.'\ ><--111 ü Shoreline & Lease Line ... e 1 Mile e . .. ......... . JI'. . .. .... Lease Map - TO location .~' I I WF-2 TO Location 10650'md (-9355'sstvd) X= 189,994 Ta TD~'~~¿:; y= 2,478,651 =- 1336' From North line 1105' From East line /' . "'''''"'_.'''_''~~N'''M<""..~~·_,__"..~,_,~.l:"w''''''_d'H< i ./ .-</ ..- ,./' ,. l " .' , , " i ,/ ... " ,i// 1\,//:}.:}I)' /, " ,../' \01 fO¡r.. :-1 ,/ - , , ,/ i ..../ ,. .. ..- i .// ,~.-.~"~".~,,,'-""~~_."'~-~ East of Lease line I I I ¡ I ì I' I I II I I ! i I' I~ Shoreline & I· Lease Line \-~- e ··'-r ,. u····I··· I ~ ) I I I .- I / ,1'/ "'-/1 /" ,/ ¡ I I I I I i I I I I I I I I .. Ii ·····'r····· ,..... "'... I e Lease Map - 7400'Sand ~ , , " . . ... .'., ,1-_.. ...'.. u . ..... ... ... / " <./ ,J' J' .' ,. ... WF-2 7400 Sand 7540'md (-7230'sstvd) x= 190,285' y= 2,476,400' 1696' From South line 758' From East line 216' West of Lease line " ,/l ,,¡' /' 1 Mile -"~ ~ ~,,--"~ -~--""~,..._,.,_.._".,,._,. () " ,. " " ;}' ,. ,. ,. ./ ~~-'~ ...,-/i ,_. _.--, _\l.~for~ná_:L }'.- !_t;o,iJ_'_::-G;i.: ~t- -;';'0.1:. ,/' .... ... " ./,/ ',- I'~rr~+ò,*" II I þ .~ Shoreline & I", Lease Line --'--_·""'·,~'""'·,,~,·_-"-,-~-~-·_,_···__"___o_..w.~,.. '_"'_>~"_""'_'~W""'_'''M'.. . .. . .. '~^'.." N_' ,_"~ ___.~ ~~ '."'-'-~'---'-"'".""."._-,...."."._-"...._._. _~",,·,,"_.'_._·_..,,"·'n_ '. I , .... ,. e e -^ - - ~ -- Lease Map - 9200' Sand "'i 1 Mile ~ ----- ~---~~ --- ._--~- -- U'IMKI5"... I \ t- 1 ~ "II \{/1F2-1 Tary IlTD "" -935.5 I pr')J~:J<J·"Þ:í ~ WF-2 9200' Sand 10083'md (-8968'sstvd) X= 190,047' y= 2,478,241' 1748' From North line 1043' From East line 242' East of Lease line WForwlWl-1 * -- - - -. . --____~_~,,,.'.~.._M,... '." ..-/' Shoreline & I'~ ......--.....----".. ..... LeaseL.l"ne - .."-~~~~ --.-'. _. _·,w' _ _ I ,. e e I I I I 0'1"""-"'"""" I I I ~.,."...J~ Lease Map - 9400' Sand ~ I ! \V~M+u-4 ....,~.......,"'''-".._. - ----~- ~. " -- - 1 Mile _w_~._ _~ -~--" -" - ~~ ---~.- ~ --~~-~. -9151 \IV Forull4 -1 ~i- - ~------ ~ . I' ~ Shoreline & í I . . --T---~··~,·_------l-ease....Llne I I I - / Lease Map - All Targets '~. ... - . IIWH- Taf!:~ TD 't> 9>'JS;5 Pro. '~'¡¡Jr;.a1'l~w // .. .../ ,', - i ,../' I ,/ /4~;~~ 1 L~ ,I ..... i;'~í-'" --..-¡ -- .-.', ,/ \, _/;¡":.f~_.::c=- ~ \~~:' , . " l i ..{' ,/ .. ...'" WFO~'-1 ,// },:='1_~A -~: ,./ '" .. ill/ '. . ~ Shoreline & /.,//'''' I ~. Lease Line -~"'-"~-----~-"-"._-"'--'.~--""--"'-'---'-'-~I---._--"-··-·--·-"--~~~-"·-_·"··-·-'~-·---·~"~_"w_'__,~,___-"~'__'~H__""'~.~'_","~._.__...~._,,~....~~......_..._ ...l .' -"-_····">_..··'"·_,··_"_..·~__,~..._.'"u".,".."...~_,~,,.._.~'". /"'/ I ,.... Lease Map -~'II ~ Feet 178700 I I . 188700 I :J 4 2492300- \ ".."",___.. t >"T·~ I _"_'._"·_·.~..M"_~"_'"_·> e ':1 198700 , -2492300 .,") '.~J ,W'¡ I '- '11 _r ;}"", ",,- .... ,/ 2482300- -2482300, : ~ e (I =) .. '" -~I WFO~IW-1 ,,£ "c.IJj I/ìf4.. " 2472300- <') -2472300 ." .. -,1- -.... fOIF& 1100 .L.b8 III .- - -.--.. .252000bO - . o 2 . ~ Wë e ~A Y TO nlE <{:\ tnlJ[t . R9~R Of' ---:--~~-~".. ~ - {'AW I ,1\ ~ Ji'{' , ,\". V . .'."'; 'L--i" ---\~-" j /,'c:,LUµL ( k #l., '-" [Ì'\ . Sir. iOO : IOII¡\GE:, PI_··j 1\1\ 907·2::;f) 9950i t1600 l468 i , . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME \N5-\- \=ùíf \o..~ ~ d dDL\ - \~-S PTD# >< Development Service CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 6.0-69) PILOT (PH) Exploration Stratigraphic "CLUE". Tbe permit is for a new we1lbore segment of existing weD, . Permit No, . API No. Production.sbould continue to be reponed as a function 'of tbe original API number. stated above. HOLE In accordance witb 2.0 AAC 25..0.05(1), aJI records, data and logs acquired for tbe pilot bole must be clearly differentiated "in botb name (name on permit plus PH) and API number (5.0 7.0/8.0) from records, datJI and logs acquired for well (name on permit). SPACING EXCEPTION "f DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance witb 2.0 AAC 25..oSS~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to tbe spacing .exception tbat may occur. AU dry ditcb sample sets submitted to tbe Commission must be in no greater tban 3D' sample intervals from below tbe permafrost or from wbere samples are first caught and 10' sample inter:vals througb target zones. t/~ ?(.//at!hß -!¿;c,L. ~;/d tR/kr;Sb . ~. r tÆ-A-t'l 6-3/.DI . . Jody I Linda: We should state in the permit approval letter that: 1. In accordance with past Commission practice, a mud log is required in one well from each drilling pad. Because a mud log was not obtained in adjacent well West Foreland #1, a mud log will be requied from the base of conductor to TD in West Foreland #2. Cuttings samples will not be required in West Foreland #2 as samples were collected from 30' to 13,500' in West Foreland #1. 2. Wellbore directional survey data must be collected and reported to the Commission in conformance with 20 AAC 25.050. Thanks, Steve Davies Field & Pool W FORELAND, UNDEFINED GAS - 920500 Well Name: W FORELAND 2 ____~_~___ Program DEV Well bore seg D PTD#: 2041430 Company EOREST OIL CORP Initial ClasslType DEV I PEND GeoArea 820 Unit _______~_ On/Off Shore On Annular Disposal D Administration 11 F~rmit fee attached_ _ _ _ _ _ _ _ _ Yes_ 12 _Leas~ _number appropriate _ _ _ _ _ _ _ _ Yes_ _ _ _ Surface location on_shore tnFed Lease A-0;35Q17~ top producti~einteryal and TO Offshore inAQL-359112, 3 _UÐtqUe welt n_ame _a!1d oumber _ - - - - - - - - - - - - - - - - - - - . _ _ _ _ _ _ _ _ Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 4 WellJocated tn_a_d_efinedPool_ No_ West Fo(ela!1d l.H1d~fjned gas popt 5 Well located prpper dtsta!1ce from driHi!1g unitboundary_ _ _ _ _ _ _ _ _ No _ _ _ Atproductive tnteNals, well will be less tha!130Q' from propertybpundary. 6 Well located prpper dista!1ce_ from other w~lls No_ _ Will_bele_ss thao 3QOO'from produci!1g gasweJl open!o same poptas required by 20 MC25.055. _ 7 S_utficient açr~ageavailable indrilJiog unit_ _ No_ Two ~eparat~ly pwoedt(acts withio a si!1gle drilltng uoit (Section 21L '8 Jf_deviated, is weJlbore plaUncJuded _ _ _ _ _ _ _ _ _ Yes - - - - - - - - - - - - - - - - - - - - - - - - 9 Op~rator only: affected party _ _ _ _ _ _ _ _ _ No 10 _Oper_ator has_apprpprtate_ b_o!1d tn Jorce - - - - - - - - _ _ _ _ _ _ _ _ Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 11 Fermit cao be tssu_ed wjtho_ut conservation order _ _ _ _ _ No_ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 12 Fermitcall be tssu_ed wJtbo_ut administ(ati~e_apprpval _ _ Yes .' SFD 8/5/2004 13 Call permjt be approved before 15-day waj! _ _ _ _ _ _ _ _ _ No 14 WellJocated within area an_d_strata authori,zed byllljectioo Order # (puUO# incpmmellts) (for _ NA - - - - - - - - - - - - - 15 _A!IWeIJs_wit/lin_1l4Joile_area_ofreviewjdeotjfied(Fpr~ervjcewelJonlY:L _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 16 Fre-produçed_ i!1j~çtor; duration of pr~-production less than 3 monthsÆor_ser:viçe well only) _ _ NA 17 ACMP_Fjnding _of Consistellcyhas been jssued fortbis prpiect _ _ _ NA . . An ACM¡:> consistellçyrevjew was completed tor th[sproject ba_ck in 199!t Sf 0 8~5l2004 . . . . . . . _ Engineering 18 COllduçtor string_provided _ . . · . . . . . . . Yes 19 Surface casing protects allkllown_ USOWs · . . . . . . . Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 20 CMTvplad~Quateto circulateonconductor_& sur(csg _ _. . . . . . . Yes 21 CMT vp! adeQu_ate_ to tie-in long string to surf ~g .... No_ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 22 _CMTwil! cover_aU knownpro_duGtive hQrilons. . . Yes 23 Casillg desi91ls ad_eQuaJe fO( C, T, B _&_ p-ermafrp$! · . . . . . . . Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 24 Adequate tankage_or reserve pit - - - - - - - Yes _ _ Rig jse_quippedwith steel pits, NoreseNe_pjtplallned, Wastes to_Clas_sJlwell. 25 Jfare-drilt l1asa 10-403 for abandonment beeo approved - - - - - - - . NA - - - - - - - - - - - - - - - - - - - - - - - - - - - 26 _Adequate wellbore_ separation propo~ed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ ¡:>ro~imity_ analysis perfprmed. Glearançe report prepared, Wf #t is only nearby welJ reçen_tly surveyed. _ _ _ _ 27 Ifdjv~rter required, dQes jt meet regulations _ . . Yes - - - - - - - - - - - - Appr Date 28 _DrilJiog flujd_ program $c.hemattc_&_ equip li$!adequate. Yes _ _ _ Maxjmum Bt¡:> 8._6EMW. ¡:>Ianned mud weigbtup to 9.5 ppg, . . TEM 8/31/2004 29 _BOPEs,_dp_they meet.reguJation _ . Yes - - . - - - - 30 _BOPE_pre_ss rating appropriate; test tp(put psig in comments) . . . . _ Yes _ _ _ CalcuJatedMASP 33j 1 psi. 5000 psijnjtjal test. ~OOOpsi, thereafter. _ . 31 Chokemanjfold complies w/APIRP-53 (May 64L _ _ · . . . . . . . Yes - - - - - - - - - - - - - - - - - - - - - - - - - - 32 WQrk will occur withoutoperationsbutdown Yes - - - - - - - - - - - - - - - - - - - - - - - - - 33 Is pres_ence_ of H2S gas_ prob_able . ........ No - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 34 Mecha_ntcalcoodjttoll pt wells within AOR verified (For service w~1! only) . ........ NA - - - - - - - - - - - - - Geology 35 Permit call be tssued wlo_ hydr_ogen_ s_ulfide measures. · . . . . . . . Yes _ 1:t2S mÞllitoriog equipm~mtwill befunctionin9at all times whiJe_ dJillillg /3. completing.. 36 _D_atapres~l)ted on pote_ntial overpressur~ ,zones. _ _ _ _ _ _ _ _ Yes _ Exp~çted r~servoir pressure is 8,}!o 9.0 ppg; willbe _drilled with 9.2 to 9.5 pRQmud, Appr Date 37 _Setsmic_analysjs_ of sballow gas_zooes_ NA _ _ WiII.twill e~isting well WFpreJand #1 toadept/lot 5305' MQ. - - - - - - - - SFD 7/29/2004 38 _Seabedcondjtioo survey (if off-shpre) . _ _.. NA - - - - - - - - - 39 _ Contaçt namelp/loneforweekly progress reports [exploratory ÞlllYl _ _ . . . . . . Yes . . . Ted Kramer .AK ¡:>rodu.ction_ Manager, a66-_2137 - - - - - - Geologic Date: Engineering Date ¢T Date Mudlog required, but samples not required. AOGCC policy has been to require a mudlog from the first development well Commissioner: Commissioner: o ner r~~ drilled from a pad. Adjacent West Foreland 1 well has cuttings samples from 30' to TO, but the well was not mudlogged. D""T$ III 11- Informed Forest's operations geologist that a mudlog would be required in West Foreland 2 from base of conductor to TO during phone conversation on 7/26/2004. SFD . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information. information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. FOREST OIL CORPORATION C·· ~O'· !.~r;)) r' '{:.I/'I f\ l . ¡ . It', ! WEST FORELAND NO.2· ¡!, L, :!~!!n ,'. WESTSIDE COOK INLET, ALASKA MUDLOGGING END OF WELL REPORT .--- '~ H-DR~Z[JN I WELL LOGGING. INC. "--_._.~-_..-.- · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · ;{o1-/1'/3 FOREST OIL CORPORATION FINAL WELL REPORT WEST FORELAND NO.2 WEST FORELAND FIELD KENAI BOROUGH, ALASKA H ---, N C R7f-Z-C ""ELL f.HG6'\\.iG, !\\.i{:", · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · OPERATOR: WELL: lOCATION: lEASE: FIELD: AREA: COUNTY: STATE: PERMIT NUMBER: API NUMBER: ELEVATION: SPUD DATE: LOGGING DATES: LOGGING DEPTHS: COMPANY REPS: COMPANY GEOLOGIST: DRilLING CONTRACTOR: MUD COMPANY: MUD TYPE: MWD I DD COMPANY: HWl LOGGING GEOLOGISTS: CASING SIZES: HOLE SIZES: WELL INFORMATION Forest Oil Corporation West Foreland NO.2 SL: 886 FSL, 571 FEL Sec. 21, 8N-14W, SM X: 190052 Y: 2475582 BHL: 1354 FNL, 1139 FEL X: 189958 Y: 2478636 ADL 0359112 FED A035017 West Foreland Cook Inlet Basin Kenai Borough Alaska 204-143-0 50-133-20542-00-00 GL: 88' ; RKB: 108.25' September 17, 2004 09/29/2004 to 11/05/2004 4450' to 11,387' Joe Harris / Fred Brent Larry Casarta Kuukpik Drilling Rig No. 5 MI VersaDril Sperry-Sun Drilling Services Lowell Price / Neil Peterson 20" at 65' ; 13 3/8" at 3003' 171/2" to 3003'; 9 7/8" to 11,387' · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H - ~--==:=--- N [] R¿4~LZ [] "'\lEL.L LOG&::¡(f\.1G. INC. Forest Oil West Foreland No.2 Operational Summary 09/24/04: Rig up mudlogging unit. 09/25/04: Rig up mudlogging unit. Start monitoring well. 09/26/04: Monitor well. 09/27/04: Monitor well. 09/28/04: Monitor well. 09/29/04: Monitor well. 09/30/04: Start logging well at 4450' MD. Drilled 9 7/8" hole from 4450' MD to 5000' MD. 10/01/04: POH at 5000' MD for additional stabilizer. RIH. Directionally drill from 5000' MD to 5218' MD. 10/02/04: Directionally drill from 5218' MD to 5871' MD. 10/03/04: Directionally drill from 5871' MD to 5995' MD. Make wiper trip. Repair Top Drive. RIH. Directionally drill from 5995' MD to 6061' MD. 10/04/04: Directionally drill ahead from 6061'MD to 6187' MD. Circulate hole. Repair generator and Pump NO.2. POH for new bit. 10/05/04: Service rig. RIH to shoe. Circulate and condition mud. Hold safety meeting. Wait on parts for rig generator. 10/06/04: Replace injectors on rig generator. Stage in hole to 5075' MD. Circulate and condition mud. POH to shoe for rig generator repairs. 10/07/04: Wait on rig generator supply parts. Service rig. 10/08/04: Wait on rig generator parts. Begin installing generator parts. Service rig. 10109/04: Repair rig generator. Circulat~ and condition mud. Stage in hole and circulate every 1000 feet to bottom. Encounter pump and generator problems. Pull to shoe. Service rig. 10/10/04: RIH and circulate bottoms up. Directionally drill from 6183' MD to 6320' MD. 10/11/04: Directionally drill from 6320' MD to 6696' MD. Circulate bottåms up. Make a wiper trip to'6000' MD. Drill ahead to 6766' MD. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H ---.---.--.--.-..---......... .......---'.-----.. N ----- tJ-R]~:~Z-D \/\1 E l.. Ll. 0 (:¡¡ E!!i. '\..í (é]¡ '" I f\J C . 10/12/04: Directionally drill from 6696' MD to 7089' MD. 10/13/04: Directionally drill from 7089' MD to 7364'. 10/14/04: Directionally drill from 7364' MD to 7648' MD. Circulate bottoms up. Make a wiper trip to 7000' MD. 10/15/04: Directionally drill from 7648' MD to 8021' MD. 10/16/04: Directionally drill from 8021' MD to 8377' MD. POH for new bit and mud motor. Requirement to run weekly BOPE test. 10/17/04: Perform weekly BOPE test. MU and RIH with new BHA. Circulate bottoms up. Directionally drill from 8277' MD to 8393' MD. 10/18/04: Directionally drill from 8393' MD to 8677' MD. 10/19/04: Directionally drill from 8677' MD to 8690' MD. POH. Change out mud motor. RIH to shoe. Slip and cut drilling line. RIH to bottom. Directionally drill from 8690' MD to 8790' MD. 10/20/04: Directionally drill from 8790' MD to 9230' MD. 10/21/04: Circulate and condition mud. Directionally drill from 9230' MD to 9418' MD. 10/22/04: Directionally drill from 9428' MD to 9438' MD. POH for new bit. Change BHA. RIH. 10/23/04: Directionally drill from 9438' MD to 9715' MD. 10/24/04: Directionally drill from 9715' MD to 9930' MD. Encounter problem with generator. Circulate bottoms up. POH. 10/25/04: POH. Repair generator. Service rig. RIH to 6120' MD. 10/26/04: RIH. Directionally drill from 9930' MD to 10129' MD. 10/27/04: Directionally drill from 10129' MD to 10381' MD. 10/28/04: Directionally drill from 10381' MD to 10585' MD. 10/29/04: Directionally drill from 10585' MD to 10717' MD. Circulate bottoms up. Make a wiper trip to 5200' MD. 10/30/04: Make a wiper trip to 5200' MD. RIH. Pump 3 round trip circulations. Condition hole for Schlumberger logs. POH. RU Schlumberger loggers. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · HCRAzcN "WELI_ LOGGI"-lG.. INC_ 10/31/04: RIH with Schlumberger logging tools. POH at 9650' MD. Reconfigure logging tool. RIH to 9650' MD. POH. RIH to ream and condition hole for logs. 11/01/04: RIH to ream and condition hole for logs. POH. PU NB #7 and new drilling BHA. RIH to 10650' MD. Circulate and condition hole. 11/02/04: Directionally drill from 10717' MD to 11066' MD. 11/03/04: Directionally drill from 11066' MD to 11284' MD. Circulate bottoms up. POH. 11/04/04: POH for NB #8. MU new bit and BHA. RIH to 2875' MD. Slip and cut drilling line. Break circulation. 11/05/04: RIH. Circulate bottoms up. Directionally drill from 11284' MD to a total depth of 11388' MD Make a wiper trip. Circulate and condition hole for Schlumberger logs. 11/06/04: Wipe hole every 1000 feet to 9000' MD. Circulate and condition for Schlumberger logs. 11/07/04: POH. RU Schlumberger loggers. RIH and log to 10700' MD. POH. PU MDT. Run MDT to 10378' MD. 11/08/04: Finish Schlumberger logs. RD Schlumberger. Test BOPE. PU hole opener. RIH with hole opener to 10850' MD. 11/09/04: Open hole to 11387' MD. Make a wiper trip to 9000' MD. Pulled tight at 10800' MD. Circulate out at 9000' MD. RIH to bottom. Circulate out. Continue to wipe hole and circulate to maintain hole for casing. RU to run casing and cementers. Release mudlogging unit. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · FOREST OIL CORPORATION WEST FORELAND NO.2 LITHOLOGY SUMMARY 4455': SAND: It to med gry overall; individ grains transluc, clr, opaque, gry, blkish brn, grn; lower fine to upper med, tr to v mnr lower crse to crse; subrnd to ang, dom subang; poor sphere; poor sort; dom qtz, mnr feld, v mnr to mnr lithics, mnr blk coal. 4540': SAND: It gry overall; individ grains clr, transluc, opaque, gry, brn, blk, grn; lower fine to upper crse, tr pebble; subrnd to ang, dom subang; poor sphere; poor sort; dom qtz, mnr feld, v mnr to mnr lithics, mnr coal, blkish brn to blk. 4655': COAL: v dk blkish brn to blk; firm to v firm; subblocky to blocky; hackly to mnr subconchoidal appearing fracs or cleats; subvitreous to vitreous Istr; lignitic to bituminous. 4820': COAL: v dk blkish brn to blk; firm to v firm; subblocky to blocky; hackly fracs; subvitreous to vitreous Istr; lignitic to bituminous. 4860': SAND: It gry overall; individ grains transluc, clr, opaque, blk, gry, grn; fine to lower crse; subrnd to ang, dom subang; poor to sli fair sphere; poor sort; dom qtz, mnr feld, v mnr to mnr lithics, mnr coal, blkish brn to blk. 4970': COAL: blk; firm to v firm; subblocky to blocky; hackly fracs, mnr subconchoidal appearing fracs or cleats; subvitreous to vitreous Istr; lignitic to bituminous. 5080': SAND: It to med gry overall; individ grains transluc, clr, opaque, gry, blk, mnr brn; lower fine to upper med, tr lower crse; subrnd to mnr ang, dom subang; poor to fair sphere; poor sort; dom qtz, mnr feld, v mnr lithics, com blk coal. 5275': SAND: It gry overall; individ grains transluc, clr, opaque, mnr gry, blk, brn, tr grn; lower fine to med, dom fine to lower med; subrnd to ang, dom subang; poor to fair sphere; fair sort; dom qtz, sli com feld, v mnr lithics, v com blk coal. 5355': CLAYSTONE: It to med dk brnish gry, mnr grnish gry hues; firm to occ v firm; subblocky to mnr subplaty; dull earthy lustr; appears massive. 5415': COAL: blk; firm to v firm; subblocky to blocky; hackly fracs, mnr subconchoidal appearing fracs or cleats; subvitreous to vitreous Istr; lignitic to bituminous. 5480': SANDSTONE: med-dk gry overall; clr, trnsl and milky qtz and felds; mod to vry prly srtd; rnd-sbrnd grs; grain sptd; com wthrd lithic and coal frags; overall mod indurated; grdg to loose, unconsl sand; occ wkly calcareous; tr rxn w/HCI. 5580': COAL: blk; firm to v firm; subblocky to blocky; hackly fracs, mnr subconchoidal appearing fracs or cleats; subvitreous to vitreous Istr; lignitic to bituminous. 5700': COAL: blk; firm to v firm; subblocky to blocky; hackly fracs, mnr subconchoidal appearing fracs or cleats; subvitreous to vitreous Istr; lignitic to bituminous. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · 5765': CLAYSTONE: It to med dk brnish gry, mnr grnish gry hues; firm to occ v firm; subblocky to mr subplaty; dull earthy lustr; appears massive; mnr assoc med to dk gry grain sprtd sndstn. 5855': COAL: blk; firm to v firm; subblocky to blocky; hackly fracs, mnr subconchoidal appearing fracs or cleats; subvitreous to vitreous Istr; interbedded with claystone and mnr snd; lignitic to bituminous. 5945': CLAYSTONE: brnsh blk-olive blk w/occ gry cast; firm-vry firm; brittle when probed; irreg fract; ctgs as blocky-tabular and subtab; massive; lacking distinct bedg struct; rrly grdg tIsilty and vry fn sandy, med brnsh gry claystn. 6080': SAND: med gry overall; dominant trnsl and milky qtz and felds; rnd-sbrnd w/mnr scat ang grs; mod-prly srtd; mod-hi sphrcty; com lithic frags & assoc coal; occ grdg tIprly ind, friable grain sprtd sndstn. 6215': SANDSTONE: It-med gry overall; dom trnsl and clr w/mnr milky qtz and felds; mod-well srtd; sbrnd-well rndd; mod ind-firm; grain supported; grdg wlloose, unconsl sand & med gry clystn. 6290': COAL: blk; firm to v firm; subblocky to blocky; hackly fracs, mnr subconchoidal appearing fracs or cleats; subvitreous to vitreous Istr; lignitic to bituminous. 6365': CLAYSTONE: med dusky brn, olive brn and med gry; firm-hard; gen massive; wk aprnt bedg struct vis as spotty lams w/gd para- lIel alignment; ctgs as tab- subtab chips and irreg blocks; earthy luster; waxy-sli gritty texture when scored. 6515': COAL: blk; firm to v firm; subblocky to blocky; hackly fracs, mnr subconchoidal appearing fracs or cleats; subvitreous to vitreous Istr; lignitic to bituminous. 6590': COAL: blk; firm to v firm; subblocky to blocky; hackly fracs, mnr subconchoidal appearing fracs or cleats; subvitreous to vitreous Istr; lignitic to bituminous. 6665': CLAYSTONE: med to dk gry, brnish gry, olive brn, mnr olive gry hues; firm to occ v firm; subblocky to mnr subplaty; earthy lustr; appears massive, with v local faint laminations; grdg wilt gry, fn-medU sand & sandstn. 6750': COAL: black; dom vitreous lustr w/occ subvit; ctgs as irregular blocks & chips; occ Irg tabular to subtab; com vis cleats and fractures; brittle-mod firm; lignitic-bitumenous. 6890': SANDSTONE: It to med gry overall, indiv grains transluc, clr, opaque, gry, blk, brn, mnr grn; fine to med grain, dom upper fine to lower med; fair to occ good sphere; fair to good sort; wk to mod cmtd, in part v wkly calc; in part v mnr clay matrix. 6980': COAL: black; dom vitreous lustr w/occ subvit; ctgs as irregular blocks & chips; oce Irg tabular to subtab; com vis cleats and fractures; brittle-mod firm; lignitic-bitumenous. 7055': SAND: med gry overall; trnsl, clr and opaque qtz and felds grs w/com coal and wthrd lithic frags; mod-pr srtg; fnL-med wI scattered crsL; rnd-sbang; fair to mod sphrcty; gen unconsol; occ- com gr sprtd sndstn w/mnr interstitial clay( <3% bulk); tr calc frags/cement; wk rxn w/HCI 7140': COAL: black; dom vitreous lustr w/occ subvit; ctgs as irregular blocks & chips; occ Irg tabular to subtab; com vis cleats and fractures;lignitic-bitumenous. 7210': SAND: It to med gry overall; indiv grains transluc, clr, opaque; lower fine to upper med, dom fine to lower med; subrnd to oce ang, dom subang; poor to fair sphere; fair to good sort; dom qtz, mnr feld, v mnr lithics. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · 7305': COAL: black; dom vitreous lustr w/occ subvit; ctgs as sm irreg blocks & chips; occ Irg tabular to subtab; com vis cleats and planar-subconchoidal fractures; brittle-mod firm; lignitic to bitumenous. 7385': SANDSTONE: It to med gry overall, indiv grains transluc, clr, opaque, gry, blk, brn, mnr grn; lower fine to occ lower crse grain, dom lower to upper med; subrnd to mnr ang, dom subang; poor to fair sphere, occ good; poor to fair sort; grains commonly supported by clay matrix, in part wkly cmtd; dom qtz, mnr feld, v mnr lithics. 7490': COAL: blk; firm to v firm; subblocky to blocky; hackly fracs, occ v mnr subconchoidal appearing fracs; subvitreous to vitreous Istr; lignitic to bituminous. 7565': SAND: It-med gry; dom tmsl and milky qtz w/com-abd feldspar; mod srtg; dom med w/assoc fnU and crsL grs; sbrnd-sbang; unconsl; grdg w/gr sprtd sndstn and siltstn; abd detrital coal and clay/siltstn frags. 7705': COAL: blk; firm to v firm; subblocky to blocky; hackly fracs, mnr subconchoidal appearing fracs or cleats; subvitreous to vitreous Istr; lignitic to bituminous. 7780': SANDSTONE: It to med gry overall, indiv grains transluc, clr, opaque, gry, brn, blk, grn; lower fine to lower med grain, dom fine to lower med; subrnd to mnr ang, dom subang; fair sphere, occ good; fair to good sort; wkly cmtd, v wk to wkly calc; grains in part supported by v It gry to gryish wht clay matrix; dom qtz, mnr feld, v mnr lithics. 7885': COAL: blk; firm to v firm; subblocky to blocky, mnr subplaty; hackly fracs, mnr to sli com subconchoidal appearing fracs; subvitreous to vitreous Istr; lignitic to bituminous. 7985': SILTSTONE: It-med gry w/com sli brnsh hue; mod firm-prly ind & friable; variably argillaceous; mnr clay cmt (poss kaolinitic); tuffaceous; gradational w/clay- stone and sand/sandstone. 8090': SANDSTONE: med to occ dk gry overall, indiv grains transluc, clr, opaque, gry, brn, blk, grn; fine to upper med grain, dom upper fine to med; subrnd to subang, dom subang; poor to fair sphere, occ good; fair sort; wkly cmtd, v wk to wkly calc; grains in part supported by It gry to med gry wht clay matrix, grading to argillaceous siltst; dom qtz, mnr feld, v mnr lithics. 8230': SILTSTONE: med to dk brnish gry, to occ grnish and olive hues; subblocky to subplaty; firm to occ hard ctgs; dull earthy luster; gritty to sandy tex; mod argillaceous; grades to claystone or fine ss. 8355': CLAYSTONE: med to dk gry, brnish gry, olive brn, mnr olive gry hues; firm to occ v firm; subblocky to mnr blocky and subplaty; dull earthy to occ waxy lustr; appears massive, mnr faint laminations; grades to argillaceous siltst. 8450': SAND: It to med gry overall; indiv grains transluc, clr, opaque; lower fine to upper med, dom fine to lower med; subrnd to occ ang, dom subang; poor to fair sphere; fair to good sort; dom qtz, mnr feld, v mnr lithics. 8450': SAND: It to med gry overall; indiv grains transluc, clr, opaque; lower fine to upper med, dom fine to lower med; subrnd to occ ang, dom subang; poor to fair sphere; fair to good sort; dom qtz, mnr feld, v mnr lithics. 8535': SANDSTONE: It to med brnsh gry/gry, occ dk gry; ind grains transl, clr, opaque, brn, blk, gry, grn; fn-medU; subrnd to subang, dom subang; pr to fair sphrcty, occ gd; fair sortg; com as sand grains floating; sli com grain contact in clay matrix; occ mnr to sli com cmntd ctgs; freq · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · grading to argillaceous siltst; dom qtz & felds; vry mnr lithic frags. 8665': SAND: It-med gry w/com brnsh cast; mod srtd; dom fnU-med; sbrnd-rnd; mod sphrcty; dom loose, unconsl; occ as grain sprtd-sli arg sndstn; com grdg tilt gry and It yelsh brn silt stn and claystn. 8755': SILTSTONE: med to dom dk brnish gry, mnr occ olive hues; subblocky to subplaty, mnr occ splintery to tabular ctgs; firm to occ mod hard ctgs; dull earthy to mnr subresinous luster; gritty to sandy tex; mod argillaceous; grades to claystone or fine ss. 8850': CLAYSTONE: med to dk gry, brnish gry, olive brn, mnr olive gry hues; firm to occ v firm; subblocky to mnr blocky and subplaty; dull earthy to occ waxy lustr; appears massive, mnr faint laminations; grades to argillaceous siltst. 8850': CLAYSTONE: med to dk gry, brnish gry, olive brn, mnr olive gry hues; firm to occ v firm; subblocky to mnr blocky and subplaty; dull earthy to occ waxy lustr; appears massive, mnr faint laminations; grades to argillaceous siltst. 8935': SAND: It to med gry overall; indiv grains transluc, clr, opaque, brn, blkish brn, gry, grn; lower fine to upper crse, dom med to lower crse; subrnd to sli com ang, dom subang; poor to occ fair sphere; poor sort; dom qtz, mnr to sl¡ com feld, mnr lithics. 9025': SILTSTONE: med to dk gry, brnish gry, mnr olive and It grn hues; subblocky, subplaty, and splintery ctgs; firm to occ mod hard ctgs; dull earthy to subresinous luster; gritty to sandy tex; mod argillaceous; grades to claystone or fine ss. 9135': SANDSTONE: It gry w/com pale yelsh hue; dom milky and trnsl qtz wI lesser felds; mod- well srtd; dom fn-medL; IT scat crs grs; rnd-sbrnd; good to fair sphrcty; abd detrtital coal frags; mnr lithics; com pr plast clay as matrix; grdg wI med yelsh brn arg siltstn, claystn & gr sprt-kaol sandstn. 9320': SAND: med brnsh gry, bcmg It yelsh-brnsh gry after washing; dom milky & trnsl grs; qtz » felds; mod srtg; fn-med w/mnr medU; sbrnd to sbang; occ gd sphrcty; com assoc interstitial clay and friable cly/siltstns; mnr sndstn; abd detrital coal frags; wk tr lithic frags. 9475': SILTSTONE: med-It grysh brn; mod firm-friable; gritty on fresh surfaces; vry argill, gen w/earthy luster, aprnc; grdg wI claystn, sandstn and sand. 9545': SAND: med brnsh gry, bcmg It yelsh-brnsh gry after washing; dom milky & trnsl grs; qtz »felds; mod srtg; fn-med w/mnr medU; sbrnd to sbang; occ gd sphrcty; com assoc interstitial clay and friable cly/siltstns; mnr sndstn; abd detrital coal frags; wi< tr lithic frags. 9655': SAND:lt-med gry w/pervasive It brn cast; dom trnsl, milky and opaque grs; mod-prly srtd; fnL-medU; rnd-sbrnd w/scattered ang; sands bcmg incrsgly crs; mnr incrs in lithics; mod arg; grdg dom w/siltstn & claystn; vry com-occ sandstn with weak calc/kaolin cmnt; gen friable w/gd vis grain contact. 9775': SANDSTONE: It to med gry, brnsh gry, occ dk gry; indiv grains transl, clr, opaque, gry, blk, brn, grn; pr srtg; fnL-occ crsU; dom med-crsL; sbrnd to ang, dom sbang; poor to fair sphrcty; com clayey, kaolinitic matrix; grdg to argillaceous siltstn; dom qtz, mnr to sli com feld; v mnr-mnr lithics; mnr-sli com coal stringers; larger ctgs/frags indic slough. 9910': CLAYSTONE: It-med gry, occ dk gry; com brnsh hue; mod firm to prly ind/friable; earthy lustr; occ brtl under probg; tufface- ous; grdg w/arg siltstn and occ sndstn; com coal partings from thin stringerslslough; non-wkly calc (scat wk rxn w/HCI). 9990': COAL: blk; firm to v firm; subblocky to blocky; hackly fracs, occ subconchoidal appearing fracs; subvitreous to vitreous Istr; lignitic to bituminous. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · 10055': CLAYSTONE: dusky brn, med grysh brn, It gry; firm-brittle; gen massive apmce; ctg as blocky, irreg-subtab; rr vis bedg con- tact wIlt gry sltstn or sndstn; mnr assoc fn, ang-sbang sand grs (gen<5% bulk); com coal partgs from slough/thin seams. 10165': SAND: It to med gry overall; indiv grains transluc, clr, opaque, brn, blkish brn, gry, grn; lower fine to oce lower crse, dom upper fine to upper med; subrnd to oce ang, dom subang; poor to fair sphere; poor sort; dom qtz, mnr feld, v mn to mnr lithics, 10255': SILTSTONE: med to dk gry, brnsh gry, occ mnr grnsh gry; sub- blocky to subtab, occ subplaty ctgs; firm to mod hard; vry dull earthy to occ subresinous luster; occ mod friable; gritty tex; fract mod argillaceous; grdg to claystn or fn sndstn. 10340': SAND: med yelsh brn-orgsh brn btwn 10355-65';(med gry-gry above and below said interval); ind grs frosty, opaque, trnsl, clr; mod-well srtd; fn-medL wI scattered medU-crsL; sbang to sbmd; unconsol; com coal part- gs (detrital & from in-situ fm); tr assoc siltstn and IT fn sndstn (combined <3%). 10430': COAL: blk; firm to v firm; subblocky to blocky; hackly fracs; subvitreous to vitreous Istr; lignitic to bituminous. 10520': SAND: med gry w/sli bm hue; pr srtg; fnU-crs; rnd-sbang > ang; dom cloudy, trnsl, opaque wI assoc grnsh and gry brn; poor srtg; fnU-crs; unconsol; mnr friable, arg sandstn; grdg dom w/siltstn and claystn 10600': CLAYSTONE: dk yelish brn to med/dk gryish brn, brnish gry; firm to v firm; subblocky to subtabular ctgs; commonly massive with rare to v mnr laminations; grades to argillaceous siltstone. 10680': SAND: med gry w/sli brn hue; pr srtg; fnU-crs; rnd-sbang > ang; dom cloudy, trnsl, opaque wI assoc grnsh and gry brn; poor srtg; fnU-crs; unconsol; mnr friable, arg sandstn; grdg dom w/siltstn and claystn 10785': COAL: blk; dull to subresinous, waxy luster; hard-brittle; irr- egular, hackly and subplanar to subconchoidal fracture; vis cleats esp on Irg ctgs; com to abundant as slough (.5-2" dia.) lignitic to bitumenous. 10865': SAND: gry-It gry w/slight brnsh hue; dom trnsl and milky grs wI lesser opaque, grn, brn; mod to prly srtd; fn-med»crs; sbrnd to sbang; unconsl; com-abd detrital coal frags; trace to rare kaolinitic, friable sand- stn; cont grdg w/siltstn and claystn; abd coal slough. 10955': CLAYSTONE: med brn-dusky brn; firm-hard/brittle; earthy to subresinous luster; com gritty aprnc on fresh surf; massive; IT wk vis lams; grdg w/light gry, prly ind, tuffaceous siltstn, sandstn and unconsol sand. 11095': SAND: It-med gry; dom milky and trnsl grs > clr and opaque; tr to rr grn, brn; com detrital coal frags/partgs; tr lithics; grdg btwn vry prly and mod srtd; 11120': SAND: It-med gry; fn-med; crs; vcrs; sbrnd-sbang; com assoc tuffaceous sandstn; cont grdg wI siltstn & claystn. 11180': COAL: blk; hard-sli brittle; subres-subvit luster; ctgs irreg, sub-blocky, tabular; com vis cleats on Irg ctgs; hackly, planar to subplanar and sub conchoidal fracture; lignitic to bitumenous; ctg size range from 0.1"-2". · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · 11265': SAND: med gry, gry, It brnsh gry; dom milky,trnsl wllesser opaque and clr grs; mod- poorly sorted; fn-crs; dom med-crsL; ang-sbang, bcmg sbrnd in finer grained spls; gen unconsol; occ to rare med gr, friab sandstn; tr-mnr siltlclaystn; incrsd abd of multi-colored lithic frags; slower ROP assoc wlcoarser grained sands. 11350': NOTE: overall coarsen'g of lith @11347'; incrsd lithics as %bulk; assoc inrsd fluid losses; 100% dull yellow spl fl from washed/treated spls. ............................................ I I II · · · Forest Oil · HALLIBURTON Alaska · Miline Point · Survey Report for West Foreland #2 Rec - Foreland #2 MWD · · Measured Vertical Vertical Dogleg · Depth Incl. Azim. Depth Northings Eastings Section Rate (ft) (ft) (ft) (ft) (ft) (O/100ft) · 0.00 0.000 0.000 0.00 O.OON O,OOE 0.00 · 100.00 1.110 16.670 99.99 0.93 N 0.28E 0.88 1.110 200.00 2.040 43.030 199.96 3,16 N 1.77 E 2,88 1.156 · 300.00 2,660 51.090 299,87 5.92N 4.79E 5.19 0.701 400.00 4.360 68.410 399.68 8.77 N 10.13 E 7.28 1.985 · 500.00 4.930 62.870 499.35 12.13N 17.49 E 9.58 0.725 · 600.00 4,660 64.240 599.00 15.86 N 24.97 E 12.23 0.293 700.00 4.160 72.800 698.71 18.69 N 32,10 E 14.04 0.825 · 800.00 1.770 130.340 798.59 18.77 N 36.74 E 13.47 3.540 900.00 2.210 127.680 898.53 16.59 N 39.44 E 10.94 0.449 · 1000.00 2.170 116.730 998.45 14.56 N 42.66 E 8.48 0.420 · 1100.00 1.740 102.850 1098.39 13,37 N 45.83E 6.86 0.637 · 1200.00 2.410 24.370 1198.35 14.95 N 48.18 E 8.10 2.676 1300.00 2.140 347.190 1298.27 18.68 N 48.6$'£ 11.73 1.473 · 1400.00 1.910 348.530 1398.21 22.14 N 47.89 E 15.26 0.235 · 1500.00 1.790 356.980 1498.16 25.33 N 47.47£ 18.48 0.298 1600.00 1.360 357.100 1598.12 28,07N 47.33 E 21.21 0.430 · 1700.00 1.130 7.120 1698.10 30.24 N 47.39 E 23.35 0.316 1800.00 0.480 49.520 1798.09 31.49 N 47.83 E 24.52 0.840 · 1900.00 1.180 83.260 1898.08 31.88 N 49.18 E 24.73 0.825 · 2000.00 0.990 91.420 1998.06 31.98 N 51.06 E 24.56 0.244 2100.00 0.990 11.400 2098.05 32.81 N 52.10 E 25.24 1.273 · 2200.00 1.390 4.500 2198.03 34,86 N 52.36 E 27.23 0.424 2300.00 1.370 4.230 2298.00 37.26 N 52.55 E 29,59 0.021 · 2400.00 0.990 15.000 2397.97 39.29 N 52.86 E 31.55 0.438 · 2500.00 0.870 19.490 2497.96 40.84 N 53.33 E 33.02 0.140 · 2600.00 1.240 36.030 2597.94 42.43 N 54,22 E 34.47 0.476 2700.00 1.790 60.150 2697.91 44.08 N 56.21 E 35.83 0.831 · 2800.00 t.970 69.890 2797.86 45.45 N 59.18 E 36.77 0.366 2867.00 2.390 69.910 2864.81 46.33 N 61.58 E 37.31 0.627 · 2956.18 1.930 70.352 2953.92 47.47 N 64.74 E 38.00 0.516 · 3044.88 2.090 70,831 3042.57 48.50 N 67.67 E 38.61 0.181 3106.43 2.200 71.150 3104.08 49.25 N 69.85 E 39.05 0.180 · 3162.06 1.540 72.630 3159.68 49.82 N 71.57 E 39.38 1.189 3219.73 0.410 136.680 3217.34 49.90 N 72.45 E 39.33 2.444 · 3281.36 0.810 221.820 3278.97 49.42 N 72.32 E 38.87 1.422 · 3362.57 1.880 242.810 3360.15 48.38 N 70.75 E 38.06 1.429 3404.57 1.860 243.240 3402.13 47.76 N 69.53 E 37.62 0.058 · 3485.81 1.840 241.940 3483.33 46.55 N 67.20 E 36.75 0.057 3527.82 1.910 239.940 3525.32 45.88 N 66.00 E 36.25 0.228 · 3608.90 1.730 244.310 3606,35 44,68 N 63,73 E 35.37 0.280 · 3650.95 1.790 247.020 3648.38 44.15 N 62.55 E 35,01 0.244 · 3712.64 1.800 249.960 3710.04 43.44 N 60.75 E 34.56 0.150 3774.29 1.580 254.890 3771.67 42,88 N 59.02 E 34,25 0.427 · 3835.98 1.550 256,660 3833.33 42.47 N 57.39 E 34,07 0.092 · 3897.72 1.520 249.760 3895.05 41.99 N 55.81 E 33.82 0.303 3959.37 1.510 255.450 3956.68 41,51 N 54.25 E 33.55 0.244 · 4021.03 1.520 254.510 4018,32 41.08 N 52.68 E 33.35 0.043 4082.70 1.410 245.870 4079.97 40.56 N 51.20 E 33.04 0.400 · 4144.29 1.460 253.580 4141.54 40,02 N 49.75 E 32.71 0.324 · · 7 November, 2004 - 13:07 Page 10f4 DrillQuest 3.03.02.005 · · · · Forest Oil · HALLIBURTON Alaska · Miline Point · Survey Report for West Foreland #2 Rec - Foreland #2 MWD · · Measured Vertical Vertical Dogleg · Depth Incl. Azim. Depth Northings Eastings Section Rate (ft) (ft) (ft) (ft) (ft) (O/100ft) · 4205.80 0,990 248.790 4203.04 39.61 N 48.51 E 32.47 0.781 · 4267.51 1.180 251.000 4264.74 39,21 N 47.41 E 32.23 0.315 4329,20 1.190 244.380 4326.41 38.73 N 46.23 E 31.92 0.222 · 4390.85 1.340 247.370 4388,05 38.17 N 44.99 E 31.54 0.266 4452.50 1.180 258.400 4449.68 37,77 N 43.70 E 31,32 0.470 · 4514.01 1,020 252.040 4511.18 37.47 N 42.56 E 31.18 0.327 · 4575.72 0.910 262.040 4572.88 37.23 N 41.55 E 31.09 0.325 4637.25 1.080 260.530 4634.40 37.07 N 40.50 E 31.07 0.280 · 4698.83 0.990 255.240 4695.97 36.84 N 39.41 E 31.00 0.213 4760.46 0.990 266,490 4757.59 36.67 N 38.36 E 30.98 0.315 · 4822.05 0.960 267.880 4819.17 36.62 N 37.32 E 31.01 0.062 · 4883.57 1.050 264.500 4880.69 36.55 N 36.24 E 31.15 0.175 · 4944.92 0.910 265.680 4942.03 36.46 N 35.20 E 31.20 0.231 5012.07 0.880 267.620 5009.17 36.40 N 34.15E 31.29 0.063 · 5073.69 0.770 278.960 5070.78 36.44 N 33.27 E 31.46 0.319 · 5135.15 0.500 285.030 5132.24 36.57 N 32.~)QE 31.68 0.452 5196.72 0.620 271.260 5193.80 36,65N 32.01 E 31,84 0.292 · 5258.36 1.010 274.260 5255.44 36.70N 31.13 E 32.01 0.636 5319.85 1.030 325.090 5316.92 37.19 N 30.28 E 32.62 1.424 · 5381.29 2.180 342.130 5378.34 38.76 N 29.60 E 34.26 2.006 · 5442.75 3.070 337.970 5439.73 41.40 N 28.63 E 37.01 1.480 5504,35 3.560 339.710 5501..23 44.72 N 27.34 E 40.48 0,812 · 5565,95 4.050 348.470 5562:69 48.64 N 26.25 E 44.52 1.232 5627.53 4.580 3o\t).2~ 5624.10 53.16 N 25,23 E 49.13 0.901 · 5689.05 4.790 342.480 5685.41 58.00 N 23.87 E 54.11 0.609 · 5750.40 5.790 344.020 5746.50 63.42 N 22.25 E 59.70 1.646 · 5811 :86 7.160 343,790 5807,57 70.08 N 20.33 E 66,56 2.229 5873.35 7.590 344.520 5868.55 77.67 N 18.17E 74.38 0.716 · 59$4.76 8;250 346.530 5929.37 85.86 N 16.06 E 82.79 1.165 5996.38 9.320 351.200 5990.27 95.09 N 14.27 E 92.18 2.086 · 6057.95 10.480 352.980 6050.92 105.58 N 12.82 E 102.77 1.948 · 6119.47 11.040 350.570 6111,36 116.94 N 11.17 E 114.25 1.168 6181.02 13.020 347.000 6171.55 129.51 N 8.65E 127.05 3,435 · 6242.54 15.640 344.880 6231.16 144.27 N 4.93E 142.18 4.343 6304.15 18.050 344.370 6290.12 161.48 N 0.19 E 159.89 3.919 · 6365.91 19.300 345.320 6348.63 180.57 N 4.98W 179.51 2.083 · 6427.53 20.170 345.380 6406.63 200.70 N 10.24 W 200.18 1.412 6489.07 20.980 345.800 6464.24 221.65 N 15.62 W 221.67 1.338 · 6550.56 22.570 345.840 6521.34 243.76 N 21.21 W 244.34 2,586 6612,07 24.150 345.060 6577.81 267.37 N 27.34 W 268.57 2.617 · 6673.60 25.550 344.670 6633.64 292.33 N 34,09 W 294.23 2.291 · 6735.05 26.610 344.250 6688,83 318.36 N 41.33 W 321.01 1.751 · 6796.55 28.310 345.060 6743.40 345.70 N 48.83 W 349.13 2.830 6858.08 28.770 344.540 6797.45 374.07 N 56.54 W 378.30 0.850 · 6919.58 29.880 345.680 6851.07 403.18 N 64.27 W 408,20 2.020 · 6981,09 31.390 345.870 6904.00 433.56 N 71.97 W 439.36 2.460 7042.25 32.970 346.310 6955.76 465.18 N 79,80 W 471.76 2.612 · 7103.77 34.460 347.130 7006.93 498.41 N 87.64 W 505.76 2.532 7165.15 35,520 347.620 7057.22 532.76 N 95.33 W 540,84 1.787 · 7226.48 38,300 348.270 7106.25 568.78 N 103.02 W 577.58 4.577 · · 7 November, 2004· 13:07 Page 20f4 DrillQuest 3.03.02.005 · · · · Forest Oil · HALLIBURTON Alaska · Miline Point · Survey Report for West Foreland #2 Ree - Foreland #2 MWD · · Measured Vertical Vertical Dogleg · Depth Incl. Azim. Depth Northings Eastings Section Rate (ft) (ft) (ft) (ft) (ft) (O/10Oft) · 7226.48 38.300 348.270 7106.25 568.78 N 103.02W 577.58 · 7287.85 39.860 347.300 7153.89 606.59 N 111,21 W 616.16 2.730 7349.22 41.310 347,070 7200.49 645.52 N 120.06 W 655.94 2,375 · 7410.63 42.270 347.150 7246.28 685.41 N 129.19W 696.72 1.566 7472.07 44.720 347.310 7290.85 726.65 N 138.54 W 738.86 3,992 · 7533.56 46.140 347.500 7334.00 769.40 N 148.09W 782.52 2.320 · 7595,05 46.710 347,820 7376.38 812.92 N 157.61 W 826.94 1.001 7655.97 47.570 348.510 7417,82 856.62 N 166.77 W 871.49 1,638 · 7717.40 47.270 348.840 7459.39 900.97 N 175,65 W 916.65 0.628 7778.96 46.630 347.230 7501.41 944.98 N 184.97W 961.53 2.176 · 7840.38 47.720 346.690 7543.16 988.86 N 195.14W 1006.40 1.888 · 7901.92 47,980 347.000 7584.46 1033.29 N 205.52 W 1051.84 0.564 · 7963.36 48.190 346.960 7625.50 1077.84 N 215.82 W 1097.~ 0,345 8024.85 48.760 347.670 7666.27 1122,75 N 225.9~'W 1143,26' 1,267 · 8086.29 48.540 347.740 7706.86 1167.81 N 235.75W 1189.26 0.368 · 8147.82 48.280 347.640 7747.70 1212.77 N 245.56 W 1235.15 0.440 8209.33 48,000 347.640 7788.75 12~7.5~N 255.37 W 1280,82 0.455 · 8271.31 47.000 348.480 7830.62 1302.23 N 264.82 W 1326.41 1,898 8332.90 48.360 349.890 7872.09 1346.~ N 273.36 W 1371.89 2.782 · 8398.55 50.160 351.560 7914.93 1396;04 N 281.37W 1421.62 3.351 · 8460.13 51.090 352.490 7954.(}() 1443.18 N 287.97 W 1469.22 1.909 8521.63 52.750 351.770 7991.93 1491.14 N 294.60 W 1517.62 2.852 · 8583.27 52,860 352.550 802tU9 1539.78 N 301.30 W 1566.72 1.024 8644.60 53.680 3$2.740 8065.87 1588.53 N 307.59W 1615.87 1.360 · 8706,09 51.740 352.640 8103.12 1637.05 N 313.81 W 1664.79 3.158 · 8767.65 49.430 351.400 8142.21 1684.14 N 320.41 W 1712.34 4.062 · 88~.05 48.280 350.560 8182.60 1729.81 N 327.65 W 1758.57 2.138 8890.61 46.600 352.380 8224.24 1774.64 N 334.39 W 1803.91 3.491 · 8952.07 44.960 351.830 8267,10 1818.27 N 340.43 W 1847.95 2.744 9013;66 44. 760 351.610 8310.76 1861.26 N 346.69 W 1891.40 0.411 · 9075.29 41.580 350.290 8355.70 1902,89 N 353.31 W 1933.55 5.364 · 9136,84 41.790 350.630 8401.67 1943.26 N 360.09 W 1974.46 0.501 9198.43 42.300 350.830 8447.41 1983.97 N 366.74 W 2015.70 0.856 · 9259.98 40.970 351.370 8493,41 2024.37 N 373.06 W 2056.59 2.238 9321.46 40.710 351.900 8539.92 2064.15 N 378.91 W 2096.79 0.705 · 9383.00 38.900 352.240 8587.20 2103.16 N 384.35 W 2136.19 2.962 · 9444,37 40,210 353.040 8634,51 2141.92 N 389.35 W 2175.26 2.290 9505.93 43.050 353.490 8680.52 2182.53 N 394.14 W 2216.15 4.639 · 9567.46 44.960 353.370 8724.78 2224,99 N 399,04 W 2258.88 3.107 9629.03 46.910 353.120 8767.60 2268.93 N 404.24 W 2303.10 3.181 · 9690.58 49.080 352.560 8808,78 2314.30 N 409.95 W 2348.83 3,590 · 9752.03 49.400 353.280 8848.90 2360.49 N 415,68 W 2395.37 1.029 · 9813.53 50.800 353.360 8888.35 2407.35 N 421.17W 2442.54 2.279 9875.03 50.530 354.350 8927.33 2454.64 N 426,26 W 2490.08 1.320 · 9936.61 50.510 355,470 8966.49 2501.99 N 430.48 W 2537.55 1.404 · 9998.11 50.970 355.140 9005.41 2549.44 N 434.38 W 2585.09 0,856 10059,66 51.060 355.350 9044.13 2597.12 N 438.34 W 2632.85 0.303 · 10121.17 50.910 355.260 9082.85 2644.76 N 442.25 W 2680.57 0.269 10182.65 51.030 356.000 9121.57 2692.37 N 445.89 W 2728.23 0.955 · 10243.73 50.460 356.050 9160.22 2739.56 N 449.17 W 2775.41 0.935 · · 7 November, 2004 - 13:11 Page 10'2 DrillQuest 3.03.02.005 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Measured Vertical Vertical Dogleg Depth Incl. Azim. Depth Northings Eaatings Section Rate (ft) (ft) (ft) (ft) (ft) (o/10Oft) 10305.21 50.390 356.200 9199.38 2786.84 N 452.37 W 2822.67 0.220 10366.82 50.220 355.810 9238,73 2834.13 N 455.68 W 2869.96 0,560 10428.26 50.510 356.180 9277.93 2881.33 N 458.98 W 2917.17 0.662 10489.71 50.440 357.440 9317.04 2928.65 N 461.62 W 2964.40 1.586 10551.07 50.600 358.230 9356,05 2975,98 N 463.41 W 3011.51 1.027 10612.62 52.320 359.060 9394.40 3024.11 N 464.54 W 3059.33 2.987 10657.63 53.330 359.030 9421.59 3059.96 N 465.14 W 3094.92 2.245 10704,04 53.550 358.830 9449.24 3097.24 N 465.84 W 3131.92 0.587 10765.61 53.760 358.890 9485.73 3146.82 N 466.82 W 3181.16 0.350 10827.10 54.400 358.510 9521.80 3196.60 N 467.95 W 3230.62 1.155 10888.70 54.540 358.190 9557.60 3246.71 N 469.40 W 3280.44 0.480 10950.22 52.360 358.940 9594.23 3296.11 N 470.64 ~'. 3329.54 3.676 11011.79 53.440 357.710 9631,37 3345.20 N 472.08W 3378.3if, 2.370 11073.36 53.590 357.910 9667.98 3394.66 N 473.97W 3427.59 0.357 11135.04 52.960 358.270 9704.87 3444.07 N 475.62·W 3476.75 1.123 11196.55 53.160 358.240 9741.83 3493.21 N 477:1? W 3525.62 0.327 11224.23 53.150 357.900 9758.43 3515.35.N 477.86 W 3547.65 0.984 11257.93 53.740 357.640 9778.50 3542.40 N 478.91 W 3574.58 1.857 11319,53 55.010 356.230 9814,38 3592:40 N 481.60W 3624.46 2.777 11387.00 55.010 356.230 9853.07 3647.55 N 485.23 W 3679.59 0.000 All data is in Feet (US Survey) unless otherwise state<!. r;>ire~ons ar\é:t .çOôrcJinates are relative to Grid North. Vertical depths are relative to Well. Northil)Qiland EaStiOgll a!'litre1ative to Well. The Dogleg Severity is in Degrees per 1()()f~{US$IJ~Y)' Vertical Section is from Well and calculated along an Azimuth of 352.0000 (Grid). Coordinate Systemi~N~?7 Alá$!«i State PItIInes, Zone 4. Grid ConvergenœÌiÚSurfåcEI is -1.5110. Magnetic Convergence at Surface is -21.548°(16-Sep-04) Based upon MinimI.lrt'tCurvafí.lt$týpe calculations, at a Measured Depth of 11387.00ft., The Bottom Hole Displ!lcement is 3679.69ft., in the Direction of 352.422° (Grid). Comments Measured Depth (ft) 11387.00 Station Coordinates TVD Northings Eaatings (ft) (ft) (ft) Comment 9853.07 3647.55 N 485.23 W Projection to bit 7 November, 2004 - 13:11 Page 2 of 2 Dri//Quest 3.03.02.005 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · MiSW~~ Operator: FOREST OIL CORP. Report For: Mr. Fred Brent Well Name: West Foreland # 2 Contractor: Kuukpik Drilling Report For: Mr. F.Pluid I Mr.T.Peter DRILLING ASSEMBLY Bit Size 9.875 in HCM605 Nozzles 3x20 I 1/32" Drill Pipe Size 4.5 in Drill Pipe Size 4.5 in Drill Collar Size 6.61 in Sample From Flow Line Temp Depth/TVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/R100 R6/R3 PV YP IOs/l Om/30m Gel API Fluid Loss HTHP FL Temp Cake APIIHTHP Unc Ret Solids Correct Solids Oil Uncorr Water OiVWater Ratio Alkal (Pom) CI Whole Mud Salt Lime E-Stability OF ft Ib/gal s/qt of cP Ib/lOOfF Ib/lOOfF cc130 min cc/30 min 1/32" %Vol %Vol %Vol %Vol mgil %Wt Iblbbl CASING Surface l3.875in (a}3003ft (3001TVD Intermediate in (a}ft (TVD) Intermediate Production or Liner 4.4(a)250°F --/2 8 6.33 72 20 78/22 1.2 42500 24.96 1.56 1171 Date Spud Date Water Depth Oil-BASED MUD REPORT No. 17 9/30/2004 Depth/TVD 5132 ft I 5129 ft 9/1712004 Mud Type VersaDril Activity Drilling Field/Area: West Foreland Description: Development Location: West MacArthur River U M·I Well No.: 11857 MUD VOLUME (bbl) Hole 610.2 Active Pits 441.8 Total Circulating Vol 1052 In Storage 547 Pit(a) 10:00 5000/4997 9.5 92 150 65/45 37/27 15/12 20 25 12/15/17 4.8(a)250°F --/2 8 6.43 73 19 79/21 1.2 40000 24.78 1.56 975 REMARKS AND TREATMENT Hole taking mud during trip, about 2 bph. Build 70 bbls of Brine water to maintain chlorides in anticipation oftaking water from injection zone. Reclaimed 12 bbls of fluid with SWACO. Length 4373 ft Length 607 ft Length 93 ft MUD PROPERTIES Pit(a)23:45 116 5132/5129 9.6(a) 100°F -95 150 76/50 41131 16/15 26 24 16/18/20 TIME DISTR Rig Up/Service Drilling TrijJping Non-Productive Tim Rig Repair Condition Hole Testing Cementing Wait on Cement Rig Repair 4 8 12 CIRCULATION DATA Pump Make lis Williams WHlOl' TSM 1000 HP Pump Size 4.5 X lO.in 5.5 X 9.in Pump Cap 1.962 gaVstk 2.638 gaVstk Pump stk/min 120(a)95% 120(a)95% Flow Rate 552 gaVmin Bottoms Up 41.3 min 9900 stk Total Circ Time 80 min 19210 stk Circulating Pressure _ 2350 psi PRODUCTS USED LAST 24 HRS Products Size M-I BAR (4-PL Y LINED BAG) 50 LB BG ENGINEERING SERVICE 1 EA MAPCO 200 1 GA TK CALCIUM CHLORIDE PWD 80 LB BG MIX II FINE 25 LB BG Amt 282 2 420 268 20 SOLIDS EQUIP Centrifuge Derrick Shaker Derrick Shaker Size Hr o 5 5 180/180/180 125/125/125 MUD PROPERTY SPECIFICATIONS Weight 9.5 Viscosity 60-80 Filtrate HTHP <8 REMARKS Finish trip out. Change out BRA. Run in hole. Stop at shoe to work on top drive. Run in to bottom. Ream down last two stands. Resume drilling ahead. (bbl) 10 71 o 10 o o o o 30 o RIG PHONE SOLIDS ANALYSIS Salt Wt% 24.96 Salt Conc,lblbbl 23.29 Adjusted Solid % 6.33 Oil/Water Ratio 78/22 Averge SG Solids 4. LowGr% .8 Low Gr Wt, Iblbbl 7.57 High Gr % 5.5 High Gr Wt Iblbbl 80.71 MUD RHEOLOGY & HYDRAULICS np/na Values 0.604/0.207 kp/ka (lb"s^n/lOOft2) 1.233/11.418 Bit Loss (psi! %) 318113.5 Bit HHP (hhp I HSI) 102/1.3 Bit Jet Vel (ftls) 192 Ann. Vel DP (ftlmin) 174.88 Ann. Vel DC (ftlmin) 250.9 Crit VelDP (ftlmin) 413 Crit Vel DC (ftlmin) 438 ECD (a} 5132 (lb/gal) 9.96 DAILY COST CUMULATIVE COST 907-776-7137 WAREHOUSE PHONE 907-776-8680 $ 17,531.26 $ 257,637.89 Last 24 Hrs MUD VOL ACCTG Oil Added Water Added Mud Received Other Dumped Shakers Evaporation Centrifuge Fonnation Left in Hole M-I ENGR I PHONE Warren Wilkes Lucian Angelescu · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · MiSWAC~ =-== Operator: FOREST OIL CORP. Report For: Mr. Fred Brent Well Name: West Foreland # 2 Contractor: Kuukpik Drilling Report For: Mr. F.Pluid I Mr.T.Peter DRILLING ASSEMBLY Bit Size 9.875 in HCM605 Nozzles 3x20 I 1/32" Drill Pipe Size 4.5 in Drill Pipe Size 4.5 in Drill Collar Size 6.61 in Length 5025 ft Length 607 ft Length 93 ft Sample From Flow Line Temp DepthlTVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/RlOO R6/R3 PV YP lOs/1 Om/30m Gel API Fluid Loss HTHP FL Temp Cake APIIHTHP Unc Ret Solids Correct Solids Oil Uncorr Water Oil/W ater Ratio Alkal (porn) Cl Whole Mud Salt Lime E-Stability OF ft lb/gal s/qt of cP lb/100ft2 lb/] 00ft2 cc/30 min cc/30 min 1/32" %Vol %Vol %Vol %Vol mg/l %Wt lblbbl Oil-BASED MUD REPORT No. 18 5784 ft I 5784 ft VersaDril Drilling Date 10/1/2004 Spud Date 911712004 Water Depth Field/Area: Description: Location: Well No. : CASING Surface 13.875in ~3003ft (3001 TVD) Intennediate in ~ft (TVD) Intennediate Production or Liner MUD PROPERTIES Pit(å¿23:45 138 5792/5784 9.5@134°F 74 150 67/45 37/28 ]4/13 22 23 ]5/17/]8 4.4@.-250°F :-/2 9 7.4] 70 2] 77/23 1.2 4] 000 23.4 1.56 1074 Out(å¿13:45 139 5500/5496 9.5@130°F 80 ]50 78/53 45/34 17/15 25 28 16/19/22 5(å¿250°F - --/2 8.5 7.18 70 21.5 77/23 1.35 35000 20.3 1.76 885 REMARKS AND TREATMENT Rebuild LCM pill. Add Base Oil for rheology. Add Brine water for volume and OWR. Change screens on shaker # I from 125 to 180 mesh. Reclaimed 19 bbls of fluid with Swaco Unit. Depth/TVD Mud Type Activity West Foreland Development West MacArthur River U 11857 MUD VOLUME (bbl) Hole 667.9 Active Pits 436.1 Total Circulating Vol 1104 In Storage 537 CIRCULATION DATA Pump Make llis Williams WHIO< TSM 1000 HP Pump Size 4.5 X lO.in 5.5 X 9.in Pump Cap 1.962 gal/stk 2.638 gal/stk Pump stk/min 120@95% 120@95% Flow Rate 552 gal/min Bottoms Up 44.9 min 10784 stk Total Circ Time 84 min 20160 stk Circulating Pressure 2900 psi PRODUCTS USED LAST 24 HRS Products Size Amt ENGINEERING SERVI( 1 EA 2 MAPCO 200 1 GA TK 4998 VERSACOAT HF 55 GA DM 1 VERSATHIN HF 55 GA DM 1 CALCIUM CHLORIDE 80 LB BG 10 MIX II FINE 25 LB BG 20 Pit(âJ07:30 118 5255/5255 9.5(âJ118°F -88 150 80/55 47/35 18/16 25 30 17/21/22 4.8(âJ250°F --/2 8 6.4 70 22 76/24 1.5 41500 22.79 1.95 720 Size Hr 2 24 24 SOLIDS EQUIP Centrifuge Derrick Shaker Derrick Shaker 180/180/180 180/1801180 MUD PROPERTY SPECS Weight 9.5 Viscosity 60-80 Filtrate HTHP <8 REMARKS Drilling ahead. Losing fluid downhole due to seepage at about 3 bph. Pump 25 bbl LCM pill to combat losses. Drill to 5255'. Flow check, positive. Shut in, 33 psi on caing, Open up and circulate out. Mud contaminated with water. Resume drilling ahead, TIME DISTR Last 24 Hrs MUD VOL ACCTG (bbl) SOLIDS ANALYSIS MUD RHEOLOGY & HYDRAULICS Rig Up/Service Oil Added 119 Salt Wt% 23.4 np/na Values 0.57410.219 Drilling 21 Water Added 0 Salt Conc,lblbbl 22.47 kp/ka (lb·s^nllOOft2) 1.337/9.707 Tripping Mud Received 0 Adjusted Solid % 7.41 Bit Loss (psi I %) 315/10.9 Non-Productive Tim Other 43 Oil/Water Ratio 77/23 Bit HHP (hhp I HSI) 101/1.3 Circulate 1 Dumped 0 Averge SG Solids 3.4 Bit Jet Vel (ft/s) 192 Monitor Well 2 Shakers 0 Low Gr % 3.8 Ann, Vel DP (ftImin) 174.88 Testing Evaporation 0 Low Gr Wt, lblbbl 34.61 Ann, Vel DC (ftImin) 250.9 Cementing Centrifuge 0 High Gr % 3.6 Crit Vel DP (ftImin) 392 Wait on Cement Formation 38 High Or Wt lblbbl 52.96 Crit Vel DC (ftImin) 417 Rig Repair Left in Hole 0 BCD @j 5784 (lbl"l] 9.84 M-I ENGR I PHONE RIG PHONE WAREHOUSE PHONE DAILY COST CUMULATIVE COST Warren Wilkes Lucian Ange1escu 907-776-7137 907-776-8680 $ 15,709.14 $ 273,347,03 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Mi SWACO--- Operator: FOREST OIL CORP. Report For: Mr. Fred Brent Well Name: West Foreland # 2 Contractor: Kuukpik Drilling Report For: Mr. F.Pluid I Mr.T.Peter DRILLING ASSEMBLY Bit Size 9.875 in HCM605 Nozzles 3x20 / 1132" Drill Pipe Size 4.5 in Drill Pipe Size 4.5 in Drill Collar Size 6.61 in Sample From Flow Line Temp Depth/TVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/RI00 R6/R3 PV YP lOs/10m/30m Gel API Fluid Loss HTHP FL Temp Cake APIIHTHP Unc Ret Solids Correct Solids Oil Uncorr Water Oil/Water Ratio Alkal (Porn) CI Whole Mud Salt Lime E-Stability OF ft Ib/gal s/qt OF cP Ib/100ft2 Ib/lOOft2 cc130 min cc/30 min 1/32" %Vol %Vol %Vol %Vol mgll %Wt Iblbb1 CASING Surface 13.875in (tii3003ft (3001 TVD Intermediate in (tiift (TVD) Intermediate Production or Liner 4.8@!250°F :-/2 9 7.49 67 24 74/26 1.1 40000 20.69 1.43 872 Oil-BASED MUD REPORT No. 19 10/2/2004 Depth/TVD 5995 ft I 5992 ft 9/17/2004 Mud Type VersaDril Activity Drilling West Foreland Development West MacArthur River U 11857 Date Spud Date Water Depth Field/Area: Description : Location : M-I Well No. : MUD VOLUME (bbl) Hole 686.5 Active Pits 428.5 Total Circulating Vol 1115 In Storage 537 Out@!07:00 140 5995/5992 9.5@!140°F 86 150 79/55 46/31 18/16 24 31 17/20/23 5@!250°F --/2 7 5.43 70.5 22.5 76/24 0.9 41000 22.19 1.17 900 REMARKS AND TREATMENT Add Base Oil for rheology and OWR. Raise mud weight from 9.5 to 9.7 ppg. Reclaimed 5 bbls with Swaco Unit. Length 5236 ft Length 607 ft Length 93 ft MUD PROPERTIES Pit@!23:45 120 599515992 9.8@108°F 124 150 91/63 52/41 22/20 28 35 20/24/25 Daily Downhole Losses = 0 Curnmulative Downhole Losses = 177 TIME DISTR Rig Up/Service Drilling Tripping Non-Productive Tim Condition Mud Monitor Well Testing Cementing Wait on Cement Rig Repair Last 24 Hrs MUD VOL ACCTG Oil Added Water Added Mud Received Other Dumped Shakers Evaporation Centrifuge Fonnation 6 Left in Hole M-I ENGR I PHONE Warren Wilkes Lucian Angelescu 6 10 2 (bbl) o o o o o o o o o o RIG PHONE 907-776-7137 CIRCULATION DATA Pump Make lis Williams WHlOl TSM 1000 HP Pump Size 4.5 X lO.in 5.5 X 9.in Pump Cap 1.962 gal/stk 2.638 gal/stk Pump stklmin 120@95% 120@95% Flow Rate 552 gal/min Bottoms Up 46.1 min 1l07l stk Total Circ Time 84.8 min 20361 stk Circulating Pressure 3450 psi PRODUCTS USED LAST 24 HRS Products Size M-I BAR (4-PL Y LINED BAG) 50 LB BG PECAN NUT PLUG FINE 50 LB BG SAFE-CARB 250 50 LB BG ENGINEERING SERVICE I EA MIX II FINE 25 LB BG Amt 330 4 2 2 8 SOLIDS EQUIP Centrifuge Derrick Shaker Derrick Shaker Size Hr o 11 II 180/180/180 180/180/180 MUD PROPERTY SPECIFICATIONS Weight 9.7 Viscosity 70-90 Filtrate HTHP <8 REMARKS Drilling ahead. Picking up water in mud from flow during connections. Drill to 5995'. Increase mud weight to 9.7 ppg. Make short trip to the shoe. Rig repairs, working on top drive. Run in hole. Ream down last 5 stands. Resume drilling ahead, rotating and sliding. SOLIDS ANALYSIS Salt Wt% 20.69 Salt Conc,lblbbl 21.92 Adjusted Solid % 7.49 Oil/Water Ratio 74/26 Averge SG Solids 3.8 Low Gr % 1.9 Low Gr Wt, lblbbl 17.2 HighGr% 5.6 High Gr Wt lblbbl 82.25 WAREHOUSE PHONE 907-776-8680 MUD RHEOLOGY & HYDRAULICS np/na Values 0.531/0.205 kp/ka (lbos^n!IOOft2) 2.458/15.282 Bit Loss (psi / %) 32519.4 Bit HHP (hhp / HSI) 105 11.4 Bit Jet Vel (ft/s) 192 Ann. Vel DP (ft/min) 174.88 Ann. Vel DC (ft/min) 250.9 Crit Vel DP (ft/min) 477 Crit Vel DC (ft/min) 505 ECD (tii 5995 (lb/gal) 10.3 DAILY COST CUMULATIVE COST $ 4,577.90 $ 277,924,93 · · · · · · · · · · · · · · · · · · · It · · · · · · · · · · · · · · · · · · · · · · · · Mi SWAÇ~> Sample From Flow Line Temp Depth/TVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/R100 R6/R3 PV YP lOs/10m/30m Gel API Fluid Loss HTHP FL Temp Cake APIIHTHP Unc Ret Solids Correct Solids Oil Uncorr Water Oil/Water Ratio Alkal (Porn) Cl Whole Mud Salt Lime E-Stability OF ft lb/gal s/qt of cP lb/1 00ft2 lb/IOOft2 cc/30 min cc/30 min 1/32" %Vol %Vol %Vol %Vol mg/l %Wt lblbbl Production or Liner 6186/6177 9.7@114°F 96 150 65/44 36/27 14/13 21 23 14/16/17 4.8@250°F =-/2 9 7.57 68 23 75/25 1.8 38000 20.54 2.34 925 OIL-BASED MtIc REPORT No. 20 10/3/2004 Depth/TVD 6186 ft I 6177 ft 9/17/2004 Mud Type VersaDril Field/Area: We~~d Trip Out Description: DevelOIfn1ent Location: Wes!MacArthur Rìver U M-I Well No.: Ilg~7 Date Spud Date Water Depth MUD VOLUME (bbl) Hole 723.9(Tot)/419.4(Bit) Active Pits 340.1 Total Circulating Vol 759.5 In Storage 537 Out@6180 128 6186/ 9.7@120°F -87. 150 84/59 50/39 20/17 25 34 15/18/21 4.8@250°F =-/2 8.5 7.34 67 24.5 73/27 2 32000 16.97 2.6 825 CIRCULATION DATA Pump Make lis Williams WHIOI TSM 1000 lIP Pump Size 4.5 X lO.in 5.5 X 9.in Pump Cap gal/stk RaJ/Stk Pump stk/min Flow Rate Bottoms Up Total Circ Time Circulating Pressure PRODUCTS USED LAST 24 HRS Products Size ENOThŒE~OSER~CE I EA VERSACOAT HF 55 OA DM LIME 50 LB BO CALCIUM CHLORIDE PWD 80 LB BO gal/min Amt 2 2 40 8 éOLlDS EQUIP Centrifuge Derrick Shaker Derrick Shaker Size Hr o 20 20 Operator: FOREST OIL CORP. Report For: Mr. Fred Brent Well Name: West Foreland # 2 Contractor: Kuukpik Drilling Report For: Mr. F.Pluid I Mr.T.Knutson DRILLING ASSEMBLY CASING Bit Size 9.875 in HCM605 Surface Nozzles 3x20 I 1/32" l3.875in (áì3003ft (3001 TVD Drill Pipe Size Length Intermediate 4.5 in 2226 ft in (áìft (TVD) Drill Pipe Size Length Intermediate 4.5 in 607 ft Drill Collar Size Length 6.61 in 93 ft MUD PROPERTIES Pit@23:45 180/180/180 180/180/180 MUD PROPERTY SPECIFICATIONS Weight 9.7 Viscosity 70-90 Filtrate HTIIP <8 REMARKS AND TREATMENT Add Base Oil for rheology and OWR. Add Lime for alkalinity. Reclaimed xx bbls with Swaco Unit. Add Calcium Chloride for salinity. Reclaimed 15 bbls with Swaco Unit. REMARKS Drilling ahead, rotating and sliding. Drill to 6186'. Rig down for repairs to main engines. Pull out of hole. Daily Downhole Losses = 54 Cummulative Dòwnhole Losses = 231 Last 24 Hrs MUD VOL ACCTG Oil Added 6 Water Added 4.5 Mud Received 13.5 Other Dumped Shakers Evaporation Centrifuge Formation Lefi in Hole M-I ENGR I PHONE Warren Wilkes Lucian Angelescu TIME DISTR Rig UplService Drilling Tripping Non-Productive Tim Condition Mud Monitor Well Testing Cementing Wait on Cement Rig Repair (bbl) o o o 3 o o o o 54 o RIG PHONE SOLIDS ANALYSIS Salt Wt% 20.54 Salt Conc,lblbbl 20.82 Adjusted Solid % 7.57 OillWater Ratio 75/25 Averge SO Solids 3.7 Low Or % 2.6 Low Or Wt, Ib/bbL 23.42 High Or % 5, High Or Wt Iblbbl 73.35 MUD RHEOLOGY & HYDRAULICS nplna Values 0.563/0.208 kplka (lbos^n/I00ft2) 1.403/9.873 Bit Loss (psi I %) 11 Bit HHP (bhp I HSl) 11 Bit Jet Vel (fils) Ann. Vel DP (ftlmin) Ann, Vel DC (ftlmin) erit Vel DP (ftlmin) 364 Crit Vel DC (ftlmin) 377 ECD (áì 2985 (lb/J!,aI) 9.7 DAILY ÇOST CU¡.1\',lI.J,Jt:..::. ~:¡S, 907-776-7137 907-776-8680 WAREHE PHONE $ 3,694.96 $ 281;619.89 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Mi SWACg,. Sample From Flow Line Temp Depth/TVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/RI00 R6/R3 PV YP 1 Os/1 Om/30m Gel API Fluid Loss HTHP FL Temp Cake API/HTHP Unc Ret Solids Correct Solids Oil Uncorr Water OillWater Ratio Alkal (Porn) CI Whole Mud Salt Lime E-Stability OF ft lb/gal s/qt of cp Ib/ I 00ft2 Ib/lOOft2 cc130 min cc130 min 1/32" %Vol %Vol %Vol %Vol mg/I %Wt Iblbbl Production or Liner 4.8@250°F --/2 9 6.78 68 23 75/25 2.9 38000 20.54 3.77 963 REMARKS AND TREATMENT TIME DISTR Rig Up/Service Drilling Tripping Non-Productive Tim BOP Testing Monitor Well Testing Cementing Wait on Cement Rig Repair 7 7 10 Oil-BASED MUD REPORT No. 21 10/4/2004 Depth/TVD 6183 ft 16177 ft 9/17/2004 Mud Type VersaDril Activity Wait On Parts West Foreland Development West MacArthur Ríver U 11857 Date Spud Date Water Depth Field/Area : Description: Location : M-I Well No. : MUD VOLUME (bbl) Hole 723.4(Tot)/423(Bit) Active Pits 328.6 Total Circulating Vol 751.6 In Storage 537 Pit@9:00 N/A 6183/6177 9.7@140°F lO3 150 71/47 40/30 15/13 24 23 13/16/19 4.8@250°F --/2 8.5 7.08 69 22.5 75/25 3.3 37500 20.69 4.29 780 CIRCULATION DATA Pump Make lis Williams WHIOI TSM 1000 HP Pump Size 4.5 X lO.in 5.5 X 9.in Pump Cap gaVstk gaVstk Pump stk/min Flow Rate Bottoms Up Total Circ Time Circulating Pressure PRODUCTS USED LAST 24 HRS Products Size ENGINEERING SERVICE 1 EA MAPCO 200 1 GA TK gaVmin Amt 2 276 SOLIDS EQUIP Centrifuge Derrick Shaker Derrick Shaker Size Hr o 3 3 Operator: FOREST OIL CORP. Report For: Mr. Fred Brent Well Name: West Foreland # 2 Contractor: Kuukpik Drilling Report For: Mr. F.Pluid / Mr.T.Knutson DRILLING ASSEMBLY CASING Bit Size 9.875 in HCM605 Surface Nozzles 2x12/5x131 1/32" l3.875in @3003ft (3001TVD' Drill Pipe Size Length Intermediate 4.5 in 2256 ft in @ft (TVD) Drill Pipe Size Length Intermediate 4.5 in 607 ft Drill Collar Size Length 6.61 in 93 ft MUD PROPERTIES Pit@23:45 -92 6183/6177 9.8@88°F Ï41 150 66/44 36/27 14/12 22 22 14/16/17 180/180/180 180/180/180 MUD PROPERTY SPECIFICATIONS Weight 9.7 Viscosity 70-90 Filtrate HTHP <8 REMARKS Pull out of hole. Test BOP's. Run in to shoe. Circulate to condition mud. Waiting on parts for rig repair, (bbl) o o o o o o o o 12 o RIG PHONE SOLIDS ANALYSIS Salt Wt% 20.54 Salt Conc,lblbbl 20.82 Adjusted Solid % 7.57 OillWater Ratio 75/25 Averge SG Solids 3.8 Low Gr % 1.8 Low Gr Wt, lblbbl 16.59 HighGr% 5.7 High Gr Wt lblbbl 84.38 WAREHOUSE PHONE Last 24 Hra MUD VOL ACCTG Oil Added Water Added Mud Received Other Dumped Shakers Evaporation Centrifuge Formation Len in Hole M-I ENGR I PHONE Warren Wilkes Lucian Angelescu 907-776-7137 907-776-8680 MUD RHEOLOGY & HYDRAULICS np/na Values 0.585/0.231 kplka (lb-s^n!100ft2) 1.223/8.780 Bit Loss (psi / %) 11 Bit HHP (hhp / HSl) 11 Bit Jet Vel (ftls) Ann. Vel DP (ftlmin) Ann. Vel DC (ftlmin) Crit Vel DP (ftlmin) 358 Crit Vel DC (ftlmin) 373 ECD @3015 (lb/gal) 9.8 DAILY COST CUMULATIVE COST $ 2,006.88 $ 283,626,77 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Mi SWACQ-~ Sample From Flow Line Temp Depth/TVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/R100 R6/R3 PV YP lOs/10m/30m Gel API Fluid Loss HTHP FL Temp Cake APIIHTHP Unc Ret Solids Correct Solids Oil Uncorr Water Oil/Water Ratio Alkal (Porn) CI Whole Mud Salt Lime E-Stability OF ft Ib/gal s/qt of cP Ib/100ft2 Ib/100fF cc/30 min cc/30 min 1/32" %Vol %Vol %Vol %Vol mg/I %Wt Iblbbl Production or Liner 6183/6177 9.8(a)86°F 113 150 60/40 33/25 12/11 20 20 12/14/15 4.8(a)250°F --/2 9.0 7.67 69 22 76/24 1.7 41000 22.58 2.21 959 REMARKS AND TREATMENT Add base oil for Rheology control. Daily Downhole Losses = 6 Cummultive Downhole Losses = 249 TIME DISTR Rig UplService Drilling Tripping Non-Productive Tim Condition Mud Monitor Well Testing Cementing Wait on Cement Rig Repair 3 12 9 Oil-BASED MUD REPORT No. 22 10/5/2004 Depth/TVD 6183 ft I 6177 ft 9/17/2004 Mud Type VersaDril Activity Trip In West Foreland Development West MacArthur River U 11857 Date Spud Date Water Depth Field/Area : Description: Location: M-I Well No.: MUD VOLUME (bbl) Hole 71 0.5(Tot)/60 1.2(Bit) Active Pits 356.5 Total Circulating Vol 957.7 In Storage 537 Pit@lO:OO 6183/6177 9.7@87°F 105 150 62/41 34/25 12/10 21 20 12/14/18 5.0(a)250°F --/2 8 6.58 70 22 76/24 1.4 37500 21.06 1.82 840 CIRCULATION DATA Pump Make lis Williams WHIOI TSM 1000 HP Pump Size 4.5 X lO.in 5.5 X 9.in Pump Cap gal/stk gal/stk Pump stk/min Flow Rate Bottoms Up Total Circ Time Circulating Pressure PRODUCTS USED LAST 24 HRS Products Size ENGINEERING SERVICE I EA MAPCO 200 I GA TK gal/min Amt 2 882 SOLIDS EQUIP Centrifuge Derrick Shaker Derrick Shaker Size Hr o 10 10 Operator: FOREST OIL CORP. Report For: Mr. Fred Brent Well Name: West Foreland # 2 Contractor: Kuukpik Drilling Report For: Mr. F.Pluid I Mr.T.Knutson DRILLING ASSEMBLY CASING Bit Size 9.875 in HCM605 Surface Nozzles 2x12/5x131 1/32" 13.875in (aJ3003ft (3001TVD' Drill Pipe Size Length Intermediate 4.5 in 4271 ft in (aJft (TVD) Drill Pipe Size Length Intermediate 4.5 in 607 ft Drill Collar Size Length 6.61 in 93 ft MUD PROPERTIES Pit(a)23:45 180/180/180 180/180/180 MUD PROPERTY SPECIFICATIONS Weight 9.7 Viscosity 70-90 Filtrate HTHP <8 REMARKS Wait on parts for rig motors. Repair rig. Run in hole. Break circulation at 5000'. Cont in hole, (bbl) 21 o o o o o o o 6 o RIG PHONE SOLIDS ANALYSIS Salt Wt% 22.58 Salt Conc,lblbbl 22.47 Adjusted Solid % 7.42 OillWater Ratio 76/24 Averge SG Solids 3.8 Low Gr % 1.7 Low Or Wt, lblbbl 15.12 High Gr % 5.8 High Gr Wt lblbbl 84.62 WAREHOUSE PHONE Last 24 Hrs MUD VOL ACCTG Oil Added Water Added Mud Received Other Dumped Shakers Evaporation Centrifuge Formation Left in Hole M-I ENGR I PHONE Warren Wilkes Lucian Angelescu 907-776-7137 907-776-8680 MUD RHEOLOGY & HYDRAULICS nplna Values 0.58510.234 kplka (lb's^nlIOOft2) 1.lll/8.011 Bit Loss (psi I %) II Bit HHP (hhp I HSI) II Bit Jet Vel (ftls) Ann. Vel DP (ftlmin) Ann. Vel DC (ftlmin) Crit Vel DP (ftlmin) 360 Crit Vel DC (ftlmin) 385 ECD (aJ 5030 (lblgal) 9.8 CAlLY COST CUMULATIVE COST $ 3,449.16 $ 287,075.93 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · I e MiSW~ Sample From Flow Line Temp Depth/TVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R2001R100 R61R3 PV YP lOs/10m/30m Gel API Fluid Loss HTHP FL Temp Cake API/HTIIP Unc Ret Solids Correct Solids Oil Uncorr Water OilIWater Ratio Alkal (porn) Cl Whole Mud Salt Lime E-Stability OF ft lblgal s/qt of cP IbII 00ft2 IbII 00ft2 cc130 min cc130 min 1132" %Vol %Vol %Vol %Vo] mg/l %Wt lblbbl Production or Liner 4.8(aJ,250°F 12 9.0 9. 69 22 76/24 1.6 40500 22.37 2.08 910 REMARKS AND TREATMENT Daily Losses = Cummultive Downhole Losses = TIME DISTR Rig Up/Service Drilling Tripping Non-Productive Tim Condition Mud Rig Repair Testing Cementing Wait on Cement Rig Repair 24 OIL-BAlD MUD REPORT No. 23 10/6/2004 DepthlTVD 6183 ft 16177 ft 9/17/2004 Mud Type VersaDril Activity Wait on Parts West Foreland Development West MacArthur River U 11857 Date Spud Date Water Depth Field/Area: Description: Location: M-I Well No. : MUD VOLUME (bbl) Hole 723.6(Tot)/418.7(Bit) Active Pits 340.4 Total Circulating Vol 759.1 In Storage 537 Pit(a}9:oo N/A 6183/6177 9.7(a}88°F 145 150 66/45 37/28 14/12 21 24 12/14/16 4.8(a}250°F 12 10 8.66 68.5 21.5 76/24 1.4 38500 21.89 1.82 820 Wait on parts for rig motors. (bbl) o o o o o o o o 3 o RIG PHONE CIRCULATION DATA Pump Make lis Williams WHI01 TSM 1000 HP Pump Size 4.5 X lO.in 5.5 X 9.in Pump Cap gal/stk gal/stk Pump stklmin Flow Rate Bottoms Up Total Circ Time Circulating Pressure PRODUCTS USED LAST 24 HRS Products Size ENGINEERING SERVICE 1 EA gal/min Amt 2 SOLIDS EQUIP Centrifuge Derrick Shaker Derrick Shaker Size Hr o o o Operator: FOREST OIL CORP. Report For: Mr. Fred Brent / Joe Harris Well Name: West Foreland # 2 Contractor: Kuukpik Drilling Report For: Mr. F.Pluid I Mr.T.Knutson DRILLING ASSEMBLY CASING Bit Size 9.88 in HCM605 Surface Nozzles 2x12/5x13I 1/32" 13.875in (áj3003ft (3001TVD· Drill Pipe Size Length Intermediate 4.5 in 2221 ft in (ájft (TVD) Drill Pipe Size Length Intermediate 4.5 in 607 ft Drill Collar Size Length 6.61 in 93 ft MUD PROPERTIES Pit(aJ,23 :00 Ñ/A 6183/6177 9.7(a}85°F 147 150 60/40 33/25 12/11 20 20 13114/16 Last 24 Hrs MUD VOL ACCTG Oil Added Water Added Mud Received Other Dumped Shakers Evaporation Centrifuge Formation Left in Hole M-I ENGR I PHONE Keith Green Lucian Angelescu 180/180/180 180/180/180 MUD PROPERTY SPECIFICATIONS Weight 9.7 Viscosity 70-90 Filtrate HTHP <8 REMARKS SOUDS ANALYSIS Salt Wt% 22.37 Salt ConcJb/bbl 22.19 Adjusted .solid % 7.44 OillWater Ratio 76/24 Averge SO Solids 3.7 Low Or % 2.4 Low Or Wt, Iblbbl 22.04 HighOr% 5. High Or Wt Ib/bbl 73.78 MUD RHEOLOGY & HYDRAULICS np/na Values 0.585/0.234 kp/ka (tb"s^nlIOOíP) LIl1/8.011 Bit Loss (psi I %) 11 Bit HHP (hhp I HSI) 11 Bit Jet Vel (ftls) Ann. Vel DP (ftlmin) Ann. Vel DC (ftlmin) Crit Vel DP (ftlmin) 344 Crit Vel DC (ftlmin) 359 ECD (ii) 2980 (tb/gal) 9.7 DAILY COST CUMULATIVE COST 907-776-7137 907-776-8680 WAREHOUSE PHONE $ 288,425.93 $ 1,350.00 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · e Mi SWAC~ «-:--.-,<~-~ -."...--- Sample From J:low Line Temp Depth/TVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/R I 00 R6/R3 PV YP IOs/lOm/30m Gel API Fluid Loss HTHP FL Temp Cake APIIHTHP Dnc Ret Solids Correct Solids Oil Uncorr Water Oil/Water Ratio Alkal (Porn) _CI Whole Mud Salt _Lime _E-Stability OF ft Ib/gal s/qt of cP Ib/IOOft2 I b/l 00ft2 cc/30 min cc130 min 1/32" %VoJ %Vol %VoJ %Vol mg/I %Wt lblbbl Production or Liner 4.8(a),,250°F /2 9.0 9. 69 22 76/24 1.4 40000 22.15 1.82 820 REMARKS AND TREATMENT Daily Losses = 3 Curnmultive Downhole Losses = 249 TIME DISTR Rig Up/Service Drilling Tripping Non-Productive Tim . Condition Mud Rig Repair Testing Cementing Wait on Cement Rig Repair 24 M-I ENGR I PHONE Keith Green Lucian Angelescu Date Spud Date Water Depth PlT(a)9:00 N/A 6183/6177 9.7(a)85°F 146 150 62/42 35/26 13111 20 22 12/15/18 5@,,250°F /2 8.5 6.99 69 22.5 76/24 1.3 39500 21.55 1.69 890 (bbl) o o o o o o o o o o RIG PHONE 907-776-7137 OIl=~BAtD MUD REPORT No. 24 10/7/2004 DepthlTVD 6183 ft 16177 ft 9/17/2004 Mud Type VersaDril Activity Rig Repair West Foreland Development West MacArthur River U 11857 Field/Area: Description: Location: M-I Well No. : MUD VOLUME (bbl) Hole 723.6(Tot)!418.7(Bit) Active Pits 340.4 Total Circulating Vol 759.1 In Storage 537 Rig making repairs to motors. SOLIDS ANALYSIS Salt Wt% 22.15 Salt Conc,lblbbl 21.92 A(Uusted Solid % 7.47 Oil/Water Ratio 76/24 Averge SG Solids 3.7 Low Gr % 2.4 Low Gr Wt, Iblbbl 22.13 HighGr% 5. High Gr Wtlblbbl 73.96 WAREHOUSE PHONE 907-776-8680 CIRCULATION DATA Pump Make lis Williams WHI01 TSM 1000 HP Pump Size 4.5 X 10.in 5.5 X 9.in Pump Cap gallstk gallstk Pump stklmin Flow Rate Bottoms Up Total Circ Time Circulating Pressure PRODUCTS USED LAST 24 HRS _Products Size _ENGINEERING SERVICE 1 EA gallmin Amt 2 SOLIDS EQUIP Centrifuge Derrick Shaker Derrick Shaker Size Hr o o o Operator: FOREST OIL CORP. Report For: Joe Harris Well Name: West Foreland # 2 Contractor: Kuukpik Drilling ~ort For: Mr. F.Pluid I Mr.T.Knutson DRILLING ASSEMBLY CASING Bit Size 9.88 in HCM605 Surface Nozzles 2x12/5x131 1/32" 13.875in @J3003ft (3001 TVD: Drill Pipe Size Length Intermediate 4.5 in 2221 ft in @Jft (TVD) Drill Pipe Size Length Intermediate 4.5 in 607 ft Drill Collar Size Length 6.61 in 93 ft MUD PROPERTIES Pit@,,23:00 Ñ/A 6183/6177 9.7(a)85°F 145 150 66/45 37/28 14/12 21 24 12/14/16 Last 24 HIS MUD VOL ACCTG Oil Added Water Added Mud Received Left in Hole Other Dumped Shakers Evaporation Centrifuge Formation 180/180/180 180/180/180 MUD PROPERTY SPECIFICATIONS Weight 9.7 Viscosity 70-90 Filtrate HTHP <8 REMARKS MUD RHEOLOGY & HYDRAULICS np/na Values 0.553/0.242 kp/ka (Ib"s^n!100ft2) 1.531/8.633 Bit Loss (psi I %) 11 Bit HHP (hhp I HSI) 11 Bit Jet Vel (ftls) Ann. Vel DP (ftlmin) Ann. Vel DC (ftlmin) Crit Vel DP (ftlmin) 366 Crit Vel DC (ftlmin) 382 ECD @, 2980 (Ib/gal) 9.7 DAILY COST CUMULATIVE COST $ 1,350.00 $ 289,775.93 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · e Mí SW~C?~ _..,'~..... Sample From Flow Line Temp DepthlTVD Mud Weight Funnel Viscosity Rheology Temp R6001R300 R200/RI00 R6/R3 PV YP IOs/1 Om/30m Gel API Fluid Loss HTHP FL Temp Cake APIIHTHP Unc Ret Solids Correct Solids .oil Uncorr Water Oil/Water Ratio Alkal (Porn) CI Whole Mud Salt Lime E-Stability °F ft Ib/gal s/qt of cP ] b/lOOft2 I b/l 00ft2 cc130 min cc/30 min 1/32" %Vol %Vol %Vol %Vol mg/I %Wt Ib/bbl Production or Liner 4.8(â1,250°F 12 9.0 9. 69 22 76/24 1.4 39000 21.72 1.82 910 REMARKS AND TREATMENT Pump nut plug sweep on bottom and circ out. Daily Losses = 6 Cummultive Downhole Losses = 255 TIME DISTR Rig Up/Service Drilling -1!iPping Non-Productive Tim Condition Mud Rig Repair Testing Cementing Wait on Cement Rig Repair 6 18 M-I ENGR I PHONE Keith Green Lucian Angelescu OIL-BAlD MUD REPORT No. 25 10/8/2004 DepthlTVD 6183 ft 16177 ft 9/17/2004 Mud Type VersaDril Activity Pooh to Shoe West Foreland Development West MacArthur River U 11857 Date Spud Date Water Depth FieldlArea : Description: Location: M-I Well No. : MUD VOLUME (bbl) Hole 720.5(Tot)/462.9(Bit) Active Pits 321.5 Total Circulating Vol 784.5 In Storage 537 Out(a)15:00 99 6183/6177 9.8(a)96°F 96 150 67/45 37/28 13/11 22 23 12/14/17 5(â1,250°F 12 8.5 7.26 69.5 22 76/24 1.7 38500 21.5 2.21 925 CIRCULATION DATA Pump Make lis Williams WHlOI TSM 1000 HP Pump Size 4.5 X lO.in 5.5 X 9.in Pump Cap gal/stk gal/stk Pump stk/min Flow Rate Bottoms Up Total Circ Time Circulating Pressure PRODUCTS USED LAST 24 HRS Products Size PECAN NUT PLUG FINE 50 LB BG ENGINEERING SERVICE I EA VERSACOAT HF 55 GA DM gal/min Amt 8 2 I SOLIDS EQUIP Centrifuge Derrick Shaker Derrick Shaker Size Hr o 18 18 Operator: FOREST OIL CORP. Report For: Joe Harris Well Name: West Foreland # 2 Contractor: Kuukpik Drilling Report For: Mr. 1. Otto I Mr.T.Knutson DRILLING ASSEMBLY CASING Bit Size 9.88 in HCM605 Surface Nozzles 2x12/5x131 1/32" L3.875in @,3003ft (300ITVD: Drill Pipe Size Length Intennediate 4.5 in 2708 ft in @ft (TVD) Drill Pipe Size Length 1ntennediate 4.5 in 607 ft Drill Collar Size Length 6.61 in 93 ft MUD PROPERTIES Pit(â1,22:oo 90 6183/6177 9.8(a)90°F 104 150 66/45 37/26 14/12 21 24 13/14/16 1801180/180 180/180/180 MUD PROPERTY SPECIFICATIONS Weight 9.7 Viscosity 70-90 Filtrate HTHP <8 I REMARKS I Pumped nutplug sweep at shoe, Trip to bottom pumped 20 bbls nut plug sweep, Rig I went down. Pool to shoe for repairs. (bbl) o o o o 16 o o o o 6 RIG PHONE SOLIDS ANALYSIS Salt Wt% 21.72 Salt Conc,lblbbl 21.37 Adjusted Solid % 7.51 OillWater Ratio 76124 Averge SO Solids 3.8 Low Or % 1.7 Low Or Wt, Iblbbl 15.49 High Or % 5.8 High Or Wt lblbbl 85.36 MUD RHEOLOGY & HYDRAULICS nplna Values 0.553/0.220 kplka (lb-s^nlIOOft2) 1.531/8.936 Bit Loss (psi I %) II Bit HHP (hhp I HSl) II Bit Jet Vel (ftls) Ann. Vel DP (ftlmin) Ann. Vel DC (ftlmin) Crit Vel DP (ftlmin) 352 Crit Vel DC (ftlmin) 393 ECD (ãJ 3467 (lb/gal) 9.8 DAILY COST CUMULATIVE COST WAREHOUSE PHONE 907-776-7137 907-776-8680 Last 24 Hrs MUD VOL ACCTG Oil Added Water Added Mud Received Left in Hole Other Dumped Shakers Evaporation Centrifuge Fôrmation $ 2,163.80 $ 291,939.73 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · I __ ¡ I Mi SWACj;b .......~...-~ Sample From Flow Line Temp Depth/TVD Mud Weight Funnel Viscosity ~Rheology Temp R600/R300 R2001R100 R6/R3 PV YP lOs/10m/30m Gel API Fluid Loss HTHP FL Temp Cake API/HTHP Unc Ret Solids Correct Solids Oil Uncorr Water 'Oil/Water Ratio Alkal (Porn) CI Whole Mud Salt Lime E-Stability cP Ib/100fF Ib/100ft2 cc/30 min cc/30 min 1/32" %Vol %Vol %Vol %Vol mg/I %Wt Ib/bbl Daily Losses = 0 Cummultive Downhole Losses = 255 TIME DISTR -Rig Up/Service -Drilling J1:œping Non-Productive Tim -Condition Mud -Rig Repair Testing Cementing Wait on Cement -Rig Repair 4 5 IS M-I ENGR I PHONE Keith Green ...Lucian Angelescu Production or Liner 4.8@,250°F 12 10 10. 68 22 76/24 1.1 41000 22.58 1.43 905 OIL-BAlD MUD REPORT No. 26 Date Spud Date Water Depth 10/9/2004 9/17/2004 Operator: FOREST OIL CORP. Report For: Mr. Joe Harris Well Name: West Foreland # 2 Contractor: Kuukpik Drilling Report For: Mr. 1. Otto I Mr.T.Knutson DRILLING ASSEMBLY CASING Bit Size 9.88 in HCM60S- Surface Nozzles 2x12/5x13I 1/32" 13.875in (Ó)3003ft (3001TVD' Drill Pipe Size Length Intennediate 4.5 in 5424 ft in (Ó)ft (TVD) Drill Pipe Size Length Intennediate 4.5 in 607 ft Drill Collar Size Length ~61 in 93 ft MUD PROPERTIES I FL@,21:30 OF - ft 6183/6177 Ib/gal 9.7cm95°F s/qt f 11 OF 150 63/43 35126 13/11 20 23 13/15/19 FieldlArea : Description: Location: M-I Well No. : MUD VOLUME (bbl) Hole 703.2 Active Pits 386.8 Total Circulating Vol 1090 In Storage 537 Pitcml4~ NIA 618316177 9.8@85°F 122 150 70/46 36/27 14/12 24 22 13115118 5cm250°F /2 8.5 7.01 69.5 22 76/24 1.6 39000 . 21.72 2.08 935 DepthlTVD 6183 ft 16177 ft Mud Type VersaDril Activity Drilling West Foreland Development West MacArthur River U 11857 CIRCULATION DATA Pump Make lis Williams WHIOI TSM 1000 HP Pump Size 4.5 X 1O.in 5.5 X 9.in Pump Cap 1.962 gal/stk 2.638 gal/stk Pump stk/min 112cm95% 120cm95% Flow Rate 536 gal/min ~ttoms Up 48.6 min 11275 stk Total Circ Time 85.4 min 19815 stk Circulating Pressure 3679 psi PRODUCTS USED LAST 24 HRS Products Size ENGlNEERING SERVICE I EA MAPCO 200 I GA TK VERSACOAT HF 55 GA DM LIME 50 LB BG Amt 2 1935 4 ~ Size SOLIDS EQUIP Centrifuge Derrick Shalçer Derrick Shaker Hr o 6 6 I I REMARKS AND TREATMENT Added Mapco 200 Base for rheology control and volume, Added Lime for alkalinity. 180/180/180 180/180/180 MUD PROPERTY SPECIFICATIONS Weight 9.7 -Yiscosity 70-90 Filtrate H1HP <8 REMARKS Trip in hole, 30' of fill getting bottom, circ bottoms up and drilling ahead. (bbl) o o 48 o o o o o o o RIG PHONE SOLIDS ANALYSIS Salt Wt% 22.58 Salt ConcJb/bbl 22.47 Adjusted Solid % 8.42 Oil/Water Ratio 76/24 Averge SG Solids 3.3 Low Gr % 4.5 Low Gr Wt. Iblbbl 40.82 High Gr % 3.9 . Higl1 Gr Wt Iblbbl 57.8 WAREHOUSE PHONE 907-776-7137 907-776-8680 Last 24 Hrs MUD VOL ACCTG Oil Added Water Added Mud Received Left in Hole Other Dumped Shakers Evaporation Centrifuge Formation MUD RHEOLOGY & HYDRAULICS np/na Values 0.551/0.245 kplka (lb's^n!IOOft2) 1.47717.866 Bit Loss (psi I %) 340/9.2 Bit HHP (hhp I HSI) 10611.4 Bit Jet Vel (ftls) 198 Ann. Vel DP (ftlmin) 169.81 Ann. Vel DC (ftlmin) 243,63 Crit Vel DP (ftlmin) 369 Crit Vel DC (ftlmin) 396 ECD (tV, 6183 (lb/gal) 10.01 DAILY COST CUMULATIVE COST $ 8,616.78 $ 300,556.51 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Mi sw~g~ Sample From Flow Line Temp Depth/TVD Mud Weight _ Funnel Viscosity Rheology Temp R600/R300 R200/R100 R6/R3 PV YP 1 Os/l Om/30m Gel API Fluid Loss HTHP FL Temp Cake API/HTHP Unc Ret Solids Correct Solids Oil Uncorr Water Oil/Water Ratio Alkal (Porn) CI Whole Mud Salt Lime E-Stability OF ft Ib/gal s/qt of cP I b/l 00ft2 I b/l 00ft2 cc/30 min cc/30 min 1/32" %Vol %Vol %Vol %Vol mg/I %Wt Ib/bbl Production or Liner 4.8@.250°F 12 10 10. 69 21 77/23 1.5 40300 23.1 1.95 960 Oil-BASED MUD REPORT No. 27 10/10/2004 DepthlTVD 6696 ft I 6666 ft 9/17/2004 Mud Type VersaDril Activity Drilling West Foreland Development West MacArthur River U 11857 Date Spud Date Water Depth Field/Area : Description : Location : M-I Well No. : MUD VOLUME (bbl) Hole 748.5 Active Pits 376.5 Total Circulating Vol 1125 In Storage 502 Out(a}8:30 120 64201 9. 7(a} 11 6°F 71 150 57/37 30121 1018 20 17 10/13/15 5(a}250°F 12 8 6.49 70 22 76/24 1.6 39500 21.93 2.08 900 CIRCULATION DATA Pump Make lis Williams WH101 TSM 1000 HP Pump Size 4.5 X 1O.in 5.5 X 9.in Pump Cap 1.962 gal/stk 2.638 gal/stk Pump stklmin 126(a}95% 124(a}95% Flow Rate 574 gal/min Bottoms Up 48.2 min 12042 stk Total Circ Time 82.3 min 20579 stk Circulating Pressure 3679 psi PRODUCTS USED LAST 24 HRS Products Size ENGINEERING SERVICE 1 EA MAPCO 200 I GA TK LIME 50 LB BG CALCIUM CHLORIDE PWD 80 LB BG Amt 2 25 10 40 SOLIDS EQUIP Centrifuge Derrick Shaker Derrick Shaker Size Hr o 24 24 Operator: FOREST OIL CORP. Report For: Mr. Joe Harris Well Name: West Foreland # 2 Contractor: Kuukpik Drilling Report For: Mr. 1. Otto I Mr.T.Knutson DRILLING ASSEMBLY CASING Bit Size 9.88 in HCM605 Surface Nozzles 2x12/5x131 l/~2" 13.875in @)OO3ft (300lTVD" Drill Pipe Size Length Intermediate 4.5 in 5937 ft in (aJft (TVD) Drill Pipe Size Length Intermediate 4.5 in 607 ft Drill Collar Size Length 6.61 in 93 ft MUD PROPERTIES Pit@,20:30 122 6696/6666 9.7(a} 120°F -68 150 58/39 31/22 11/9 19 20 10/13/25 1801180/180 180/180/180 MUD PROPERTY SPECIFICATIONS Weight 9.7 Viscosity 70-90 Filtrate HTHP <8 REMARKS AND TREATMENT REMARKS Added Calcium Chloride for Salinity and Lime alkainity. Reclaimed 25 bbls Drilling ahead 6696', Circ bottoms up and short trip every 1000' or 24hrs, trip back with Swaco unit. Added 25 bbls of Mapco 200 base in hole and cont drilling, Last 24 Hrs MUD VOL ACCTG Oil Added Water Added Mud Received Other Dumped Shakers Evaporation Centrifuge Formation Left in Hole M-l ENGR I PHONE Keith Green Lucian Angelescu Daily losses = 48 bbls new volume Cummultive downhole losses = 303 bbls TIME DISTR Rig Up/Service Drilling Tripping Non-Productive Tim Condition Mud Rig Repair Testing Cementing Wait on Cement Rig Repair 24 (bbl) o o o o o o o o o o RIG PHONE SOLIDS ANALYSIS Salt Wt% 23.1 Salt Conc.lb/bbl 22.08 Adjusted Solid % 8.44 OillWater Ratio 77/23 Averge SG Solids 3.4 Low Gr % 4.4 Low Gr Wt. Iblbbl 39.97 High Gr % 4. High Gr Wt Iblbbl 59.46 WAREHOUSE PHONE 907-776-7137 907-776-8680 MUD RHEOLOGY & HYDRAULICS nplna Values 0.573/0.255 kplka (lb-s^n!IOOft2) 1.171/6.336 Bit Loss (psi I %) 390/10.6 Bit HHP (hhp IHS1) 131/1.7 Bit Jet Vel (Ns) 212 Ann. Vel DP (ftlmin) 181.85 Ann. Vel DC (ftImin) 260.9 Crit Vel DP (ftImin) 335 Crit Vel DC (ftImin) 360 ECD @ 6696 (lb/gal) 9.97 DAILY COST CUMULATIVE COST $ 3,404.10 $ 303,960.61 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · e--~-- MiSW~ç~ Sample From Flow Line Temp Depth/TVD Mud Weight Funnel Viscosity Rheology Temp R6001R300 R2001R 100 R61R3 PV YP lOs/10m/30m Gel API Fluid Loss HTHP FL Temp Cake APIIHTHP Unc Ret Solids Correct Solids Oil Uncorr Water Oil/Water Ratio Alkal (Porn) Cl Whole Mud Salt Lime E-Stabilitv OF ft Ib/gal s/qt of cP Ib/lOOft2 Ib/1 00ft2 ccl3 0 min cc130 min 1/32" %Vol %Vol %Vol %Vol mg/I %Wt lblbbl Production or Liner 5.0(ci}250°F 12 10 8.35 68 22 76/24 1.7 50100 26.27 2.21 928 REMARKS AND TREATMENT Added CaCI2 and Lime, added 30 bbls of brine for OIW ratio, Adding Versacoat and Versawet. Daily losses = 10 Curnmultive Downhole losses = 313 Lossing 4 +1- bblslhr above new hole volume made, TIME DISTR Rig Up/Service Drilling Tripping Non-Productive Tim Condition Mud Rig Repair Testing Cementing Wait on Cement Rig Repair 24 (bbl) o o 30 o o 10 o o o 76 RIG PHONE 907-776-7137 OIL-BA.D MUD REPORT No. 28 10/11/2004 DepthlTVD 7066 ft I 7015 ft 9/17/2004 Mud Type VersaDril Activity Drilling West Foreland Development West MacArthur River U 11857 Date Spud Date Water Depth Field/Area : Description: Location: M-I Well No. : MUD VOLUME (bbl) Hole 781.3 Active Pits 389.7 Total Circulating Vol 1171 In Storage 407 Out(ci}15:00 120 69451 9.7(ci}118°F -70 150 65/43 34/25 13111 22 21 12/15/17 4.8(a>,250°F 12 8.5 6.92 69.5 22 76/24 1.6 41000 22.58 2.08 930 CIRCULATION DATA Pump Make lis Williams WHIOI TSM 1000 HP Pump Size 4.5 X 10.in 5.5 X 9.in Pump Cap 1.962 gal/stk 2.638 gal/stk Pump stk/min 108(ci}95% 110(ci}95% Flow Rate 502 gal/iñin Bottoms Up 57.4 min 12508 stk Total Circ Time 98 min 21358 stk Circulating Pressure 3679 psi PRODUCTS USED LAST 24 HRS Products Size M-l BAR (4-PL Y LINED BAG) 50 LB BG PECAN NUT PLUG FINE 50 LB BG G-SEAL 50 LB BG SAFE-CARB 250 50 LB BG ENGINEERING SERVICE 1 EA VERSACOATHF 55GADM VERSAMOD 55 GA DM VERSA WET 55 GA DM CALCIUM CHLORIDE PWD 80 LB BG Amt 20 12 1 6 2 1 I 1 12 SOLIDS EQUIP Centrifuge Derrick Shaker Derrick Shaker Size Hr 3 24 24 Operator: FOREST OIL CORP. Report For: Mr. Joe Harris Well Name: West Foreland # 2 Contractor: Kuukpik Drilling Report For: Mr. J. Otto I Mr.T.Knutson DRILLING ASSEMBLY CASING Bit Size 9,88 in HCM605 Surface Nozzles 2x12/5x131 1/32" 13.875in @,3003ft (3001TVD' Drill Pipe Size Length Intermediate 4.5 in 6307 ft in (oJft (TVD) Drill Pipe Size Length Intermediate 4.5 in 607 ft Drill Collar Size Length 6.61 in 93 ft MUD PROPERTIES Pit@,21 :00 118 7014/6964 9. 7(ci} 120°F 77 150 65144 35126 11110 21 23 12/14/16 180£180/180 180/180/180 MUD PROPERTY SPECIFICATIONS Weight 9.7 Viscosity 70-90 Filtrate HTHP <8 REMARKS Drilling ahead no problems, pumping 20lblbbls LCM sweeps twice per tour and High Vis sweeps once per tour and before short trips. SOLIDS ANALYSIS Salt Wt% 26.27 Salt ConcJblbbl 27.45 Adjusted Solid % 8. Oil/Water Ratio 76/24 Averge SG Solids 3.3 Low Gr % 4.3 Low Gr Wt, Ib/bbl 38.88 High Gr % 3.7 High Gr Wt Iblbbl 54.77 MUD RHEOLOGY & HYDRAULICS nplna Values 0.563/0.272 kplka (lb-s^n/100ft2) 1.403/6.841 Bit Loss (psi! %) 29818.1 Bit HHP (hhp I HSI) 87/1.1 Bit Jet Vel (ftls) 185 Ann. Vel DP (ftlmin) 159.04 Ann. Vel DC (ftlmin) 228.18 Crit Vel DP (ftlmin) 367 Crit Vel DC (ftlmin) 397 ECD (oJ 7066 (lb/gal) 10.01 DAILY COST CUMULATIVE COST WAREHOUSE PHONE 907-776-8680 $ 4,311.06 $ 308,271.67 Last 24 Hrs MUD VOL ACCTG Oil Added Water Added Mud Received Other Dumped Shakers Evaporation Centrifuge Fonnation Left in Hole M-I ENGR I PHONE Keith Green Lucian Angelescu · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Mi SW~9~ Operator: FOREST OIL CORP. Report For: Mr. Joe Harris Well Name: West Foreland # 2 Contractor: Kuukpik Drilling Report For: Mr. 1. Otto I Mr.T.Knutson DRILLING ASSEMBLY Bit Size 9.88 in HCM605 Nozzles 2x12/5x13 I 1/32" Drill Pipe Size Length 4.5 in 6567 ft Drill Pipe Size Length 4.5 in 607 ft Drill Collar Size Length 6.61 in 93 ft Sample From Flow Line Temp Depth/TVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/RI00 R6/R3 PV yp lOs/10m/30m Gel API Fluid Loss HTHP FL Temp Cake API/HTHP Unc Ret Solids Correct Solids Oil Uncorr Water Oil/Water Ratio Alkal (Porn) CI Whole Mud Salt Lime E-Stability cP I bll OOft2 I b/ 1 OOft2 cc/30 min cc/30 min 1/32" %Vol %Vol %Vol %Vol mg/l %Wt lblbbl Oil-BASED. MUD REPORT No. 29 Date 10/12/2004 DepthlTVD 7326 ft I 7266 ft Spud Date 9/17/2004 Mud Type VersaDril Water Depth Activity Drilling Field/Area: West Foreland Description: Development Location: West MacArthur River U Well No.: 11857 CASING Surface 13.875in (å!3003ft (3001TVD) Intermediate in (å!ft (fVD) Intermediate Production or Liner MUD PROPERTIES OF ft lb/gal s/qt of Pit(â}20:00 127 7234/7264 9.7(â}122°F -78 150 66/45 36/27 13/12 21 24 13/16/19 Out(â}15:00 122 7180/7120 9.7(â}120°F 78 150 72/49 40/29 15/13 23 26 14/26/30 5@-250°F 12 10 8.02 67 23 74/26 1.8 50000 25.38 2.34 925 REMARKS AND TREATMENT Added Pre mixed brine and Mapco 200 to active system for volume and treated also with CaCl2 for salinity. Added lime alkainity. Daily Losses = 78 Cummultive Downhole Losses 391 6@-250°F 12 9 9. 69 22 76/24 .8 50100 26.27 1.04 1067 TIME DISTR Last 24 Hrs MUD VOL ACCTG Rig Up/Service Oil Added Drilling 24 Water Added Tripping Mud Received Non-Productive Tim Other Condition Mud Dumped Rig Repair Shakers Testing Evaporation Cementing Centrifuge Wait on Cement Formation Rig Repair Left in Hole M~ENGR/PHONE I Keith Green Lucian Angelescu (bbl) o o 22 o o 10 o 8 60 o RIG PHONE 907-776-7137 MUD VOLUME (bbl) Hole 804.3 Active Pits 385.7 Total Circulating Vol 1190 In Storage 332 Pit@04:00 CIRCULATION DATA Pump Make Ilis Williams WHlo( TSM 1000 HP Pump Size 4.5 X 1O.in 5.5 X 9.in Pump Cap 1.962 gallstk 2.638 gallstk Pump stklmin 110@95% III (â}95% Flow Rate 509 gaUmin Bottoms Up 58.2 min 12858 stk Total Circ Time 98.2 min 21701 stk Circulating Pressure 3230 psi PRODUCTS USED LAST 24 HRS Products Size Amt PECAN NUT PLUG FIN 50 LB BG 72 G-SEAL 50 LB BG 12 SAFE-CARB 250 50 LB BG 36 ENGINEERING SERVIC 1 EA 2 MAPCO 200 1 GA TK 946 VERSACOATHF 55 GADM 1 LIME 50 LB BG 15 CALCIUM CHLORIDE 80 LB BG 15 HRP 55 GADM 1 SOLIDS EQUIP Centrifuge Derrick Shaker Derrick Shaker Size Hr 6 24 24 180/180/180 180/180/180 MUD PROPERTY SPECS Weight 9.7 Viscosity 70-90 Filtrate HTHP <8 REMARKS Drilling ahead @ 7295' with no problems. Short trips made with little drag recorded. Mixing and pumping every stand down High Vis I LCM sweeps for good hole cleaning. SOLIDS ANALYSIS Salt Wt% 26.27 Salt Conc,lb/bbl 27.45 Adjusted Solid % 7. OillWater Ratio 76/24 Averge SG Solids 3.7 Low Gr % 2.2 Low Or Wt, lblbbl 20. High Gr % 4.8 High Or Wt lblbbl 70.56 WAREHOUSE PHONE 907-776-8680 MUD RHEOLOGY & HYDRAULICS nplna Values 0,553/0.231 kplka (lb's^n!100ft2) 1.531/8.780 Bit Loss (psi I %) 306/9.5 Bit HHP (hhp I HSl) 91/ 1.2 Bit Jet Vel (ftIs) 188 Ann. Vel DP (ftImin) 161.25 Ann. Vel DC (ftImin) 231.36 Crit Vel DP (ftImin) 379 Crit Vel DC (ftImin) 404 ECD (å! 7326 (lb/galj 10.04 DAILY COST CUMULATIVE COST $ 9,274.67 $ 317,546.34 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · e Mi SWACc:t-- -- _.,_.,._~- -, OIi.-BASi-A,UD REPORT No. 30 Date 10/13/2004 DepthlTVD 7642 ft I 7404 ft Spud Date 9/17/2004 Mud Type VersaDril Water Depth Activity Tripping Field/Area: West Foreland Description: Development Location: West MacArthur River U Well No.: 11857 Operator: FOREST OIL CORP. Report For: Mr. Joe Harris Well Name: West Foreland # 2 Contractor: Kuukpik Drilling Report For: Mr. J. Otto / Mr.T.Knutson DRILLING ASSEMBLY CASING Bit Size 9.88 in HCM605 Surface Nozzles 2x12/5x131 l/32" 13.875in (á}3003ft (3001TVD) Drill Pipe Size Length Intermediate 4.5 in 6883 ft in (á}ft (TVD) Drill Pipe Size Length Intermediate 4.5 in 607 ft Drill Collar Size Length 6.61 in 93 ft Sample From Flow Line Temp Depth/TVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/R100 R6/R3 PV YP IOs/lOm/30m Gel API Fluid Loss HTHP FL Temp Cake APIIHTHP Unc Ret Solids Correct Solids Oil Uncorr Water Oil/Water Ratio Alkal (Porn) Cl Whole Mud Salt Lime E-Stability OF ft Ib/gal s/qt of cP 1 b/ 100ft2 Ib/1 OOfP cc/30 min cc/30 min 1/32" %Vol %Vol %Vol %Vol mg/l %Wt Iblbbl Production or Liner MUD PROPERTIES FL@23:00 122 7642/7404 9.7(íl}120°F -74 150 67/46 36/27 14/12 21 25 15/19/21 5.5@,250°F 12 10 10. 68 22 76/24 1.7 57000 28.85 2.21 1042 Pit(íl}19:00 122 7577/7376 9.7(íl}120oP -75 150 85156 45/33 16/15 29 27 17/22/25 5@,2500P /2 10 8.01 68 22 76/24 1.9 60000 29.91 2.47 1067 REMARKS AND TREATMENT Built 70 bbls fresh Versadrill on location for dilution and volume. Treated active system with pre-mix brine and lime. Daily Losses = Cummultive Downhole Losses = New Hole Vol 24 hrs = 36 bbls MUD VOLUME (bbl) Hole 832.2 Active Pits 351.8 Total Circulating Vol 1184 In Storage 332 PL(íl}IO:00 122 74521 9.7(íl}120oP 76 150 75/49 40/29 14/13 26 23 15/21/24 5@,2500P 12 10 8.01 66.5 23.5 74/26 2.1 50500 25.17 2.73 1020 CIRCULATION DATA Pump Make tlis Williams WHlo( TSM 1000 HP Pump Size 4.5 X lO.in 5.5 X 9.in Pump Cap gal/stk gallstk Pump stk/min Flow Rate Bottoms Up Total Circ Time Circulating Pressure P~ODUCTS USED LAST 24 HRS Products Size Amt M-l BAR (4-PL Y LINEr 50 LB BG 122 PECAN NUT PLUG FIN 50 LB BG 36 G-SEAL 50 LB BG 9 SAFE-CARB 250 50 LB BG 18 ENGINEERING SERVI( I EA 2 MAPCO 200 I GA TK 93 VERSACOAT HF 55 GA DM 2 VERSA WET 55 GADM 2 LIME 50 LB BG 17 lMG-400 50 LB BG 5 CALCIUM CHLORIDE 80 LB BG 31 gal/min SOLIDS EQUIP Centrifuge Derrick Shaker Derrick Shaker Size Hr 4 24 24 180/180/180 180/180/180 MUD PROPERTY SPECS Weight 9.7 Viscosity 70-90 Filtrate HTHP <8 REMARKS TIME DISTR Last 24 Hrs MUD VOL ACCTG (bbl) SOLIDS ANALYSIS MUD RHEOLOGY & HYDRAULICS Rig Up/Service Oil Added 0 Salt Wt"1o 28.85 nplna Values 0.543/0.231 Drilling 24 Water Added 0 Salt Conc,lblbbl 31.24 kplka (lbos^n!100ft2) 1.665/8.780 Tripping Mud Received 0 Adjusted Solid % 7.67 Bit Loss (psi! %) I Non-Productive Tim Other 0 Oil/Water Ratio 76/24 Bit HHP (hhp I HSI) I Condition Mud Dumped 0 Averge SG Solids 3.3 Bit Jet Vel (ft/s) Rig Repair Shakers 0 Low Gr % 4.1 Ann, Vel DP (ft/min) Testing Evaporation 0 Low Gr Wt, lblbbl 37.12 Ann. Vel DC (ft/min) Cementing Centrifuge 0 High Gr % 3,6 Crit Vel DP (ft/min) 379 Wait on Cement Fonnation 0 High Gr Wt lblbbl 52.75 Crit Vel DC (ft/min) 404 Rig Repair Left in Hole 0 ECD (á) 7642 (lb/gal) 9.7 M-I ENGR I PHONE RIG PHONE WAREHOUSE PHONE DAILY COST CUMULATIVE COST Keith Green ' Lucian Angelescu 907-776-7137 907-776-8680 $ 8,970,50 $ 326,516.84 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . MiSW~~ Operator: FOREST OIL CORP. Report For: Mr. Joe Harris Well Name: West Foreland # 2 Contractor: Kuukpik Drilling Report For: Mr. 1. Otto I Mr.T.Knutson DRILLING ASSEMBLY Bit Size 9.88 in HCM605 Nozzles 2x12/5x13 I 1/32" Drill Pipe Size Length 4.5 in 7237 ft Drill Pipe Size Length 4.5 in 607 ft Drill Collar Size Length 6.61 in 93 ft Sample From Flow Line Temp Depth/TVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/RIOO R6/R3 PV YP I Os/I Om/30m Gel API Fluid Loss HTHP FL Temp Cake APIIHTHP Unc Ret Solids Correct Solids Oil Uncorr Water Oil/Water Ratio Alkal (Porn) CI Whole Mud Salt Lime E-Stability OF ft lblgal s/qt of cP Ib/100ft2 Ib/100fP cc/30 min cc/30 min 1/32" %Vol %Vol %Vol %Vol mg/l %Wt lblbbl OIL-BASEAuD REPORT No. 31 Date 10/14/2004 DepthlTVD 7996 ft I 7655 ft Spud Date 9/17/2004 Mud Type VersaDril Water Depth Activity Drilling Field/Area: West Foreland Description: Development Location: West MacArthur River U Well No.: 11857 CASING Surface 13.875in (á)3003ft (3001 TVD) Intennediate in (á)ft (TVD) Intennediate Production or Liner MUD PROPERTIES Pit(a{02:30 125 7998/7656 9.7(a{125°F 84 150 77/53 43/34 17/15 24 29 21/26/29 5.0(a{250°F 12 10 8.33 68 22 76/24 1.1 50000 26.24 1.43 1066 FL(a{20:30 130 7956/7803 9.7(a{122°F 85 150 74/51 42/31 19/18 23 28 21/25/28 4.8(a{250°F /2 10 8.33 68 22 76/24 1.3 51500 26.81 1.69 1070 REMARKS AND TREATMENT Added Pre mixed Versa drill for volume and dilution, and added lime for alkalinities. Daily Losses = 12 Cumultive Downhole Losses = 403 TIME DISTR Last 24 Hrs MUD VOL ACCTG Rig UplService Oil Added Drilling 18 Water Added Tripping 4 Mud Received Non-Productive Tim Other Condition Mud Dumped Rig Repair 2 Shakers Testing Evaporation Cementing Centrifuge Wait on Cement Formation Rig Repair Left in Hole M-I ENGR I PHONE Keith Green Lucian Angelescu MUD VOLUME (bbl) Hole 863.5 Active Pits 361.5 Total Circulating Vol 1225 In Storage 363 FL(a{15:30 122 78941 9.7(a{1l9°F 89 150 79/53 43/32 18/16 26 27 23/27/30 5.0(a{250°F 12 10 8.33 68 22 76/24 1.7 50500 26.43 2.21 1050 CIRCULATION DATA Pump Make llis Williams WHIO< TSM 1000 HP Pump Size 4.5 X lO.in 5.5 X 9.in Pump Cap 1.962 gallstk 2.638 gallstk Pump stk/min 120(a{95% 117 (a{95% Flow Rate 544 gaìímin Bottoms Up 58.3 min 13812 stk Total Circ Time 94.6 min 22415 stk Circulating Pressure 3484 psi PRODUCTS USED LAST 24 HRS Products Size Amt M-I BAR (4-PL Y LINEr: 50 LB BG 42 PECAN NUT PLUG FIN 50 LB BG 18 G-SEAL 50 LB BG 6 ENGINEERING SERVI( 1 EA 2 MAPCO 200 1 GA TK 840 VERSACOATHF 55 GADM 1 LIME 50 LB BG 10 MIX II FINE 25 LB BG 24 SOLIDS EQUIP Centrifuge Derrick Shaker Derrick Shaker Size Hr o 24 24 180/180/180 180/180/180 MUD PROPERTY SPECS Weight 9.7 Viscosity 70-90 Filtrate HTHP <8 REMARKS Drilling ahead @ 7971,' with no problems. Pumping LCM sweeps every connection or as needed. Total vol of cuttings drilled= 460 total vol of oil recovered= 377 Daily vol of cuttings drilled= 29 Daily vol of oil recovered= 55 SOLIDS ANALYSIS Salt Wt% 26.24 Salt Conc,lblbbl 27.4 Adjusted Solid % 8.01 OillWater Ratio 76124 Averge SG Solids 3.3 Low Gr % 4.3 Low Gr Wt, Iblbbl 38.9 HighGr% 3.7 High Gr Wt Iblbbl 54.8 WAREHOUSE PHONE (bbl) 20 o o o o 2 o o 12 o RIG PHONE 907-776-7137 907-776-8680 MUD RHEOLOGY & HYDRAULICS nplna Values 0.539/0.233 kplka (lb·s^n!IOOft2) 1.963/10.938 Bit Loss (psi I %) 350/10 Bit HHP (hhp I HSI) 111/1.5 Bit Jet Vel (ftls) 201 Ann. Vel DP (ftlmin) 172.34 Ann. Vel DC (ftlmin) 247.27 Crit Vel DP (ftlmin) 431 Crit Vel DC (ftlmin) 460 ECD (á) 7996 (Ib/gan 10.15 DAILY COST CUMULATIVE COST $ 6,061.62 $ 337,337.08 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · e MiSW~~ Operator: FOREST OIL CORP. Report For: Mr. Joe Harris Well Name: West Foreland # 2 Contractor: Kuukpik Drilling Report For: Mr. J. Otto I Mr.T.Knutson DRILLING ASSEMBLY _ Bit Size 9.88 in HCM605 Nozzles 2x12/5x13 I 1/32" Drill Pipe Size Length 4.5 in 6939 ft Drill Pipe Size Length 4.5 in 607 ft Drill Collar Size Length 6.61 in 93 ft OIL-BASE'MUD REPORT No. 32 Date 10/15/2004 DepthlTVD 8277 ft I 7837 ft Spud Date 9/17:2004 Mud Type VersaOril Water Depth Activity POOH FiefdlArea: West Foreland Description: Development Location: West MacArthur River U Well No.: 11857 CASING Surface 13.875in (a)3003ft (3001 TVD) Intennediate in (a)ft (TVD) Intennediate Sample From Flow Line Temp Depth/TVD Mud Weight Funnel Viscosity _Rheology Temp R600/R300 _R200/R100 R61R3 PV YP lOs/10m/30m Gel _API Fluid Loss HTHP FL Temp _Cake API/HTHP _Unc Ret Solids _Correct Solids Oil _ Uncorr Water _Oil/Water Ratio -^lkal (porn) _Cl Whole Mud _Salt Lime _ E-Stability OF ft lb/gal s/qt of cP Ib/lOOft2 Ib/lOOft2 cc/30 min cc/30 min 1/32" %Vol %Vol %Vol %Vol mg/l %Wt lblbbl Production or Liner MUD PROPERTIES Pit@02:30 8277/7837 9.7@120°F 82 150 75151 40/30 21/17 24 27 22/25/27 5.0(á}250°F 12 10 7.96 68 22 76/24 1.5 50500 26.43 1.95 1046 REMARKS AND TREATMENT Daily Losses = 30 Cumulative Downhole losses = 433 - TIME DISTR Last 24 Hrs MUD VOL ACCTG -Rig Up/Service Oil Added Drilling 18 Water Added Tripping 4 Mud Received Non-Productive Tim Other -Circulate 2 Dumped -Rig Repair Shakers Testing Evaporation Cementing Centrifuge Wait on Cement Fonnation ßig Repair Left in Hole M-I ENGR I PHONE Keith Green Lucian Angelescu Pit(á}20:00 -0 82241 9.7(á}122°F 80 150 74/51 41/30 22/18 23 28 20/26/29 5.0(á}250°F 12 10 7.96 68 22 76/24 1.5 50500 26.43 1.95 1030 (bbl) 110 o o o o 3 o 6 21 o RIG PHONE 907-776-7137 MUD VOLUME (bbl) Hole 892. I (Tot)/837 .2(Bit) Active Pits 363.9 Total Circulating Vol 1201.1 In Storage 428 FL(á}1O:00 125 82241 9.7(á}122°F -79 150 75150 40/30 20/17 25 25 20/25/28 5.2(á}250°F 12 10 7.96 68 22 76/24 1.6 51000 26.62 2.08 1040 CIRCULATION DATA Pump Make llis Williams WHI0( TSM 1000 HP Pump Size 4.5 X lO.in 5.5 X 9.in Pump Cap gal/stk gal/stk Pump stklmin Flow Rate Bottoms Up Total Circ Time Circulating Pressure PRODUCTS USED LAST 24 HRS Products Size Amt M-I BAR (4-PL Y LINEI 50 LB BG 100 PECAN NUT PLUG FIN 50 LB BG I MIX II MEDIUM 25 LB BG 16 G-SEAL 50 LB BG 19 SAFE-CARB 250 50 LB BG 15 ENGThŒERINGSERVK 1 EA 2 MAPCO 200 I GA TK 4620 VERSACOAT HF 55 GA DM 2 VERSAWET 55 GADM I LIME 50 LB BG 17 IMG-400 50 LB BG 3 CALCIUM CHLORIDE 80 LB BG 20 gal/min SOLIDS EQUIP Centrifuge Derrick Shaker Derrick Shaker Size Hr 3 18 18 180/180/180 180/180/180 MUD PROPERTY SPECS Weight 9.7 Viscosity 70-90 Filtrate HTHP <8 REMARKS Drilled to 8277' Circ LCM pill & B/U, pump slug POOH, Hole tight @ 7260' and 7020/6960' pump out of hole. 907-776-8680 MUD RHEOLOGY & HYDRAULICS nplna Values 0.556/0.162 kplka (lb·s^nlIOOft2) 1.694/13.927 Bit Loss (psi! %) 11 Bit HHP (hhp I HSI) 11 Bit Jet Vel (ftIs) Ann. Vel DP (ftImin) Ann. Vel DC (ftImin) Crit Vel DP (ftImin) Crit Vel DC (ftImin) ECD (a) 7698 (lb/ga) DAILY COST 405 423 9.7 CUMULATIVE COST $ 18,806,59 $ 356,143.67 Total Vol of Cuttings drilled = 486 Total Vol of Oil recovered = 387 Daily Vol of Cuttings drilled =26 SOLIDS ANALYSIS Salt Wt% 26.43 Salt Conc,lblbbl 27.67 Adjusted Solid % 7.98 OillWater Ratio 76/24 Averge SG Solids 3.3 Low Gr % 4.3 Low Gr Wt, Iblbbl 38.78 High Gr % 3.7 High Gr Wt Iblbbl 54.64 WAREHOUSE PHONE · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · MiSW~~ Operator: FOREST OIL CORP. Report For: Mr. Joe Harris Well Name: West Foreland # 2 Contractor: Kuukpik Drilling Report For: Mr. J. Otto I Mr.T.Knutson DRILLING ASSEMBLY Bit Size 9.88 in HCM605 Nozzles 2x12/5x13 I 1/32" Drill Pipe Size Length 4.5 in 6959 ft Drill Pipe Size Length 4.5 in 606 ft Drill Collar Size Length 6.61 in 93 ft CASING Surface 13.875in (ciì3003ft (3001 TVD) Intermediate in (ciìft (TVD) Intermediate Sample From Flow Line Temp Depth/TVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/RIOO R6/R3 PV YP lOs/1Om/30m Gel API Fluid Loss HTHP FL Temp Cake APIIHTHP Unc Ret Solids Correct Solids Oil Uncorr Water OilfW ater Ratio Alkal (porn) CI Whole Mud Salt Lime E-Stability OF ft Ib/gal s/qt of cP Ib/lOOft2 Ib/l 00ft2 cc/30 min cc/30 min 1/32" %Vol %Vol '%Vol %Vol mg/I %Wt Iblbbl Production or Liner MUD PROPERTIES PIT(aJ,23:00 Ñ/A 8277/7837 9.7(a}115°F 85 150 75150 38/28 20/18 25 25 21/25/30 5.0(aJ,250°F 12 10 10. 68 22 76/24 1.5 50500 26.43 1.95 1038 REMARKS AND TREATMENT Added lime for alkainity's once circ was broken, Daily Losses = 54 Cumulative Downhole losses = 487 TIME DISTR Last 24 Hrs MUD VOL ACCTG Rig Up/Service Oil Added DrìlIing Water Added Tripping 23 Mud Received Non-Productive Tim Other Circulate Dumped Rig Repair Shakers Testing Evaporation Cementing Centrifuge Wait on Cement Formation Rig Repair Left in Hole M-I ENGR I PHONE Keith Green Lucian Angelescu PIT(a}IO:00 N/A 8277/7837 9.7(a}118°F 84 150 75150 40/30 20/17 25 25 20/25/28 5.2(a}250°F 12 10 10. 68 22 76/24 1.6 51000 26.62 2.08 1030 (bbl) o o o o o o 5 o 49 o RIG PHONE 907-776-7137 Oil-BASED MUD REPORT No. 33 Date 10/16/2004 DepthlTVD 8277 ft I 7837 ft Spud Date 9/17/2004 Mud Type VersaDril Water Depth Activity Wash to Bottom Field/Area: West Foreland Description: Development Location: West MacArthur River U Well No.: 11857 MUD VOLUME (bbl) Hole 892(Tot)/838.6(Bit) Active Pits 311 Total Circulating Vol 1149.6 In Storage 428 CIRCULATION DATA Pump Make lIis Williams WHlo( TSM 1000 HP Pump Size 4.5 X lO.in 1 X 9.in Pump Cap 1.962 gallstk .087 gallstk Pump stklmin 90(a}95% 120(a}95% Flow Rãte 187 gaÌÎ'min Bottoms Up 164.8 min 34618 stk Total Circ Time 258.2 min 54222 stk Circulating Pressure 2897 psi PRODUCTS USED LAST 24 HRS Products Size Amt ENGINEERING SERVI( I EA 2 LIME 50LBBG 10 SOLIDS EQUIP Centrifuge Derrick Shaker Derrick Shaker Size Hr o 2 2 180/180/180 180/180/180 MUD PROPERTY SPECS Weight 9.7 Viscosity 70-90 Filtrate HTHP <8 REMARKS Pooh for bit, trip back in with tight spot @ 7069' break circ and wash down. cant drilling. Total Vol of Cuttings drilled = 486 Total Vol of Oil recovered = 405 Daily Vol of Cuttings drilled = 0 SOLIDS ANALYSIS Salt Wt"1o 26.43 Salt ConcJblbbl 27.67 Adjusted Solid % 7.98 Oil/Water Ratio 76/24 Averge SG Solids 3.3 Low Gr % 4.3 Low Gr Wt, ¡blbbl 38.78 HighGr% 3.7 High Gr Wt Iblbbl 54.64 WAREHOUSE PHONE MUD RHEOLOGY & HYDRAULICS nplna Values 0.585/0.126 kplka (Ibos^n!100íP) 1.389/15.638 Bit Loss (psi! %) 41/1.4 Bit HHP (hhp I HSI) 51.1 Bit Jet Vel (ftls) 69 Ann. Vel DP (ftlmin) 59,24 Ann. Vel DC (ftlmin) 85 Crit Vel DP (ftlmin) 391 Crit Vel DC (ftlmin) 404 ECD (aJ 7714 (Ib/ga¡j 10.05 DAILY COST CUMULATIVE COST $ 1,525.80 $ 357,669.47 907-776-8680 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · e MiSW~9~ OIL-BASEAuD REPORT No. 34 Date 10/17/2004 Depth/TVD 8649 ft I 8088 ft Spud Date 9/17/2004 Mud Type VersaDril Water Depth Activity Drilling Field/Area: West Foreland Description: Development Location: West MacArthur River U Well No.: 11857 Operator: FOREST OIL CORP. Report For: Mr. Joe Harris Well Name: West Foreland # 2 Contractor: Kuukpik Drilling Report For: Mr. J. Otto I Mr.T.Knutson DRILLING ASSEMBLY Bit Size 9.88 in HCM605 Nozzles 2x12/5x131 1/32" Drill Pipe Size Length 4.5 in 7894 ft Drill Pipe Size Length 4.5 in 606 ft Drill Collar Size Length 6.61 in 93 ft CIRCULATION DATA Pump Make His Williams WHlO( TSM 1000 HP Pump Size 4.5 X 10.in 1 X 9.in Pump Cap 1.962 gallstk .087 gallstk Pump stklmin 120@95% Flow Rate 10 gal/min Bottoms Up 3374.2 min 404904 stk Total Circ Time ;413.8 min 649656 stk Circulating Pressure 2897 psi PRODUCTS USED LAST 24 HRS Products Size Amt M-IBAR(4-PLYLINEI: 50LBBG 210 PECAN NUT PLUG FIN 50 LB BG 20 PECAN NUT PLUG ME 50 LB BG 10 ENGINEERING SERVI( 1 EA 2 MAPCO 200 1 GA TK 4368 VERSACOAT HF 55 GA DM 1 VERSAWET 55 GADM 1 LIME 50 LB BG 17 IMG-400 50 LB BG 5 CALCIUM CHLORIDE 80 LB BG 13 MIX II FINE 25 LB BG 25 CASING Surface 13.875in (a!3003ft (3001TVD) Intermediate in (a!ft (TVD) Intermediate MUD VOLUME (bbl) Hole 921.3 Active Pits 367.7 Total Circulating Vol 1289 In Storage 369 Production or Liner MUD PROPERTIES Pit(tiJl1 :30 125 8632/8076 1O.0(tiJ 120°F 85 150 78/54 44/33 20/17 24 30 19/27/31 5.0(tiJ250°F 12 11.5 11.5 66.5 22 75/25 1.5 51000 26.62 1.95 1021 Sample From Flow Line Temp Depth/TVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/RlOO R6/R3 PV YP lOs/10m/30m Gel API Fluid Loss HTHP FL Temp Cake APIIHTHP Unc Ret Solids Correct Solids Oil Uncorr Water OillWater Ratio Alkal (Porn) CI Whole Mud Salt Lime E-Stability Out(tiJI0:00 125 85401 9.95(tiJ122°F 86 150 77/53 44/34 20/17 24 29 19/26/33 5.2(tiJ250°F 12 11.5 9.36 66.5 22 75/25 1.4 53000 27.38 1.82 955 OF ft Ib/gal s/qt of cP I b/ 1 00ft2 I b/ 1 00ft2 cc/30 min cc/30 min 1/32" %Vol %Vol %Vol %Vol Hr 6 24 24 SOLIDS EQUIP Centrifuge Derrick Shaker Derrick Shaker Size 180/180/180 180/180/180 mg/I %Wt Ib/bbl MUD PROPERTY SPECS Weight 9.7 Viscosity 70-90 Filtrate HTHP <8 REMARKS AND TREATMENT Building fresh mud for volume and dilution, weighted up using barite to 10ppg for better gas control, added lime for alkalinities REMARKS Drilling ahead with no hole problems @ 8661' Continue to build volume using premix tank and adding to active as required, or dilution is needed Total Vol of Cuttings drilled = 522 Total Vol of Oil recovered = 415 Daily Vol of Cuttings drilled = 36 Daily Vol of Oil recovered = 10 SOLIDS ANALYSIS Salt Wt% 26.62 Salt Conc,lblbbl 27.95 Adjusted Solid % 9.46 Oil/Water Ratio 75/25 Averge SG Solids 3.3 LowGr% 5.1 Low Gr Wt, Iblbbl 46.5 High Gr % 4.3 High Gr Wt Iblbbl 63.87 WAREHOUSE PHONE Daily Losses = 110 Cumulative Downhole losses = 597 TIME DISTR Last 24 Hrs MUD VOL ACCTG Rig Up/Service Oil Added Drilling 24 Water Added Tripping Mud Received Non-Productive Tim Other Circulate Dumped Rig Repair Shakers Testing Evaporation Cementing Centrifuge Wait on Cement Fonnation Rig Repair Left in Hole M-I ENGR I PHONE Keith Green Lucian Angelescu MUD RHEOLOGY & HYDRAULICS nplna Values 0.531/0.189 kplka (lb·s^nl100ft2) 2.107/13.323 Bit Loss (psi I %) I Bit HHP (hhp I HSI) I Bit Jet Vel (ftls) 4 Ann, Vel DP (ftlmin) 3.17 Ann. Vel DC (ftlmin) 4.55 Crit Vel DP (ftlmin) 419 Crit Vel DC (ftlmin) 441 ECD (a! 8649 (lb/galj 10.22 DAILY COST CUMULATIVE COST $ 17,435.06 $ 375,104.53 (bbl) 104 16 o o o 10 o 16 84 o RIG PHONE 907-776-7137 907-776-8680 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · e MiSW~~ -.-...- Operator: FOREST OIL CORP. Report For: Mr. Joe Harris Well Name: West Foreland # 2 Contractor: Kuukpik Drilling Report For: Mr. J. Otto I Mr.T.Knutson DRILLING ASSEMBLY Bit Size 9.88 in HCM605 Nozzles 6xl41 1/32" Drill Pipe Size 4.5 in Drill Pipe Size 4.5 in Drill Collar Size 6.61 in Length 7894 ft Length 606 ft Length 93 ft Sample From Flow Line Temp Depth/TVD Mud Weight Funnel Viscosity Rheology Temp R6001R300 R200IRI00 R6/R3 PV YP lOs/10m/30m Gel API Fluid Loss HTHP FL Temp Cake APIIHTHP Unc Ret Solids Correct Solids Oil Uncorr Water Oil/Water Ratio Atkal (Porn) CI Whole Mud Salt Lime E-Stability cP Ib/l00ft2 Ib/l00ft2 cc/30 min cc/30 min 1/32" %Vol %Vol %Vol %Vol mg/l %Wt 'lblbbl CASING Surface 13.875in (aJ,3003ft (300ITVD) Intermediate in @ft (TVD) Intermediate Production or Liner MUD PROPERTIES OF ft lblgal s/qt OF Pit@22:00 NIA 8677/8106 1O(a}89°F 110 150 79155 45/35 20/18 24 31 20/25/27 5(a}250°F 12 12 9.96 66 22 75/25 1.6 51000 26.62 2.08 1106 Pit@IO:00 N/A 8677/8106 10(a}90°F 120 150 78/53 44/34 20/17 25 28 19/25/28 5@,250°F 12 11.5 9.39 66.5 22 75/25 1.4 52500 27.19 1.82 975 REMARKS AND TREATMENT Premix weight is 10.Oppg with a 75/25 OWR for volume and dilution. Adding Lime for Alkalinity. Daily Losses = 110 Cumulative Downhole losses = 597 TIME DISTR Last 24 Hrs MUD VOL ACCTG Rig Up/Service Oil Added Drilling 4 Water Added Tripping 19 Mud Received Non-Productive Tim Other Circulate Dumped Rig Repair Shakers Testing Evaporation Cementing Centrifuge Wait on Cement Formation Rig Repair Left in Hole M~ENGR/PHONE I Keith Green Lucian Angelescu (bbl) 50 o o o o o o o o o RIG PHONE 907-776-7137 OIL-BASE"'UD REPORT No. 35 Date 10/18/2004 DepthlTVD 8649 ft / 8088 ft Spud Date 9/17/2004 Mud Type VersaDril Water Depth Activity Trip in Hole Field/Area: West Foreland Description: Development Location: West MacArthur River U Well No.: 11857 MUD VOLUME (bbl) Hole 921.3 Active Pits 367.7 Total Circulating Vol 1289 In Storage 428 CIRCULATION DATA Pump Make !\is Williams WHI(){ TSM 1000 HP Pump Size 4.5 X lO.in 1 X 9.in Pump Cap gallstk gallstk Pump stk/min Flow Rate Bottoms Up Total Circ Time Circulating Pressure PRODUCTS USED LAST 24 HRS Products Size Amt M-I BAR (4-PL Y LINEI 50 LB BG 120 ENGINEERING SERVI( I EA 2 MAPCO 200 I GA TK 2100 VERSACOAT HF 55 GA DM I VERSAWET 55 GADM I IMG-400 50 LB BG 5 CALCIUM CHLORIDE 80 LB BG 20 gallmin SOLIDS EQUIP Centrifuge Derrick Shaker Derrick Shaker Size Hr o 5 5 180/180/180 180/180/180 MUD PROPERTY SPECS Weight 10.0 Viscosity 70-90 Filtrate HTIIP <8 REMARKS Continued drilling to 8677'. Circulated before pumping slug and pulling out of hole. Made up new Mud Motor before tripping back into hole with very little fill recorded. Total Vol of Cuttings drilled =: 522 Total Vol of Oil recovered = 415 Daily Vol of Cuttings drilh;d = 36 SOLIDS ANALYSIS Salt Wt% 26.62 Salt Conc,lb/bbl 27.95 Adjusted Solid % 9.96 OillWater Ratio 75/25 Averge SG Solids 3.2 LowGr% 6.1 Low Gr Wt, Iblbbl 55.94 High Gr % 3.8 High Gr Wt Iblbbl 55.97 WAREHOUSE PHONE MUD RHEOLOGY & HYDRAULICS nplna Values 0.522/0.190 kplka (lb·s^nlI00ft2) 2.257/14.096 Bit Loss (psi I %) II Bit HHP (hhp / HSI) II Bit Jet Vel (ft/s) Ann. Vel DP (ft/min) Ann. Vel DC (ft/min) Crit Vel DP (ft/min) Crit Vel DC (ft/min) ECD @ 8649 (lb/gal! DAILY COST $ 9,979.65 433 456 10 CUMULATIVE COST 907-776-8680 $ 379,728.34 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · MiSW~~ Operator: FOREST OIL CORP. Report For: Mr. Joe Harris Well Name: West Foreland # 2 Contractor: Kuukpik Drilling Report For: Mr. J. Otto I Mr.T.Knutson DRILLING ASSEMBLY Bit Size 9.88 in HCM605 Nozzles 6x141 1/32" Drill Pipe Size 4.5 in Drill Pipe Size 4.5 in Drill Collar Size 6.61 in Sample From Flow Line Temp Depth/TVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/R 100 R6/R3 PV YP IOs/1Om/30m Gel API Fluid Loss HTHP FL Temp Cake APIIHTHP Unc Ret Solids Correct Solids Oil Uncorr Water OillWater Ratio Alkal (Porn) Cl Whole Mud Salt Lime E-Stability Length 8418 ft Length 606 ft Length 93 ft cP Ib/100ft2 lb/I 00ft2 cc/30 min cc/30 min 1/32" %Vol %Vol %Vol %Vol mg/l %Wt lblbbl Oil-BASED MUD REPORT No. 36 9173 ft I 8428 ft VersaDril Drilling Date 10/19/2004 Spud Date 9/1712004 Water Depth Field/Area: Description: Location: Well No. : CASING Surface 13.875in (Q)3003ft (3001TVD) lntennediate in (Q)ft (TVD) lntennediate Production or Liner MUD PROPERTIES OF ft lb/gal s/qt of Pit@,22:00 120 9130/8396 1O.0~120°F foo 150 83159 49/38 21/19 24 35 21/26/30 5.0@,250°F 12 12 11.91 66 22 75/25 1.4 56000 28.49 1.82 968 Flow~12:00 120 9004/8300 1O.2~120°F f02 150 87/56 46/35 22/20 31 25 22/30/34 5.1~250°F 12 12 11.91 66 22 75/25 1.8 52000 27 2.34 971 REMARKS AND TREATMENT Continue adding 10.Oppg Pre-Mix as required for Dilution and Volume. Added lime for alkalinity and Versathin to adjust Rheology. Daily Losses = 54 Cumulative Downhole losses = 651 TIME DISTR Last 24 Hrs MUD VOL ACCTG Rig Up/Service Oil Added Drilling 21 Water Added Tripping 2 Mud Received Non-Productive Tim Other Circulate Dumped Rig Repair Shakers Testing Evaporation Cementing Centrifuge Wait on Cement Fonnation Rig Repair Left in Hole M~ENGR/PHONE I Keith Green Kenny Miller MUD VOLUME (bbl) Hole 967.6 Active Pits 397.4 Total Circulating Vol 1365 In Storage 373 DepthlTVD Mud Type Activity West Foreland Development West MacArthur River U 11857 CIRCULATION DATA Pump Make lIis Williams WHl()( TSM 1000 HP Pump Size 4.5 X lO.in 1 X 9.in Pump Cap 1.962 gaIlstk .087 gaIlstk Pump stk/min 89~95% 90~95% Flow Rãte 182 gaIlmin Bottoms Up 194.4 min 34793 stk Total Circ Time 315 min 56385 stk Circulating Pressure 2213 psi PRODUCTS USED LAST 24 HRS Products Size Amt M-I BAR (4-PL Y LINEr 50 LB BG 180 PECAN NUT PLUG FIN 50 LB BG 40 ENGINEERING SERVI( 1 EA 2 MAPCO 200 1 GA TK 2310 VERSACOAT HF 55 GA DM 1 VERSA WET 55GADM 1 VERSATHIN HF 55 GA DM 1 LIME 50 LB BG 17 IMG-400 50 LB BG 3 CALCIUM CHLORIDE 80 LB BG 20 MIX n FINE 25 LB BG 50 SOLIDS EQUIP Centrifuge Derrick Shaker Derrick Shaker Size Hr 1 22 22 180/180/180 180/180/180 MUD PROPERTY SPECS Weight 10.0 Viscosity 70-90 Filtrate HTHP <8 REMARKS Trip back to bottom and break circulation cont drilling @ 9175' pumpming LCM sweeps on connections, 907-776-8680 Total Vol of Cuttings drilled = 522 Total Vol of Oil recovered = 435 Daily Vol of Cuttings drilled = 536 Daily Vol of Oil recovered = 20 SOLIDS ANALYSIS Salt Wt% 28.49 Salt Conc,lblbbl 30.69 Adjusted Solid % 9.72 OilIWater Ratio 75/25 Averge SG Solids 3.2 LowGr% 6. Low Gr Wt, Iblbbl 54.66 HighGr% 3.7 High Gr Wt Iblbbl 54.51 WAREHOUSE PHONE MUD RHEOLOGY & HYDRAULICS nplna Values 0.492/0.198 kp/ka (lb's^n!100ft2) 2.920/14.685 Bit Loss (psi I %) 37/1.7 Bit HHP (hhp I HSI) 4/.1 Bit Jet Vel (ftls) 65 Ann. Vel DP (ftlmin) 57.66 Ann. Vel DC (ftlmin) 82.73 Crit Vel DP (ftlmin) 453 Crit Vel DC (ftlmin) 478 ECD (Q) 9173 (lb/gaJ) 10.44 DAILY COST CUMULATIVE COST $ 14,113.51 $ 393,841.85 (bbl) 55 o o o o 12 o 15 27 o RIG PHONE 907-776-7137 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Operator: FOREST OIL CORP. Report For: Mr. Fred Brent Well Name: West Foreland # 2 Contractor: Kuukpik Drilling Report For: Mr. J. Otto I Mr.T,Knutson DRILLING ASSEMBLY 8632 ft, 4.5-in DP 606 ft, 4.5-in HWDP 93 ft, 6.61-in DC 31 ft, 6.7S-in MWD 25 ft, 7 -in MudM ft, -in Nozzles 6x14 1/32" Bit 9.875-in HCM605 Sample From Flowline Temp DepthlTVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/R 100 'R6/R3 PV YP 10s/10m/30m Gel API Fluid Loss HTHP Fluid Loss Cake APT IHT Unc Ret Solids Correct Solids Synthetic Uncorr Water SyntheticlWater Ratio Alkal Mud (Pom) CI- Whole Mud Salt Lime Emul Stability cP Ib/100ft2 Ib/100ft2 ccJ30min ccJ30min 1/32" %Vol %Vol %Vol %Vol SYNTHETIC-BASED MUD REPORT No. 37 Field/Area West Foreland Description Development Location West MacArthur River U Water Depth : 0 ft M-I Well: 11857 CASING (*TVD) MUD VOLUME (bbl) 13.875-in @3003 ft (3001 TVD) Hole 987 Active Pits 375 Total Circulating Volume 1362 MUD PROPERTIES PIT 22:00 Pit 14:00 138 136 9370/8575 9288/8514 10.0~130 10.0~124 95 94 150 150 80/55 80/55 45~ 4&35 18/17 18/17 25 25 30 30 20/25130 20/26130 OF ft Iblgal s/qt of mg/L O/OWt Ib/bbl 5~250 12 11 8.96 67 22 75/25.0 1.1 52500 27.19 1.43 985 5@250 12 11 8.96 67 22 75/25.0 1.05 51000 26.62 1.37 986 0:00 0:00 I I ,O@ .O@ /I ~ I ~ I REMARKS AND TREATMENT 1.0 /.0 Depthll "D : 9387 ft I 8586 ft Date : 10/20/2004 Spud Date: 9/17/2004 Mud Type: VersaDril Activity : DrillinQ CIRCULATION DATA Pump Make Ellis WHliams WH100( TSM 1000 HP Pump Liner x Stk 4.5x10 in 1x9 in Pump Capacity gal/stk 1.962 0.087 Pump stk/min 11 0~950/0 1 02~950/0 Flow Rate 225 gal/min Pump Pressure 3130 psi Bottoms Up 160.2 min 33961 stk Total Circulation 254.2 min 53899 stk PRODUCTS USED Last 24 hr Size Amount 50 LB BG 20 25 LB BG 20 1EA 2 1 GA TK 2100 50 LB BG 10 Products PECAN NUT PLUG FINE MIX II MEDIUM ENGINEERING SERVICE MAPCO 200 LIME II SOLIDS CONTROL EQUIPMENT Last 24 hr Type Model/Size Hrs Used Centrifuge 16 Derrick Shaker 1 180/180/180 24 Derrick Shaker 2 180/180/180 24 MUD PROPERTY SPECS Weight 10 Viscosity 70-90 Filtrate HTHP <8 Actual 10 95 REMARKS Continued drilling ahead to 9173', Circulated and conditioned the mud system due to excessive mud density. Diluted the system with whole mud from pre-mix while using the rig's centrifuge and Swaco centrifuge. Resumed drilling ahead while pumping LCM sweeps on connections to 9288'. Circulated while troubleshoot mud pump. Resume drilling/sliding ahead continuing pumping LCM sweeps on connections. SOLIDS ANALYSIS RHEOLOGY & HYDRAULICS 27.19 nplna 0.541/0.198 28.77 Kp/Ka 2.016/13,139 8.89 Bit Pressure Loss/% 57/1.8 75/25 Bit HHP/HSI 81 .1 2.9 Jet Velocity 80 7 Va Pipe 71.3 63.36 Va Collars 102.3 1.9 Cva Pipe 426 28.24 Cva Collars 450 ECD at Shoe 10.27 ECD at TD 10.42 Pre-mix weighing 9.7ppg, Mapco200 Base fluid, Lime, Versathin. TIME DISTRIBUTION Last 24 hrs Rig UplService Drilling Tripping Non-Productive Tirr Circulate Rig Repair Testing Cementing Wait on Cement Rig Repair 20.5 1 2.5 M-I ENGR I PHONE Kenny Miller 0 Billv Hunter MUD VOL ACCTG Synthetic Added Water Added Mud Received Mud Retumed Dumped Shakers Evaporation Centrifuge Fonnation Left in Hole Other RIG PHONE (bbl) 50 20 15 22 Salt Wt% Salt Cone Adjusted Solids SyntheticlWater Ratio Average SG Solids Low Gravity % Low Gravity WI. High Gravity % High Gravity WI. WAREHOUSE PHONE 907-776-8680 DAILY COST CUMULATIVE COST $7.460.80 $401.302.65 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · ,.....-_.."._, -.,_._.,""".*'~''-4~-"__,;,,,.._; Mí BWAC~~.- ""C- ""'c~::::::::'~ SYNTHETIC-BASED MUD REPORT No. 38 Operator: FOREST OIL CORP. Field/Area : West Foreland Report For: Mr. Fred Brent Description: Development Well Name: West Foreland # 2 Location : West MacArthur River U Contractor: Kuukpik Drilling Water Depth : 0 ft Report For: Mr. J. Otto I Mr.T.Knutson RiQ Name: # 5 DRILLING ASSEMBLY CASING ("TVD) ft, 4,,5-in DP 13.875-in @3003ft (3001 TVD) 606 ft, 4,,5-in HWDP 93 ft, 6,61-in DC 31 ft, 6.75-in MWD 25 ft, 7 -in MudM ft, -in Nozzles 14x6 1/32" Bit 9,,875-in FS2653 Sample From Flowline Temp DepthlTVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/R100 R6/R3 PV YP 1 Os/1 Om/30m Gel API Fluid Loss HTHP Fluid Loss Cake APTlHT Unc Ret Solids Correct Solids Synthetic Uncorr Water SyntheticlWater Ratio Alkal Mud (Psm) CI- Whole Mud Salt Lime Emul Stability cP Ib/100ft2 Ib/100ft> ccI30min ccI30min 1/32" %Vol %Vol %Vol %Vol OF ft Iblgal s/qt OF MUD PROPERTIES Pit 23:00 0:00 na 943~8630 I 9.9~90 "O~ 94 150 80/57 48/37 20/19 23 34 20/26/30 H na 5.0~250 "O@ na/2 I 10 7,,96 68 22 76/24 1 51000 26.62 1,,3 946 MUD VOLUME (bbl) Hole I Active Pits 1060 229 Total Circulating Volume 229 Depth Drilled Last 24hr 16 ft Volume Drilled Last 24hr 2 bbl 0:00 0:00 mglL %Wt Iblbbl I "O@ I .0@1 H "O@ I "O@ I Reserve Volume bbl 373 REMARKS A~b TREATMENT Maintain volume with pre-mix" Diluted the system with Base Fluid" Prepared slug" Total Vol of Cuttings drilled = 548 Total Vol of Oil recovered = 515 Daily Vol of Cuttings drilled =2 Daily Vol of Oil recovered = 25 TIME DISTRIBUTION Last 24 hIS Rig UplService Drilling 7 Tripping 15.5 Non-Productive TifT Circulate 1,,5 Rig Repair Testing Cementing Wait on Cement Rig Repair M-I ENGR I PHONE Kenny Miller 0 Billy Hunter MUD VOL ACCTG (bbl) Synthetic Added Water Added Mud Received Mud Returned Dumped Shakers 20 Evaporation 10 Centrifuge 15 F onnation Left in Hole Other 28 RIG PHONE 907-776-7137 DepthlTVD : 9438 ft I 8630 ft Date: 10/21/2004 Spud Date: 911712004 Mud Type: VersaDril Activity : Trippin!:l CIRCULATION DATA Pump Make Ells WHams WH1000 TSM 1000 HP Pump Liner x Stk 4.5x10 in Pump Capacity gallstk 1.962 Pump stklmin 0~95% Flow Rate Pump Pressure Bottoms Up Total Circulation PRODUCTS USED Last 24 hr Size Amount 1 EA 5.5x9 in 2.638 0@95% gaVmin psi Products ENGINEERING SERVICE 2 II SOLIDS CONTROL EQUIPMENT Last 24 hr Type ModellSize HIS Used Centrifuge 8.0 Derrick Shaker 1 1801180/180 24,,0 Derrick Shaker 2 180/180/180 24.0 MUD PROPERTY SPECS Weight 10 Viscosity 70-90 Filtrate HTHP <8 Actual 9.9 94 5 REMARKå Continued drilling and sliding to rebuild angle to 9,433" Began decreasing the mud density from 10,,0 to 9.7ppg while drilling ahead" When the mud reached 9.9ppg the density was allowed to stabilize to maintain a 9.9ppg with Base Fluid and the Swaco centrifuge" Circulated thé 9..9 around before pulling six stands to 9122'" Cont. trip out hole" Troubleshoot mud pumps before pumping slug and pulled out of hole for BHA change" SOLIDS ANALYSIS SaltWt% Salt Conc Adjusted Solids SyntheticlWater Ratio Average SG Solids Low Gravity % Low Gravity Wt. High Gravity % High Gravity Wt. WAREHOUSE PHONE 907-776-8680 26.62 27,,95 7.96 76/24 3 5.7 52,07 2,,2 32,,82 RHEOLOGV & HYDRAULICS nplna KplKa Bit Pressure Loss/% Bit HHP/HSI Jet Velocity Va Pipe Va Collars Cva Pipe Cva Collars ECD at Shoe DAILY COST CUMULATIVE COST $1.350.00 $402.652.65 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Mi S'^'~g~~,_ .-....._""'",_""'_........ .'\ "I'".:' SYNTHETIC-BASED MUD REPORT No. 39 Operator: FOREST OIL CORP. FieldlArea : West Foreland Report For: Mr. Fred Brent Description: Development Well Name: West Foreland # 2 Location : West MacArthur River U Contractor: Kuukpik Drilling Water Depth : 0 ft Report For: Mr. J. Otto I Mr.T.Knutson Rig Name: # 5 DRILLING ASSEMBLY CASING (*TVD) 8840 ft, 4.5-in DP 13.875-in @3OO3 ft (3001 TVD) 606 ft. 4.5-in HWDP 93 ft, 6.61-in DC 31 ft, 6.75-in MWD 25 ft, 7 -in MudM ft, -in Nozzles 22x3 1/32" Bit 9.875-in MX-20 Sample From Flowline Temp Depth/TVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/R 100 R6/R3 PV YP 1 Os/1 Om/30m Gel API Fluid Loss HTHP Fluid Loss Cake APT/HT Unc Ret Solids Correct Solids Synthetic Uncorr Water SyntheticlWater Ratio Alkal Mud (Psm) CI- Whole Mud Salt Lime Emul Stability cP Ib/100ft2 Ib/100ft2 ccI30min ccl30min 1/32" %Vol %Vol %Vol %Vol MUD PROPERTIES Pit 23:00 Pit 15:00 130 118 9580/8738 9446/8636 10.0@130 10.1@118 95 111 150 150 80/55 77/53 45/34 43/32 17/16 17/15 25 24 30 29 19/24/28 18/24/27 OF ft Ib/gal s/qt OF mg/L %Wt Ib/bbl 5.8@250 /2 12 10.01 66 22 75/25 1.9 51000 26.62 2.47 914 5.8@250 /2 12 9.93 66 22 75/25 1.95 51500 26.81 2.54 904 MUD VOLUME (bbl) Hole I Active Pits 1005 295 Total Circulating Volume 1300 Depth Drilled Last 24hr 157 ft Volume Drilled Last 24hr 15 bbl 0:00 0:00 I I ,O@ .O@ /I .O@ I .O@ / DepthlTVD: 9595 ft I 8749 ft Date : 10/22/2004 Spud Date: 9/17/2004 Mud Type: VersaDril Activity : Drilling CIRCULATION DATA Pump Make ElisWillamsWH\OOO TSM 1000HP Pump Liner x Stk 4.5x10 in 5.5x9 in Pump Capacity gal/stk 1.962 2.638 Pump stklmin 117@95% 101@95% Flow Rate 496 gaVmin Pump Pressure 3426 psi Bottoms Up 74 min 16127 stk Total Circulation 110.1 min 23998 stk PRODUCTS USED Last 24 hr Size Amount 50 LB BG 150 50 LB BG 20 25 LB BG 20 1EA 2 1 GA TK 2268 55GADM 2 55 GA DM 2 50 LB BG 40 50LBBG 1 80 LB BG 15 Products M-I BAR (4-PL Y LINED BAG PECAN NUT PLUG MEDIU~ MIX II MEDIUM ENGINEERING SERVICE MAPCO 200 VERSACOAT HF VERSAWET LIME IMG-400 CALCIUM CHLORIDE PWD /I SOLIDS CONTROL EQUIPMENT Last 24 hr Type Model/Size Hrs Used Centrifuge 10.0 Derrick Shaker 1 180/180/180 24.0 Derrick Shaker 2 180/180/180 24.0 MUD PROPERTY SPECS Weight 10 Viscosity 70-90 Filtrate HTHP <8 Actual 10.0 95 5.8 Reserve Volume bbl 434 REMARKSA~bTREATMENT REMARKå Maintain volume with pre-mix. Added Lime, Versathin. VersaCoat, VersaWet. Continued pulling out of hole. Make up new BHA. Tripped in hole to xxxx and began Total Vol of Cuttings drilled = 548 Total Vol of Oil recovered = 515 Daily Vol of washing/reaming to bottom. Resumed drilling ahead while pumping LCM Sweep on Cuttings drilled =2 Daily Vol of Oil recovered = 25 Daily Downhole losses = 0 connections. Built 75 bbls. new mud. Cummulative Downhole losses= 651+x TIME DISTRIBUTION Last 24 hrs Rig Up/Service Drilling 9.5 Tripping 11.5 Non-Productive Tirr Reaming 1.5 Condition Hole 1.5 Testing Cementing Wait on Cement Rig Repair M-I ENGR I PHONE Kenny Miller 0 Billy Hunter MUD VOL ACCTG Synthetic Added Water Added Mud Received Mud Returned Dumped Shakers Evaporation Centrifuge Formation Left in Hole Other RIG PHONE 907-776-7137 (bbl) 54 16 7 10 SOLIDS ANALYSIS SaltWt% Salt Conc Adjusted Solids SyntheticlWater Ratio Average SG Solids Low Gravity % Low Gravity WI. High Gravity % High Gravity WI. WAREHOUSE PHONE 907-776-8680 26.62 27.95 9,96 75/25 2.7 9 82.2 .9 13.54 RHEOLOGY & HYDRAULICS np/na 0.541/0.215 Kp/Ka 2.016/12.023 Bit Pressure Loss/% 183/ 5.3 Bit HHP/HSI 53/ .7 Jet Velocity 143 Va Pipe 157.1 Va Collars 225.4 Cva Pipe 425 Cva Collars 451 ECD at Shoe 10.31 DAILY COST $12,863.09 CUMULATIVE COST $415,515.74 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Mi S'^'~~. SYNTHETIC-BASED MUD REPORT No. 40 Operator: FOREST OIL CORP. Field/Area West Foreland Report For: Mr. Fred Brent Description Development Well Name: West Foreland # 2 Location West MacArthur River U Contractor: Kuukpik Drilling Water Depth : 0 ft Report For: Mr. J. Otto I Mr.T.Knutson RiQ Name: # 5 DRILLING ASSEMBLY CASING (*TVD) 9132 ft, 4.5-in DP 13.875-in @3OO3 ft (3001 TVD) 606 ft, 4.5-in HWDP 93 ft, 6.61-in DC 31 ft, 6.75-in MWD 25 ft, 7 -in MudM ft, -in Nozzles 22x3 1/32" Bit 9,875-in MX-20 Sample From Flowline Temp DepthlTVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/R 1 00 R6/R3 PV YP 1 Os/1 Om/30m Gel API Fluid Loss HTHP Fluid Loss Cake APTlHT Unc Ret Solids Correct Solids Synthetic Uncorr Water SyntheticlWater Ratio Alkal Mud (Psm) CI- Whole Mud Salt Lime Emul Stability cP Ib/100ft2 Ib/100ft> ccl30min ccl30min 1/32" %Vol %Vol %Vol %Vol OF ft Ib/gal s/qt of MUD PROPERTIES Pit 23:00 Flow 15:00 138 138 9930/8962 9850/8918 10.0@138 10.0@138 91 85 150 150 8&54 7&51 43/33 42/31 16/15 15/14 26 25 28 26 18n4~ 17n3n6 MUD VOLUME (bbl) Hole I Active Pits 1035 340 Total Circulating Volume 1371 Depth Drilled Last 24hr 335 ft Volume Drilled Last 24hr 32 bbl 0:00 0:00 mg/L %Wt Ib/bbl 6.0@250 /2 11.5 9.51 66.5 22 75/25 2.1 50000 26.24 2.73 943 5.7@250 /2 11.5 9.34 67.5 21 76n4 2.7 53000 28.31 3.51 922 / .O@ / .O@ /I .O@ / .O@ / Reserve Volume bbl 346 REMARKS A~b TKEAI RIIENT Maintain volume with pre-mix. Added Lime. Versathin, VersaCoat, VersaWet. Total Vol of Cuttings drilled = 548 Total Vol of Oil recovered = 515+20 Daily Vol of Cuttings drilled =20 Daily Vol of Oil recovered = 15 Daily Downhole losses =5 Cummulative Downhole losses= 656 TIME DISTRIBUTION Last 24 hrs Rig Up/Service Drilling 21 Tripping Non-Productive Tirr Circulate 3 Condition Hole Testing Cementing Wait on Cement Rig Repair M-I ENGR / PHONE Kenny Miller 0 Billy Hunter MUD VOL ACCTG Synthetic Added Water Added Mud Received Mud Returned Dumped Shakers Evaporation Centrifuge Formation Left in Hole Other (bbl) 75 24 10 10 5 102 RIG PHONE 907-776-7137 DepthlTVD : 9930 ft I 9000 ft Date : 10/23/2004 Spud Date: 9/1712004 Mud Type: VersaDril Activity : Circ. CIRCULATION DATA Pump Make Ells WiIams WH1000 TSM 1000 HP Pump Liner x Stk 4.5x10 in 5.5x9 in Pump Capacity gal/stk 1.962 2,638 Pump stklmin 117@95% 120@95% Flow Rate 546 gaVmin Pump Pressure 3426 psi Bottoms Up 68.9 min 16322 stk Total Circulation 105.5 min 24993 stk PRODUCTS USED Last 24 hr Size Amount 50 LB BG 300 1EA 2 1 GA TK 3150 55 GA DM 1 55 GA DM 1 50 LB BG 10 50 LB BG 1 80 LB BG 10 Products M-I BAR (4-PL Y LINED BAG ENGINEERING SERVICE MAPCO 200 VERSACOAT HF VERSAWET LIME IMG-400 CALCIUM CHLORIDE PWD /I SOLIDS CONTROL EQUIPMENT Last 24 hr Type Model/Size Hrs Used Centrifuge 24,0 Derrick Shaker 1 180/180/180 24.0 Derrick Shaker 2 180/180/180 24.0 MUD PROPERTY SPECS Weight 10 Viscosity 70-90 Filtrate HTHP <8 Actual 10.0 91 6 REMA~Kà Resumed drilling ahead while pumping LCM Sweep on connections. Built 80 bbls new mud for volume. Running centrifuges to condition solids while minimizing excessive fluid generated.... SOLIDS ANALYSIS SaltWt% Salt Cone Adjusted Solids SyntheticlWater Ratio Average SG Solids Low Gravity % Low Gravity WI. High Gravity % High Gravity WI. WAREHOUSE PHONE 907-776-8680 26.24 27.4 9,51 75/25 2.8 8 73.21 1.5 21.43 RHEOLOGY & HYDRAULICS np/na 0.567/0.225 Kp/Ka 1.678/11.091 Bit Pressure Loss/% 221/6.5 Bit HHP/HSI 71/ .9 Jet Velocity 157 Va Pipe 173 Va Collars 248.2 Cva Pipe 417 Cva Collars 444 ECD at Shoe 10.3 DAILY COST $13,412.75 CUMULATIVE COST $428,928.49 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Mi SWAC~__. """'""~':7"'-'~ SYNTHETIC-BASED MUD REPORT No. 41 Operator: FOREST OIL CORP. Field/Area West Foreland Report For: Mr. Fred Brent Description Development Well Name: West Foreland # 2 Location West MacArthur River U Contractor: Kuukpik Drilling Water Depth : 0 ft Report For: Mr. J. Otto I Mr.T.Knutson Rig Name: # 5 DRILLING ASSEMBLY CASING ("1VD) 2037 ft, 4.5-in DP 13.875-in @3OO3 ft (3001 TVD) 606 ft. 4,5-in HWDP 93 ft. 6.61-in DC 31 ft. 6.75-in MWD 25 ft. 7 -in MudM ft,-in Nozzles 22x2 1132" Bit 9.875-in mx-s18 OF ft Ib/gal s/qt OF MUD PROPERTIES Pit 23:00 Pit 15:00 nla nla 9930/8962 993018962 10.0@78 10.1@78 150 152 150 150 80/54 81/54 44133 44/33 16115 16115 26 27 28 27 18/23/26 18/22/25 Sample From Flowline Temp DepthfTVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/R 100 R6/R3 PV YP 1 0511 Om/30m Gel API Fluid Loss HTHP Fluid Loss Cake APTlHT Unc Ret Solids Correct Solids Synthetic Uncorr Water SyntheticlWater Ratio Alkal Mud (Psm) CI- Whole Mud Salt Lime Emul Stability cP Ib/100ft2 Ib/100ft> ccl30min ccl30min 1/32" %Vol %Vol %Vol %Vol 6.0@25O 12 11.5 11.5 66.5 22 75125 2 50500 26.43 2.6 940 6,0@25O 12 11.5 9.48 66.5 22 75125 2 50500 26.43 2,6 938 mglL %Wt Ib/bbl MUD VOLUME (bbI) Hole I Active Pits 1080 248 Total Circulating Volume 638 Depth Drilled Last 24hr ft Volume Drilled Last 24hr Obb! 0:00 0:00 I I .O@ .O@ II .O@ I .O@ I Depthll ýD : 9930 ft I 8962 ft Date : 10/2412004 Spud Date: 9117/2004 Mud Type: VersaDril Activity : TriDØina CIRCULATION DATA Pump Make ElJlaW-.oWH'OOO TSM'OOO"" Pump Liner x Stk 4.5x10 in Pump Capacity gallstk 1.962 Pump stklmin 0«2195% Flow Rate Pump Pressure Bottoms Up Total Circulation PRODUCTS JSED Last 24 hr Size Amount 50 LB BG 140 1EA 2 5.5x9 in 2.638 0@95% gallmin psi Products 104-1 BAR (4-PL Y LINED BAG. ENGINEERING SERVICE II SOLIDS CONTROL EQUIPMENT Last 24 hr Type Model/Size Hrs Used Centrifuge Derrick Shaker 1 180/180/180 Derrick Shaker 2 18011801180 MUD PROPERTY SPECS Weight 10 Viscosity 70-90 Filtrate HTHP <8 Actual 10.0 150 6 Reserve Volume bbl 346 REMARKSA~~TKEATMENT REMARKå No mud treatment last 24 hours Total Vol of Cuttings drilled = 548 Total Vol of Continued circulating before before pumping slug and pulling out of hole due to engine Oil recovered = 625 Daily Vol of Cuttings drilled =0 Daily Vol of Oil recovered issues for the rig. Test BOP's while making up a re-run bit.. = 45 Daily Downhole losses =49 Cummulative Downhole losses= 705 TIME DIStRIBUTION Last 24 hrs Rig Up/Service Drilling Tripping 16.5 Non-Productive Tirr Testing 6.5 Condition Hole Testing Cementing Wait on Cement Rig Repair MUD VOL ACCTG Synthetic Added "water Added Mud Received Mud Returned Dumped Shakers Evaporation Centrifuge Formation Left in Hole Other (bbI) 49 5 M-I ENGR / PHONE Kenny Miller 0 Billy Hunter RIG PHONE 907-776-7137 SOLIDS ANALYSIS SaltWt% Salt Conc ,.Adjusted Solids SyntheticlWater Ratio Average SG Solids Low Gravity % Low Gravity WI. High Gravity % High Gravity WI. WAREHOUSE PHONE 907-776-8680 26.43 27.67 9.48 75/25 2,8 8 73.09 1,4 21.27 RHEOLOGY & HYDRAULICS np/na 0.567/0.225 Kp/Ka 1.678/11.091 Bit Pressure Loss/% 11 Bit HHP/HSI /1 Jet Velocity "va Pipe Va Collars Cva Pipe 397 Cva Collars 413 ECD at Shoe DAILY COST CUMULATIVE COST $2.589.00 $431.517.49 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Mí B'^'~g~~ ,---..-..'" Operator: FOREST OIL CORP. Report For: Mr. Fred Brent Well Name: West Foreland # 2 Contractor: Kuukpik Drilling Report For: Mr. J. Otto I Mr.T.Knutson DRILUNG ASSEMBLY 9321 ft, 4.5-in DP 606 ft. 4.5-in HWOP 93ft, 6.61-in DC 31 ft. 6.75-in MWD 25 ft. 7-in MudM ft.-in Nozzles 22x2 1132'" Bit 9.875-in mx-s18 Sample From Flowline Temp DepthrrvD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/R100 R6/R3 PV YP 1 Os/1 Om/30m Gel API Fluid loss HTHP Fluid loss Cake APTlHT Unc Ret Solids Correct Solids Synthetic Uncorr Water SyntheticlWater Ratio Alkal Mud (Psm) CI- Whole Mud Salt Lime Emul Stability cP Ib/100W Ib/100ft2 ccl30min ccI30min 1/32" %Vol %Vol %Vol %Vol SYNTHETIC-BASED MUD REPORT No. 42 Field/Area West Foreland Description Development Location West MacArthur River U Water Depth 0 ft Ri~ Name: #5 CASING ("1VD) 13.875-in @3003 It (3001 TVD) 'F ft Ib/gal s/qt 'F MUD PROPERTIES Pit 23:00 F11ow14:10 136 125 1007~9055 998~8998 10.0@136 10.1@125 88 95 150 150 80154 80/54 45/34 44133 16/15 16/15 26 26 28 28 18/23/26 18/23/25 mg/l %Wt Ib/bbl 6.0@250 /2 12 9.71 66 22 75/25 2.5 56150 28.54 3.25 934 6.0@25O 12 13 10.69 65 22 75/25 2.7 56500 28.67 3.51 948 Reserve Volume bbl 358 REMARKSA~TKEATMENT Maintain volume with pre-mix. Added lime, Vefflathin, VefflaCoat, VefflaWe¡ Total Vol of Cuttings drilled" 558 Total Vol of Oíl rec.overed "635 Daily Vol of Cuttings drilìed "1 () Daily Vol of Oil recovered "1 () Daily Downhole losses =(} Cummulat!ve Downhole fcsses=705 tiME DISTRIBUTION Last 24 hrs Rig Up/Service Drilling 12.5 Tripping 7 Non-Productive Tirr Condition Mud 4.5 Condition Hole Testing Cementing W!Iit on Cement ~iº Repair M-I ENGR I PHONE Kenny Miner 0 Billy Hunter MUD VOL ACCTG (bbI) Synthetic Added 64 Water Added Mud Received Mud Returned Dumped Shakers 12 Evaporation Centrifuge 10 F onnation Left in Hole Other RIG PHONE 907-776-7137 MUD VOLUME (bbI) Hole I Active Pits 1047 321 Total Circulating Volume 1368 Depth Drilled last 24hr 146 ft Volume Drílled last 24hr 14 bbI 0:00 0:00 I ¡ .O@J O@J 1/ .O@ I .O@ I Depthll vD : 10076 ft / 9055 ft Date : 10/25/2004 Spud Date: 9/17/2004 Mud Type: VersaDril Activity : DrillinQ CIRCUlATION DATA Pump Make ___'000 TSM'OOOHÞ Pump Liner x Stk 4.5x10 in 5.5x9 in Pump Capacity gal/stk 1.962 2.638 Pump stk/min 108ft95% 105@95% Flow Rate 489 galhnin Pump Pressure 3241 psi Bottoms Up 78.1 mín 16636 stk Total Circulation 117.5 min 25027 stk PRODUCTS USED Last 24 hr Size Amount 50 LB BG 120 50 lB BG 10 25 LB BG 10 1 EA 2 1 GA TK 2688 55 GA DM 1 55 GA DM 1 55 GA DM 2 50 LB BG 16 Products M-I BAR (4-Pl Y LINED BAG PECAN NUT PLUG MEDU~ r~'ux ~! MED~UM ENGINEERING SERVICE MAPCO 200 - VERSACOAf HF VERSAWET VERSATHIN HF LIME /I SOLIDS CONTROl. EQUIPMENT Last 24 hr Type Modei/Size Hrs Used Centrifuge 12.0 Derrick Shaker 1 180/180/180 24.0 Derrick Shaker 2 180/1801180 24.0 MUD PROPERTY SPECS Weight 10 Viscosity 70-90 Filtrate HTHP <8 Actual 10.0 88 6 REMARKå Continue tripping in hole Break CirCl)latioo before resuming drilling ahead. PuH out of hole one stand and circulated whìle troubleshoot mud pump. resume driUing ahead while pumping LCM Sweep every connecíion. SOLIDS ANALYSIS SaltWt% Salt Cone Adjusted Solids SyntheticlWater Ratio ,.Average SG Solids low Gravity % Low Gravity WI. High Gravity % High Gravity WI. WAREHOUSE PHONE 907-776-8680 .; 28,54 30.77 9.71 75/25 2.7 8.9 SO.89 .8 12.04 RHEOLOGY & HYDRAULICS np/na 0.567/0.233 Kp/Ka 1.678/10.938 Bit Pressure loss/% 400/12.3 Bit HHP/HSI 114/1.5 Jet Velocity 211 Va Pipe 154.9 Va Collars 222.3 Cva Pipe 424 Cva Collars 453 ECD at Shoe 10.3 DAILY COST CUMULATIVE COST $12,484.87 $444.002.36 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · MIBV"I\r-Q. ..,~~ Operator: FOREST OIL CORP. Report For: Mr. Fred Brent Well Name: west Foreland # 2 Contractor: Kuukpik Drilling Report For: Mr, J, Otto I Mr.T.Knutson DRILLING ASSEMBLY 9620 ft, 4.5-in DP 606 ft, 4.5-in HWDP 93 ft, 6.61-in DC 31 ft, 6.75-in MWD 25 ft, 7-in MudM ft, -in Nozzles 22x2 1m' Bit 9.875-in mx-<318 Sample From Flowline Temp Depth/TVD Mud Weight Funnel Viscosity Rheology Temp R6001R3OO R2OOIR1oo R6/R3 PV YP 10s110ml3Om Gel API Fluid Loss HTHP Fluid Loss Cake APT/HT Unc Ret Solids Correct Solids Synthetic Uncorr Water SyntheticlWater Ratio Alkal Mud (Psm) CI- Whole Mud Salt lime Emul Stability cP 1b11 ()()ft" 1b/1 ()()ft" ccl30rrún ccI30min 1f3Z' %VoI %VoI %Vol %VoI SYNTHETIC-BASED MUD REPORT No. 43 Fleld/Area : West Foreland Description : Development Location : West MacArthur River U Water Depth: 0 ft Ria Name: # 5 CASING rTVD) MUD VOLUME (bbl) 13.875-in @3003 ft (3001 TVD) Hole I Active Pit$ 1074 369 Total Circulating Volume 1443 Depth Drilled last 24hr 299ft Volume DriUed last 24hr 28bb1 OF ft lblgal slqt OF MUD PROPERTIES Pit 23:00 Pit 13:13 145 140 1037019240 1028519186 10.0@138 10.0@132 84 85 150 150 77/52 76/51 42/31 41/30 15/13 14/13 25 25 27 26 15/19/24 15/19/24 mg/L %wt IbIbbI 6.2@250 /2 11 9.33 67 22 75/25 2.4 50500 26,43 3.12 988 6.2@250 /2 11 9.28 67 22 75/25 2.9 52000 27 3.77 1041 Reserve Volume bbI 358 REMARKS Arb TREATMENT Screened up shakers to 210mesh on back 2 panefs, Total Vol of Cuttings drilled = 568 Total Vol of Oil recovered = 635 Daily Vol of Cuttings drilled =10 Daily Vol of Oil recovered =19 Daily Downhole losses =10 Cummulative Downhole losses= 715 TIME DISTRIBUTION last 24 hrs Rig Up/Service Drilling 16.5 Tripping Non-Productive Ti", Condition Mud 7.5 Condition Hole Testing Cementing Wait on Cement Rig Repair M-I ENGR I PHONE Kenny Miller 0 Billy Hunter MUD VOL ACCTG Synlhetiç Added 'water Added Mud Received MudRetumed Dumped Shakers Evaporation Centrifugè Formation Left in Hole Other (bbl) 121 25 35 10 RIG PHONE 907-776-7137 0:00 0:00 I I .O@ .O@ II .O@ I .O@ I Depth/TVD: 10375 ft I 9244 ft Date: 10/26/2004 Spud Date: 9/17/2004 Mud Type : VersaDril ActIvity: Drilling CIRCULATION DATA Pump Make EisW;..msWH1000 TSM1000HP Pump liner x Stk 4.5x10 in 5,5x9 in Pump Capacity gaVstk 1.962 2.638 Pump stklmin 123@95% 98@95% Flow Rate 500 gaVmin Pump Pressure 3316 psi Bottoms Up 78.2 min 17293 stk Total Circulation 121.2 min 26788 stk PRODUCTS USED Last 24 hr Size Amount 50 LB BG 405 50 LB BG 20 25 LB BG 20 1 EA 2 1 GA TK 5082 55GADM 2 55GADM 1 80 LB BG 26 Products M-I BAR (+PLY liNED BAG) PECAN NUT PLUG MEDlUfJ MIX Ii MEDIUM ENGiNEERING SERVICE MAPCO 200 VERSACOAT HF VERSAWET CALCIUM CHLORIDE PWD II SOLIDS CONTROL EQUIPMENT Last 24 hr Type ModellSlze Hrs Used Centrifuge 24.0 Derrick Shaker 1 210/210/180 24.0 Derrick Shaker 2 21012101180 24.0 MUD PROPERTY SPECS Weight 10 VISCosity 7()-'90 Filtrate HTH P <8 Actual 10.0 84 6.2 REMARK!; Continued drilling ahead to 10283'. Circulated sands up the annular. Resume drilling ahead... SOLIDS ANALYSIS Salt Wt"Á> Salt Cone .Adjusted Solids SvntheticlWater Ratio ,.AveraA8 SG Solids Low Gravity % Low Gravity Wt High Gravity % High Gravity Wt WAREHOUSE PHONE 907-776-8680 26.43 27.67 8.98 75/25 2.9 7 63.85 2. 28.85 RHEOLOGY & HYDRAUlICS np/na 0.566/0.248 Kp/Ka 1.62319.258 BitPressureLossI% 418/12.6 Bit HHP/HSI 12211.6 Jet Velocity 216 "va Pipe 158.4 "va Collars 227.3 Cva Pipe 401 Cva Collars 430 ECo at Shoe 10.27 DAILY COST $20,972.88 CUMULATIVE COST $464.975.24 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · ;.-~;,--..._" Mi SVV~ç~~ . . .,:~,:,,~>;,-~ SYNTHETIC-BASED MUD REPORT No. 44 Operator: FOREST OIL CORP. Field/Area: West Foreland Report For: Mr. Fred Brent Description: Development Well Name: West Foreland # 2 Location : West MacArthur River U Contractor: Kuukpik Drilling Water Depth : 0 ft Report For: Mr. J. Otto I Mr.T.Knutson RiQ Name: # 5 DRILLING ASSEMBLY CASING (*TVD) 9795 It, 4.5-in DP 13.875-in @3OO31t(3001 TVD) 606 It, 4.5-in HWDP 93 It, 6.61-in DC 31 It, 6.75-in MWD 25 It, 7 -in MudM It. -in Nozzles 22x21132" Bit 9.875-in mx-s18 Sample From Flowline Temp DepthnVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/R 100 R6/R3 PV YP 1 Os/1 Om/30m Gel API Fluid Loss HTHP Fluid Loss Cake APTlHT Unc Ret Solids Correct Solids Synthetic Uncorr Water SyntheticlWater Ratio Alkal Mud (Psm) CI- Whole Mud Salt Lime Emul Stability OF ft Ib/gal s/qt of cP Ib/100ft2 Ib/100ft' ccI30min ccI30min 1/32" %Vol %Vol %Vol %Vol mg/L %Wt Ib/bbl MUD PROPERTIES Pit 23:30 PIT 10:00 145 145 10550/9355 10390~225 10.0@140 10.0@J140 82 84 150 150 78/52 77152 43/31 42/30 15/14 15/14 26 25 26 27 15/18124 15/19/24 6.4@250 2/ 10 7.91 68 22 76124 2.9 52000 27 3.77 980 6.4@250 2/ 11 9 67 22 75125 2.4 50100 26.27 3.12 964 Reserve Volume bbl 346 REMARKS A~b TREATMENT Total Vol of Cuttings drilled = 586 Total Vol of Oil recovered =705 Daily Vol of Cuttings drilled =18 Daily Vol of Oil recovered =70 Daily Downhole losses =55 Cummulative Downhole 10sses=819 MUD VOLUME (bbl) Hole I Active Pits 1089 350 Total Circulating Volume 1439 Depth Drilled Last 24hr 175 It Volume Drilled Last 24hr 17 bbl 0:00 0:00 DepthlTVD: 10550 ft I 9355 ft Date: 10/2712004 Spud Date: 911712004 Mud Type: VersaDril Activity : DrillinQ CIRCULATION DATA Pump Make EIìs WiIams WHlooo TSM 1000 HP Pump Liner x Stk 4.5x10 in 5.5x9 in Pump Capacity gallstk 1.962 2.638 Pump stklmin 124@95% 101@95% Flow Rate 510 gallmin Pump Pressure 3547 psi Bottoms Up 77.8 min 17502 slk Total Circulation 118.5 min 26664 slk PRODUCTS USED Last 24 hr Size Amount 50 LB BG 560 50 LB BG 64 1 GA TK 5250 55GADM 8 55GADM 4 55 GA DM 4 50 LB BG 35 50 LB BG 3 80LBBG 114 Products M-I BAR (4-PL Y LINED BAG PECAN NUT PLUG MEDIU~ MAPCO 200 VERSACOATHF VERSAWET "vERSATHIN HF LIME IMG-400 CALCIUM CHLORIDE PWD SOLIDS CONTROL EQUIPMENT Last 24 hr Type ModellSize Hrs Used Centrifuge 16.0 Derrick Shaker 1 210/210/180 24.0 Derrick Shaker 2 2101210/180 24.0 MUD PROPERTY SPECS Weight 10 Viscosity 70-90 Filtrate HTHP <8 Actual 10.0 82 6.4 1 .O@ 1 .O@ REMARKå Continued drilling ahead to 10283'. Circulated sands up the annular. Resume drilling ahead... /I /I .O@ 1 .O@ 1 TIME DISTRIBUTION Last 24 hrs MUD VOL ACCTG (bbl) SOLIDS ANALYSIS RHEOLOGY & HYDRAULICS Rig Up/Service Synthetic Added 125 Salt wt% 27 np/na 0.58510.227 Drilling 15.5 Water Added Salt Cone 28,5 Kp/Ka 1,445/10.320 Tripping Mud Received Adjusted Solids 7.91 Bit Pressure Loss/% 435112.3 Non-Productive Tin Mud Retumed SyntheticlWater Ratio 76/24 Bit HHP/HSI 129/1.7 Condition Mud Dumped Average SG Solids 3.2 Jet Velocity 220 Condition Hole Shakers 35 Low Gravity % 4.9 Va Pipe 161,6 Testing Evaporation Low Gravity WI. 45 Va Collars 231.8 Cementing Centrifuge 40 High Gravity % 3. Cva Pipe 403 Wait on Cement Formaüon 131 High Gravity WI. 43.55 Cva Collars 429 Rig Repair 7.5 Left in Hole ECD at Shoe 10.28 Other M-I ENGR I PHONE RIG PHONE WAREHOUSE PHONE DAILY COST CUMULATIVE COST Kenny Miller 0 Billy Hunter 907-776-7137 907-776-8680 $35.711.08 $500.686.32 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Mi BV\I~ç~~ SYNTHETIC-BASED MUD REPORT No. 44 Operator: FOREST OIL CORP. Field/Area West Foreland Report For: Mr. Fred Brent Description Development Well Name: West Foreland # 2 Location West MacArthur River U Contractor: Kuukpik Drilling Water Depth : 0 ft Report For: Mr. J. Otto I Mr.T.Knutson Ri~ Name: # 5 DRILLING ASSEMBLY CASING (*TVD) 9795 ft, 4.5-in DP 13.875-in @3003 ft (3001 TVD) 606 ft, 4.S-in HWDP 93 It, 6.61-in DC 31 It, 6.7S-in MWD 25 ft, 7 -in MudM ft. -in Nozzles 22x2 1/32" Bit 9.87S-in mx-s18 Sample From Flowline Temp DepthnvD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/R100 R6/R3 PV YP 10s/10m/30m Gel API Fluid Loss HTHP Fluid Loss Cake APT/HT Unc Ret Solids Correct Solids Synthetic Uncorr Water Synthetic/Water Ratio Alkal Mud (Psm) CI- Whole Mud Salt Lime Emul Stability OF ft Ib/gal s/qt of cP Ib/100ft2 Ib/100ft2 ccl30min ccl30min 1/32" %Vol %Vol %Vol %Vol mg/L %wt Ib/bbl MUD PROPERTIES Pit 23:30 PIT 10:00 145 145 10550/9355 1039O~225 10.0@140 10.0~140 82 84 150 150 7~52 77ffi2 4~31 4~ 15/14 15/14 26 25 26 27 15/18/24 15/19/24 6.4@250 21 10 7.91 68 22 76/24 2.9 52000 27 3.77 980 6.4~250 21 11 9 67 22 75/25 2.4 50100 26.27 3.12 964 Reserve Volume bbl 346 REMARKS AfÍb ·1 t<EATMENT Total Vol of Cuttings drilled = 586 Total Vol of Oil recovered =705 Daily Vol of Cuttings drilled =18 Daily Vol of Oil recovered =70 Daily Downhole losses =55 Cummulatìve Downhole losses=819 MUD VOLUME (bbl) Hole I Active Pits 1089 350 Total Circulating Volume 1439 Depth Drilled Last 24hr 175ft Volume Drilled Last 24hr 17 bbl 0:00 0:00 DepthlTVD : 10550 ft I 9355 ft Date : 10/2712004 Spud Date: 9/17/2004 Mud Type: VersaDril Activity : Drillin~ CIRCULATION DATA Pump Make EIs WiIams WH1000 TSM 1000 HP Pump Liner x Stk 4.5x10 in 5.5x9 in Pump Capacity gal/stk 1.962 2.638 Pump stklmin 124~95% 101@95% Flow Rate 510 gaVmin Pump Pressure 3547 psi Bottoms Up 77.8 min 17502 stk Total Circulation 118.5 min 26664 stk PRODUCTS USED Last 24 hr Size Amount 50 LB BG 560 50 LB BG 64 1 GA TK 5250 55 GA DM 8 55 GA DM 4 55GADM 4 50 LB BG 35 50 LB BG 3 80 LB BG 114 Products M-I BAR (4-PL Y LINED BAG PECAN NUT PLUG MEDIU~ MAPCO 200 VERSACOAT HF VERSA WET "vERSATHIN HF LIME IMG-400 CAlCIUM CHLORIDE PWD SOLIDS CONTROL EQUIPMENT Last 24 hr Type Model/Size Hrs Used Centrifuge 16.0 Derrick Shaker 1 210/210/180 24.0 Derrick Shaker 2 210/210/180 24.0 MUD PROPERTY SPECS Weight 10 Viscosity 70-90 Filtrate HTHP <8 Actual 10.0 82 6.4 I .O@ I .O@ REMARK~ Continued drilling ahead to 10283'. Circulated sands up the annular, Resume drilling ahead... /I /I .O~ I .O@ I TIME DISTRIBUTION Last 24 hrs MUD VOL ACCTG (bbl) SOLIDS ANALYSIS RHEOLOGY & HYDRAULICS Rig Up/Service Synthetic Added 125 Salt wt% 27 np/na 0.585/0.227 Drillin¡¡ 15.5 Water Added Salt Cone 28.5 Kp/Ka 1.445/10.320 Tripping Mud Received Adjusted Solids 7.91 Bit Pressure Loss/% 435/12.3 Non-Productive TilT Mud Retumed Synthetic/Water Ratio 76/24 Bit HHP/HSI 129/1.7 Condition Mud Dumped Average SG Solids 3.2 Jet Velocity 220 Condition Hole Shakers 35 Low Gravity % 4,9 Va Pipe 161.6 Testing Evaporation Low Gravity WI. 45 Va Collars 231.8 Cementing Centrifuge 40 High Gravity % 3. Cva Pipe 403 Wait on Cement Formation 131 High Gravity wt. 43.55 Cva Collars 429 Rig Repair 7,5 Left in Hole ECD at Shoe 10.28 Other M-I ENGR I PHONE RIG PHONE WAREHOUSE PHONE DAILY COST CUMULATIVE COST Kenny Miller 0 Billy Hunter 907-776-7137 907-776-8680 $35.711.08 $500,686.32 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Mí SW~ç~~ SYNTHETIC-BASED MUD REPORT No. 46 Operator: FOREST Oil CORP. Field/Area West Foreland Report For: Mr. Fred Brent Description Development Well Name: West Foreland # 2 location West MacArthur River U Contractor: Kuukpik Drilling Water Depth : 0 ft Report For: Mr. J. Otto I Mr.T.Knutson Rig Name: # 5 DRILLING ASSEMBLY CASING (*TVD) ft, 4.5-in DP 13.875-in @3003 ft (3001 TVD) 606 ft, 4.5-in HWDP 93 ft, 6.61-in DC 31 ft, 6.75-in MWD 25 ft, 7-in MudM ft, -in Nozzles 22x2 1/32" Bit 9.875-;n mx-s18 Sample From Flowline Temp DepthfTVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/R100 R6/R3 PV YP 1 Os/1 Om/30m Gel API Fluid Loss HTHP Fluid Loss Cake APTlHT Unc Ret Solids Correct Solids Synthetic Uncorr Water SyntheticlWater Ratio Alkal Mud (Psm) CI- Whole Mud Salt Lime Emul Stability cP Ib/100ft2 Ib/100ft' ccl30min ccl30min 1/32" %Vol %Vol %Vol %Vol MUD PROPERTIES Pit 23:30 Pit 13:10 130 130 10717/9457 10717/9457 10.1@115 10.1@118 86 86 150 150 74/50 74/50 38/28 39/28 14/13 14/13 24 24 26 26 16/21/23 16/20/23 OF ft Iblgal s/qt OF mglL %Wt Iblbbl 6.2@250 12 10.5 8.37 68.5 21 77/23 2.3 52200 28.01 2.99 962 6.0@250 /2 10.5 8.37 68.5 21 77/23 2.35 52500 28.12 3.06 979 Reserve Volume bbl 347 REMARKS Allb TREATMENT Daily vol. cuttings drilled=O Total vol. cuttings drilled=602 Daily vol. oil recovered=12 Total vol. oil recovered=734 Daily downhole losses=112 Cummulative downhole losses=1050 TIME DISTRIBUTION Last 24 hrs Rig UplService Drilling Tripping Non-Productive TilT Condition Mud Condition Hole Testing Cementing Wait on Cement Rig Repair M-I ENGR I PHONE Kenny Miller 0 Billy Hunter MUD VOL ACCTG Synthetic Added Water Added Mud Received Mud Returned Dumped Shakers Evaporation Centrifuge F onnation Left in Hole Other RIG PHONE 907-776-7137 (bbl) 54 16 112 MUD VOLUME (bbl) Hole I Active Pits 1181 290 Total Circulating Volume 290 Depth Drilled Last 24hr ft Volume Drilled Last 24hr bbl 0:00 I ,O@ /I .O@ I Rig-up Schlumberger. SOLIDS ANALYSIS Salt Wt% Salt Cone Adjusted Solids SyntheticlWater Ratio Average SG Solids Low Gravity % Low Gravity WI. High Gravity % High Gravity WI. WAREHOUSE PHONE 907-776-8680 0:00 I .O@ /I .O@ I DepthlTVD: 10717 ft I 9457 ft Date : 10/2912004 Spud Date: 9/17/2004 Mud Type : VersaDril Activity : RiQ up Wireline CIRCULATION DATA Pump Make EIs WiIams WHI000 TSM 1000 HP Pump Liner x Stk 4.5x10 in Pump Capacity gallstk 1.962 Pump stklmin 0@95% Flow Rate Pump Pressure Bottoms Up Total Circulation PRODUCTS USED Last 24 hr Size Amount 50 LB BG 170 50LBBG 5 25 LB BG 8 50LBBG 9 1EA 2 1 GA TK 2268 55GADM 1 55 GA DM 1 50 LB BG 10 50 LB BG 1 80 LB BG 18 5.5x9 in 2.638 0@95% gallmin psi Products M-I BAR (4-PL Y LINED BAG PECAN NUT PLUG MEDIU~ MIX II MEDIUM G-SEAL ENGINEERING SERVICE MAPCO 200 VERSACOA T HF VERSAWET LIME IMG-400 CAlCIUM CHLORIDE PWD SOLIDS CONTROL EQUIPMENT Last 24 hr Type ModellSize Hrs Used Centrifuge 3.0 Derrick Shaker 1 2101175/175 24.0 Derrick Shaker 2 210/175/175 24.0 MUD PROPERTY SPECS Weight 10 Viscosity 70-90 Filtrate HTHP <8 Actual 10.1 86 6.2 REMARKå 28.01 28.61 8.38 77/23 3.2 5.1 46.65 3.3 47.83 RHEOLOGY & HYDRAULICS np/na Kp/Ka Bit Pressure Loss/% Bit HHP/HSI Jet Velocity Va Pipe Va Collars Cva Pipe Cva Collars ECD at Shoe DAILY COST CUMULATIVE COST $11.635,03 $539.353.00 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Mi SWACQ~,~ "·,·",·,·:t;;:::::~~~ SYNTHETIC-BASED MUD REPORT No. 47 Operator: FOREST OIL CORP. Field/Area : West Foreland Report For: Mr. Fred Brent Description: Development Well Name: West Foreland # 2 Location: West MacArthur River U Contractor: Kuukpik Drilling Water Depth : 0 ft Report For: Mr. J. Otto I Mr.T.Knutson Ri~ Name: # 5 DRILLING ASSEMBLY CASING (*TVD) ft, 4.5-in DP 13.875-in @3003 ft (3001 ND) 606 ft, 4.5-in HWDP 93 ft, 6.61-in DC 31 ft, 6,75-in MWD 25 ft, 7 -in MudM ft, -in Nozzles 22x2 1/32" Bit 9.875-in mx-s18 Sample From Flowline Temp DepthfTVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/R 100 R6/R3 PV YP 1 Os/1 Om/30m Gel API Fluid Loss HTHP Fluid Loss ·Cake APT/HT Unc Ret Solids Correct Solids Synthetic Uncorr Water 'SyntheticlWater Ratio Alkal Mud (Psm) CI- Whole Mud Salt Lime Emul Stabílìty OF ft Ib/gal s/qt OF cP Ib/100ft2 Ib/100ft2 cc/30min cc/30min 1/32" %Vol %Vol %Vol %Vol mg/L %Wt Iblbbl MUD PROPERTIES pit 22:00 pit 14:00 nIa nIa 10717~57 10717/9457 10.2@88 10.2@88 110 110 150 150 75/50 75/50 39/28 39/28 15/14 15/14 25 25 25 25 16/21/25 16/21/25 6.0@250 /2 10.5 8.4 68 21.5 76/24 2.2 52000 27.46 2.86 965 6.0@250 /2 10.5 8.4 68 21.5 76/24 2.2 52000 27.46 2.86 965 Reserve Volume bbl 345 REMARKS ~b TREATMENT No mud treat to sysytem made 80 bbl pre-rnix. Daily vol. cuttings drilled=O Total vol. cuttings drilled=602 Daily vol. oil recovered=O Total vol. oil recovered=734 Daily downhole losses=4 Cummulative downhole losses=1054 MUD VOLUME (bbl) Hole I Active Pits 1181 367 Total Circulating Volume 367 Depth Drilled Last 24hr ft Volume Drilled Last 24hr bbl 0:00 0:00 DepthlTVD : 10717 ft I 9457 ft Date : 10/30/2004 Spud Date: 9/1712004 Mud Type : VersaDril Activity: Test Bop's CIRCULATION DATA Pump Make ElisWOiamsWHI000 TSM 1000 HP Pump Liner x Stk 4.5x10 in Pump Capacity gal/stk 1.962 Pump stk/min 0@95% Flow Rate Pump Pressure Bottoms Up Total Circulation PRODUCTS USED Last 24 hr Size Amount 50 LB BG 160 1EA 2 1 GA TK 2268 55GADM 1 55 GA DM 1 50 LB BG 7 50 LB BG 1 80 LB BG 10 5.5x9 in 2.638 0@95% gaVmin psi Products M-I BAR (4-PL Y LINED BAG ENGINEERING SERVICE MAPCO 200 VERSACOAT HF VERSAWET LIME IMG-400 CALCIUM CHLORIDE PWD SOLIDS CONTROL EQUIPMENT Last 24 hr Type Model/Size Hrs Used Centrifuge Derrick Shaker 1 210/175/175 24.0 Derrick Shaker 2 2101175/175 24.0 MUD PROPERTY SPECS Weight 10 Viscosity 70-90 Filtrate HTHP <8 Actual 10.2 110 6 / .O@ / .O@ REMARK! Completed rigging up Schlumberger wireline. Attempt to run MPT. No success past 8400'. Pull out of hole. Adjust length to get past ledge. No success. Pulled out of hole and rig down wireline. Make up test plug for BOP's. Tested BOP's. /I /I .O@ / .O@ / TIME DISTRIBUTION Last 24 hrs MUD VOL ACCTG (bbl) SOLIDS ANALYSIS RHEOLOGY & HYDRAULICS ~ig Up/Service Synthetic Added 54 SaltWt% 27.46 np/na Drilling Water Added 15 Salt Cone 28.5 Kp/Ka Tripping Mud Received Adjusted Solids 8.4 Bit Pressure Loss/% Non-Productive Tirr Mud Returned SyntheticlWater Ratio 76/24 Bit HHP/HSI Wireline Logs 15.5 Dumped Average SG Solids 3.3 Jet Velocity Condition Hole Shakers Low Gravity % 4.8 Va Pipe Testing 8.5 Evaporation Low Gravity WI. 43,65 Va Collars Cementing Centrifuge High Gravity % 3.6 Cva Pipe Wait on Cement Formation 4 High Gravity WI. 52.95 Cva Collars 'Rig Repair Left in Hole ECO at Shoe Other M-I ENGR / PHONE RIG PHONE WAREHOUSE PHONE OAIL Y COST CUMULATIVE COST Kenny Miller 0 Billy Hunter 907-776-7137 907-776-8680 $10.021.85 $549.374.85 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Mí SVV~C~~~_ ,,---:-~-:::.::-,,:::-::~,.......~ Operator: FOREST OIL CORP. Field/Area West Foreland Report For: Mr. Fred Brent Description Development Well Name: West Foreland # 2 Location West MacArthur River U Contractor: Kuukpik Drilling Water Depth 0 ft Report For: Mr.F.Pluid I Mr.T.Knutson Ri~ Name: # 5 DRILLING ASSEMBLY CASING (*1VD) 10269 ft, 4.5-in DP 13.875-in @3003 ft (3001 TVD) 606 ft, 4.5-in HWDP 93 ft, 6.61-in DC 31 ft, 6.75-in MWD 25 ft, 7 -in MudM ft, -in Nozzles 22x3 1/32" Bit 9.875-in MX-S18 Sample From Flowline Temp DepthfTVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/R100 R6/R3 PV YP 1 Os/1 Om/30m Gel API Fluid loss HTHP Fluid loss Cake APT/HT Unc Ret Solids Correct Solids Oil Uncorr Water OillWater Ratio Alkal Mud (porn) CI- Whole Mud Salt Lime Emul Stability cP Ib/100ft2 Ib/1 00ft> cc/30min ccI30min 1/32" %Vol %Vol %Vol %Vol MUD PROPERTIES flow 23:00 flow 14:00 136 136 11000/9628 10845/9539 10.2@136 10.1@136 86 90 150 150 78/54 87/57 46/34 46/35 16/14 16/15 24 30 30 27 18/24/26 18/23/26 OF ft Ib/gal sIqt OF mg/l %Wt Ib/bbl 6.0@250 /2 12 9.65 66 22 75/25 2.4 57500 29.03 3.12 959 6.2@250 /2 11.5 9.92 67.5 21 76/24 2.1 51500 27.73 2,73 923 Reserve Volume bbl 347 REMARKS AN ~ ., KEATMENT Run centrifuge. Pump LCM Sweeps, Daily vol. cuttings drilled=21 Total vol. cuttings drilled=623 Daily vol. oil recovered=20 Total vol. oil recovered=754 Daily downhole losses=88 Cummulative downhole losses=1149 TIME DISTRIBUTION Last 24 hrs Rig Up/Service Drilling 18 Tripping 2 Non-Productive TifT Reaming Condition Hole 4 Testing Cementing Wait on Cement Rig Repair M-I ENGR I PHONE Kenny Miller 0 Chad Rieger MUD VOL ACCTG Oil Added Water Added Mud Received Mud Returned Dumped Shakers Evaporation Centrifuge F onnation Left in Hole Other RIG PHONE 907-776-7137 MUD VOLUME (bbl) Hole I Active Pits 1131 382 Total Circulating Volume 1513 Depth Drilled last 24hr 307 ft Volume Drilled last 24hr 29 bbl 0:00 0:00 Oil-BASED MUD REPORT No. 49 DepthITVD : 11024 ft I 9642 ft Date: 11/1/2004 Spud Date: 9117/2004 Mud Type: VersaDril Activity : Drillin~ CIRCULATION DATA Pump Make EIs Wiliams WH1000 TSM 1000 HP Pump liner x Stk 4.5x10 in 5.5x9 in Pump Capacity gal/stk 1.962 2.638 Pump stklmin 118@95% 99@95% Flow Rate 493 gal/min Pump Pressure 3450 psi Bottoms Up 83.5 min 18112 stk Total Circulation 128,9 min 27971 stk PRODUCTS USED Last 24 hr Size Amount 50 LB BG 170 1 GA TK 2268 55GADM 1 55GADM 1 50 LB BG 22 50LBBG 1 80 LB BG 15 Products M-I BAR (4-PL Y LINED BAG MAPCO 200 VERSACOATHF VERSAWET LIME IMG-400 CALCIUM CHLORIDE PWD SOLIDS CONTROL EQUIPMENT Last 24 hr Type Model/Size Hrs Used Centrifuge 15.0 Derrick Shaker 1 210/210/210 22,0 Derrick Shaker 2 210/210/210 22.0 MUD PROPERTY SPECS Weight 10 Viscosity 70-90 Filtrate HTHP <8 Actual 10.2 86 6 / .O@ / .O@ REMARKå Resumed tripping in hole to 9300'. Wash/ream t010690'. Circulated bottom's up before resuming drilling ahead while pumping LCM Sweeps on connections. Drilling ahead at time of report. Note: Rig centrifuge down. Ran Swaco until operational. Screened up to 210 mesh screen on shakers in the late aftemoon. (bbl) 54 16 10 10 88 /I /I .O@ / .O@ / SOLIDS ANALYSIS SaltWt% Salt Cone Adjusted Solids OillWater Ratio Average SG Solids low Gravity % low Gravity WI. High Gravity % High Gravity WI. WAREHOUSE PHONE 907-776-8680 29.03 31,51 9.65 75/25 3 7.4 66.87 2.3 33.71 RHEOLOGY & HYOAAUlICS np/na 0.531/0.253 Kp/Ka 2.107/9.888 Bit Pressure loss/% 184/5.3 Bit HHP/HSI 53/ .7 Jet Velocity 142 Va Pipe 156.2 Va Collars 224.1 Cva Pipe 418 Cva Collars 449 ECD at Shoe 10.5 DAILY COST CUMULATIVE COST $9,251.40 $560.794.60 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Mí B\N~9~' OIL-BASED MUD REPORT No. 50 Operator: FOREST OIL CORP. Field/Area West Foreland Report For: Mr. Fred Brent Description Development Well Name: West Foreland # 2 Location West MacArthur River U Contractor: Kuukpik Drilling Water Depth : 0 ft Report For: MLF.Pluid I Mr.T.Knutson Rin Name: # 5 DRILLING ASSEMBLY CASING (*1VD) 10525 ft, 4.5-in DP 13.875-in @3OO3 ft (3001 TVD) 606 ft, 4,5-in HWDP 93 ft, 6.61-in DC 31 ft, 6.75-in MWD 25 ft, 7 -in MudM ft, -in Nozzles 22x3 1/32" Bit 9.875-in MX-818 Sample From Flowline Temp DepthfTVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/R 1 00 R6/R3 PV YP 1 Os/1 Om/30m Gel API Fluid Loss HTHP Fluid Loss Cake APT/HT Unc Ret Solids Correct Solids Oil Uncorr Water OillWater Ratio Alkal Mud (Pam) CI- Whole Mud Salt Lime Emul Stability cP Ib/100ft2 Ib/100ft2 ccI30min ccI30min 1/32" %Vol %Vol %Vol %Vol MUD PROPERTIES pit 23:30 flow 14:00 141 141 11280/9796 11190/9739 10.0@125 10.1@141 80 82 150 150 78/52 76/50 41/30 39/28 16/14 15/14 26 26 26 24 15/18/20 16/20/22 OF ft Ib/gal slqt of mg/L %Wt Ib/bbl 6.2@250 12 11 8.89 66 23 74/26 2.1 58000 28.3 2.73 912 6.2@250 12 11 8.89 68 21 76/24 2.5 54000 28.69 3.25 929 Reserve Volume bbl 347 REMARKS Atl"J TREATMENT Run centrifuge. Pump LCM SWeeps. Pre-mix, Daily vol. cuttings drilled=19 Total vol. cuttings drilled=642 Daily vol. oil recovered=39 Total vol. oil recovered=793 Daily downhole losses=150 Cummulative downhole losses=1199 TIME DISTRIBUTION Last 24 hIS Rig Up/Service Drilling 23.5 Tripping Non-Productive TifT Reaming Condition Hole 0.5 Testing Cementing Wait on Cement Rig Repair M-I ENGR / PHONE Kenny Miller 0 Chad Rieger MUD VOL ACCTG Oil Added Water Added Mud Received Mud Retumed Dumped Shakers Evaporation Centrifuge Fonnation Left in Hole Other RIG PHONE 907-776-7137 MUD VOLUME (bbl) Hole I Active Pits 1154 349 Total Circulating Volume 1503 Depth Drilled Last 24hr 256 ft Volume Drilled Last 24hr 24 bbl 0:00 0:00 1 1 .O@ .O@ /I /I DepthlTVD : 11280 ft I 9796 ft Date: 11/212004 Spud Date: 9117/2004 Mud Type: VersaDril Activity : Drillinn CIRCULATION DATA Pump Make ElisWilamsWHI000 TSM 1000 HP Pump Liner x Stk 4.5x10 in 5.5x9 in Pump Capacity gal/stk 1.962 2.638 Pump stklmin 112@95% 100@95% Flow Rate 465 gallmin Pump Pressure 3450 psi Bottoms Up 90.2 min 19124 stk Total Circulation 135.8 min 28780 stk PRODUCTS USED Last 24 hr Size Amount 50 LB BG 390 50 LB BG 8 50LBBG 4 1EA 4 1 GA TK 4536 55GADM 2 55GADM 2 50 LB BG 24 50 LB BG 2 80 LB BG 32 25LBBG 11 Products M-I BAR (4-PL Y LINED BAG PECAN NUT PLUG MEDIU~ G-SEAL ENGINEERING SERVICE MAPCO 200 VERSACOAT HF VERSAWET LIME IMG-400 CALCIUM CHLORIDE PWD MIX II FINE SOLIDS CONTROL EQUIPMENT Last 24 hr Type Model/Size HIS Used Centrifuge 24.0 Derrick Shaker 1 210/210/210 24.0 Derrick Shaker 2 210/210/210 24.0 MUD PROPERTY SPECS Weight 10 Viscosity 70-90 Filtrate HTHP <8 REMARKå Continue drilling ahead to 11418'. Circulate bottom's up. (bbl) 106 31 10 15 150 .O@ 1 .O@ 1 SOLIDS ANALYSIS Salt wt% Salt Conc Adjusted Solids OillWater Ratio Average SG Solids Low Gravity % Low Gravity WI. High Gravity % High Gravity WI. WAREHOUSE PHONE 907-776-8680 Actual 10.0 80 6.2 28.3 31.78 8.64 74/26 3 6.5 59.26 2.1 31.26 RHEOLOGY & HYDRAULICS np/na 0.585/0.217 Kp/Ka 1.445110.479 Bit Pressure Lossl% 161/4.7 Bit HHP/HSI 44/.6 Jet Velocity 134 Va Pipe 147.3 Va Collars 211.4 Cva Pipe 396 Cva Collars 421 ECD at Shoe 10.28 DAILY COST $22.189.52 CUMULATIVE COST $582,984.12 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Mi sw~g~~ Operator: FOREST Oil CORP. Field/Area West Foreland Report For: Mr. Fred Brent Description Development Well Name: West Foreland # 2 location West MacArthur River U Contractor: Kuukpik Drilling Water Depth : 0 ft Report For: Mr.F.Pluid I Mr.T.Knutson Rig Name: # 5 DRILLING ASSEMBLY CASING (*TVD) 2511 ft, 4.5-in DP 13.875-in @3OO3 ft (3001 TVD) 483 ft, 4,5-in HWDP 30 ft, 6.18-in Drill Jar 122 ft, 4.5-in HWDP 1 ft, 6.23-in XO Sub 6 ft, 6.9-in Stabilizer Nozzles 22x3 1/32" Bit 9.875-in MX-S18 Sample From Flowline Temp DepthfTVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/R100 R6/R3 PV YP 1 0511 Om/30m Gel API Fluid Loss HTHP Fluid Loss Cake APTlHT Unc Ret Solids Correct Solids Oil Uncorr Water OillWater Ratio Alkal Mud (pom) CI- Whole Mud Salt Lime Emul Stability cP Ib/100ft' Ib/100ft' ccl30min ccl30min 1/32" %Vol %Vol %Vol %Vol OF ft Iblgal s/qt of MUD PROPERTIES pit 23:00 pit 14:45 nIa nIa 11284/9799 11284~799 10.3@85 10.3@110 190 113 150 150 7W53 80ffi3 44~2 4~31 14/13 14/13 26 27 27 26 15/20/21 14/17120 mglL %Wt Iblbbl 6.4@250 12 12 10.01 66 22 75/25 1.95 50000 26.24 2.54 930 6.4@250 12 12 9.93 66 22 75/25 2.3 51500 26.81 2.99 980 Reserve Volume bbl 346 REMARKS AN') TREATMENT Run centrifuge. Pump LCM Sweeps. Pre-mix. Daily vol. cuttings drilled=O Total vol. cuttings drilled=648 Daily vol. oil recovered=O Total vol. oil recovered=793 Daily downhole losses=x Cummulative downhole losses=1199 TIME DISTRIBUTION Last 24 hrs Rig UplService Drilling 1 Tripping 17,5 Non-Productive TiIT Reaming Condition Hole 3 Testing Cementing Wait on Cement Rig Repair 2.5 M-I ENGR I PHONE Kenny Miller 0 Chad Rieger MUD VOL ACCTG Oil Added Water Added Mud Received Mud Returned Dumped Shakers Evaporation Centrifuge Formation Left in Hole Other (bbl) 54 16 20 25 64 RIG PHONE 907-776-7137 MUD VOLUME (bbl) Hole I Active Pits 1151 328 Total Circulating Volume 775 Depth Drilled Last 24hr 4ft Volume Drilled Last 24hr bbl 0:00 0:00 I .O@ I .O@ /I .O@ I .O@ I OIL-BASED MUD REPORT No. 51 DepthlTVD : 11284 ft I 9799 ft Date: 11/3/2004 Spud Date: 9117/2004 Mud Type : VersaDril Activity: Tripping in Hole CIRCULATION DATA Pump Make EIs WiIams WHI000 TSM 1000 HP Pump Liner x Stk 4.5x10 in Pump Capacity gallstk 1.962 Pump stk/min 112@95% Flow Rate Pump Pressure Bottoms Up Total Circulation PRODUCTS USED Last 24 hr Size Amount 50 LB BG 258 1 EA 2 1 GA TK 2268 55GADM 1 55 GA DM 1 50LBBG 8 50 LB BG 1 80 LB BG 8 5.5x9 in 2.638 100@95% gallmin psi Products M-I BAR (4-PL Y LINED BAG ENGINEERING SERVICE MAPCO 200 VERSACOAT HF VERSAWET LIME IMG-400 CALCIUM CHLORIDE PWD /I SOLIDS CONTROL EQUIPMENT Last 24 hr Type Model/Size Hrs Used Centrifuge 4,0 Derrick Shaker 1 210/210/210 4,0 Derrick Shaker 2 210/2101210 4.0 MUD PROPERTY SPECS Weight 10 Viscosity 70-90 Filtrate HTHP <8 Actual 10.3 190 6.4 REMARKå Continue drilling ahead to 11284', Circulated bottom's up before pulling out of hole 10 check bit due to low ROP. Make up new BHA. Trip in hole with same at time of report, SOLIDS ANALYSIS Salt WI% Salt Cone Adjusted Solids OillWater Ratio Average SG Solids Low Gravity % Low Gravity WI. High Gravity % High Gravity WI. WAREHOUSE PHONE 907-776-8680 26.24 27.4 10.01 75/25 3.1 7.2 65.38 2.8 41.41 RHEOLOGY & HYDRAULICS nplna 0.576/0.257 Kp/Ka 1.559/9,123 Bit Pressure Loss/% 11 Bit HHP/HSI 11 Jet Velocity Va Pipe Va Collars Cva Pipe Cva Collars ECD at Shoe 380 433 10.25 DAILY COST CUMULATIVE COST $10,815.79 $593.799.91 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Mí SWAC~ ''''''""c·-::,,::.'::....~ "'-,~'_."'..'-''''.~ OIL-BASED MUD REPORT No. 52 Operator: FOREST OIL CORP. Field/Area : West Foreland Report For: Mr. Joe Harris Description: Development Well Name: West Foreland # 2 Location: West MacArthur River U Contractor: Kuukpik Drilling Water Depth: 0 ft Report For: Mr.F.Pluid I Mr.T.Knutson Ri:I Name: # 5 DRILLING ASSEMBLY CASING (*TVD) 10601 ft, 4.5-in DP 13.875-in @3003 ft (3001 TVD) 483 ft, 4.5-in HWDP 30 ft. 6.18-in Drill Jar 122 ft, 4.5-in HWDP 1 ft, 6.23-in XO Sub 6 ft, 6.9-in Stabilizer Nozzles 22x3 1132" Bit 9.875-in MX-S18 Sample From Flowline Temp DepthíTVD Mud Weight Funnel Viscosity Rheology Temp R600íR300 R200/R100 R6/R3 PV YP 1 Osl1 Om/30m Gel API Fluid loss HTHP Fluid loss Cake APT/HT Unc Ret Solids Correct Solids Oil Uncorr Water OilIWater Ratio Alkal Mud (Pomí CI- Whole Mud Salt lime Emui Stabiiíty cP Ib/100fF Ib/100fF ccí30min cc/30min 1/32" %Vol %Vol %Vol %Vol MUD PROPERTIES pit 23:00 flow 14:00 130 123 11388/9861 11350/9838 10.1@125 10.2@123 82 96 150 150 7&53 7W53 4~2 43132 14/12 14/12 25 26 28 27 15/20/21 16/19/21 OF It Ib/gal s/qt of mg/l %Wt Ib/bbl 6.4@250 /2 12 9.89 66 22 75/25 1.6 52500 27.19 2.08 906 6.4@250 /2 12.5 10.51 65,5 22 75/25 1.8 50000 26.24 2.34 916 Reserve Volume bbl 345 REMARKS Att3 TREATMENT Run centrifuge. Pump LCM SWeeps. Pre-mix. Daily vol. cuttings drilled= 10 Total vol. cuttings drilled=658 Daily vol. oil recovered=20 Total vol. oil recovered=913 Daily downhole losses=99 Cummulative downhole I055es=1298 TIME DISTRIBUTION Last 24 hIS Rig Up/Service Drilling 8 Tripping 12 Non-Productive Tin Reaming 1 Condition Hole 3 Testing Cementing Wait on Cement Rig Repair M-I ENGR / PHONE Kenny Miller 0 Chad Rieger MUD VOL ACCTG Oil Added Water Added Mud Received Mud Returned Dumped Shakers Evaporation Centrifuge Formation left in Hole Other RIG PHONE 907-776-7137 MUD VOLUME (bbl) Hole I Active Pits 1163 336 Total Circulating Volume 1499 Depth Drilled last 24hr 104 ft Volume Drilled last 24hr 10 bbJ 0:00 0:00 Depth/TVD : 11388 ft I 9861 ft Date : 11/412004 Spud Date: 9/1712004 Mud Type: VersaDril Activity; Short Trip CIRCULATION DATA Pump Make EIs Wilams WHI000 TSM 1000 HP Pump liner x Stk 4.5x10 in 5.5x9 in Pump Capacity gal/stk 1.962 2.638 Pump stk/min 113@95% 100@95% Flow Rate 486 gaVmin Pump Pressure 3584 psi Bottoms Up 86.9 min 18520 stk Total Circulation 124.6 min 26543 stk PRODUCTS USED Last 24 hr Size Amount 50 LB BG 170 50 LB BG 25 50 LB BG 35 1EA 2 1 GA TK 2268 55GADM 1 55GADM 1 50 LB BG 31 50 LB BG 1 80 LB BG 7 25LBBG 3 /I Products M-t BAR (~L Y LINED BAG PECAN NUT PLUG MEDIU~ G-SEAl ENGINEERING SERVICE MAPCO 200 "vERSACOAT HF VERSAWET LIME IMG-400 CALCIUM CHLORIDE PWD MIX II FINE SOLIDS CONTROL EQUIPMENT Last 24 hr Type Model/Size Hrs Used Centrifuge 16.0 Derrick Shaker 1 210/210/210 20.0 Derrick Shaker 2 210/210/210 20.0 Actual 10.1 82 6.4 REMARKS Continued tripping in hole while breaking circulation at 9000. Wash/ream from 10717 to bottom. Resumed drilling ahead...TD @11388. Mud weight on flow line was cold. Density lowered as mud warmed. 10 15 99 / .O@ / .O@ (bbl) 54 15 /I .O@ I .O@ / SOLIDS ANALYSIS SaltWt% Salt Cone Adjusted Solids Oil/Water Ratio Average SG Solids low Gravity % low Gravity Wi High Gravity % High Gravity WI. WAREHOUSE PHONE 907-776-8680 MUD PROPERTY SPECS Weight 10 Viscosity 70-90 Filtrate HTHP <8 27.19 28.77 9.89 75/25 2.9 8.2 75.01 1.6 24.12 R"'EOLOGY & HYDRAULICS nplna 0.557/0.280 Kp/Ka 1.74818.113 Bit Pressure loss/% 177 /4.9 Bit HHP/HSI 50/.7 Jet Velocity 140 Va Pipe 154 Va Collars 223.1 Cva Pipe 403 Cva Collars 438 ECD at Shoe 10.37 DAilY COST $14,124.06 CUMULATIVE COST $607,923.97 CAS ÒÓt\ @ (lZ,1'"Í (~ ~p ~>~1!A r l/,^-r ~O~ ~;l1ql' ¿ð¡~~ tßl iLtr 2011'- + ¡(l3 ~ ;' 5/1M' f"(ll.?~t I · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · ,{".~",-"",.~,.".,""'~-,¡n_I<'.'.""';;.:--"'''''''';'~''''''..,':.¡;....~~ MI S,^,ACQ Operator: FOREST OIL CORP. Field/Area: West Foreland Report For: Mr. Joe Harris Description: Development Well Name: West Foreland # 2 Location: West MacArthur River U Contractor: Kuukpik Drilling Water Depth : 0 it Report For: Mr. J.OttoJ Mr. T.Knutson RiQ Name: # 5 DRILLING ASSEMBLY CASING (*1VD) 10489 ft, 4.5-in DP 13.875-in @3003ft(30011VD) 483 ft, 4.5-in HWDP 30 ft, 6.18-in Drill Jar 122 ft, 4.5-in HWDP 1 ft, 6.23-in XO Sub 6 ft, 6.9-in Stabilizer Nozzles 22x3 1132" Bit 9.875-in MX-S18 Sample From FlowLine Temp DepthnvD Mud Weiqht Funnel Viscosity RheOloqy Temp R600/R300 R200/R100 R6/R3 PV YP 10s/10m130m Gel API Fluid Loss HTHP Fluid Loss Cake APTIHT Unc Ret Solids Correct Solids Oil Uncorr Water OillWater Ratio Alkal Mud (Pom\ CI- Whole Mud Salt Lime 'Emul Stability MUD PROPERTIES pit 23:00 flow 13:10 125 124 11387~860 11387~860 10.1@125 10.2@124 99 125 150 150 80/55 75151 45/32 42/30 15113 13/12 25 24 30 27 16/22/24 13/16/18 OF It Iblgal slc¡t OF cP Ib/100ft' Ibl100ft' ccl30min ccl30min 1/32" O/OVol %Vol %Vol %Vol 6.4@25O 12 11.5 9.52 65.5 23 74/26 1.2 50000 25.38 1.56 929 6.4@25O 12 11 9.06 65 24 73IZT 1.2. 49500 24.4 1.56 919 mglL %Wt Iblbbl Reserve Volume bbl 345 lŒMARKS Arð Itu::ATMENT Run centrifuge. Pump Various Sweeps. Pre-mìx. DI!Iily vol. cuttings drilled: o Total vol. cuttings drilled=658 Daily vol. oR recovered=24 Total vol. oil recovered=937 Daily downhole losses=O Cummulative downhole 1osses=1298 TIME DISTRIBUTION Last 24 hIS Rig UplService DrillinQ Trippin9 9.5 Non-Productive TilT Reaming Condition Hole 14.5 TestinQ Cementing Wait on Cement Rig Repair MUD VOL ACCTG (bbIl Oil Added 54 Water Added 16 Mud Received Mud Returned Dumped Shakers 12 Evaporation Centrifuge 12 Formation Left in Hole Other i?,lG PH()f..:r: Kenny Miller 0 Chad Rieger 907-776-7137 MUD VOLUME (bbl) Hole I Active Pits 1153 358 Total Circulating Volume 1511 Depth Drilled Last 24hr ft Volume Drilled Last 24hr bbl 0:00 0:00 1 .O@ 1 .O@ /I .()@ 1 .O@ I I OIL-BASED MUD REPORT No. 53 I I 1 DepthJ I v"D : 11387 ft I 9860 it Date: 11/512004 Spud Date: 9/1712004 Mud Type: VersaDril Activity : Trippina CIRCULATION DATA Pump Make EJio_WH1000 TSM1000HP Pump Liner x Stk 4.5x10 in Pump Capacity gallstk 1.962 Pump stklmin 113@95% Flow Rate Pump Pressure Bottoms Up Total Circulation PRODUCTS UseD Last 24 hr Size Amount 50 LB BG 376 50 LB BG 8 50 LB BG 14 50LBBG 34 1 EA 2 1 GA TK 2268 55GADM 1 55GADM 1 50 LB BG 11~ 50 LB BG 2 80LBBG 7 5.5x9 in 2.638 100@95% gal/min psi /I Products M-I BAR (4-PL Y UNED BAG PECAN NUT PLUG FINE PECAN NUT PLUG MEDIU~ G.-SEAL E:NGlNEERlNG SERVICE MAPCO 200 "veRsAWET VERSATHlN HF LIME IMG-400 CAlCIUM CHLORIDE PWD SOUDS CONTROL EQUIPMENT Last 24 hr Type Model/Size Hrs Used Cen~ 23.0 Derrick Shaker 1 21012101210 24.0 Derrick Shaker 2 21012101210 24.0 MUD PROPERTY SPECS Weight 10 Viscosity 70-90 Filtrate HTHP <8 Actual 10.1 99 6.4 MMARKA Pump LCM sweep and CBU...shOrttrip....POOH to 10289'. Pump SWeep and CBU. POOH to 9336'. Pump Sweep and CBU. POOH to 8975'. Mix and pump 20bbl La-VIS Sweep followed by 10bbl mud. Chased Sweep with 20bbl of 11.7ppg Weighted SWeep. CBU...shOrt trip TIH to 11368. Pump LCM sweep CBU pump La-visIHi-llis sweep CBU spot LCM pill @ 8000'. SOLIDS ANAlYSIS Salt Wt"¡(, Salt Cone Adjusted Solids OiUWater Ratio Average SG Solids Low Gravity % Low Gravity WI. HiQh Gravity % High Gravity WI. 907-776-8680 25.38 27.4 9.52 74126 3 7.4 67.05 2.2 31.61 RHEOLOGY & HYDRAULICS np/na 0.541/0.257 KpIKa 2.01619.123 Bit Pressure Lossl% 11 Bit HHP/HSI 11 Jet Velocity Va Pipe Va Collars Cva Pipe 405 Cva Collars 437 ECO at Shoe 10.1 GUMUL/},.Tf\/Ë c::(;§r $15,692.44 $623.616.41 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Mi SWAC~......;~ ~" .- ~:-.::~:¿~~::;~"'~ Operator: FOREST OIL CORP. Field/Area: West Foreland Report For: Mr. Joe Harris Description: Development Well Name: West Foreland # 2 Location : West MacArthur River U Contractor: Kuukpik Drilling Water Depth : 0 ft Report For: Mr. J.Otto I Mr. T.Knutson Rig Name: # 5 DRILLING ASSEMBLY CASING (*TVD) ft, 4.5-ín DP 13.875-in @3003ft(3001 TVD) 483 ft, 4.5-in HWDP 30 ft, 6.18-in Drill Jar 122 ft, 4.5-in HWDP 1 ft, 6.23-in XO Sub 6 ft, 6.9-in Stabilizer Nozzles 22x3 1/32" Bit 9.875-in MX-S18 Sample From Flowline Temp DepthJTVD Mud Weight Funnel Viscosity Rheology Temp R6001R300 R2OO1R100 R6IR3 PV yp 10s110m/30m Gel API Fluid Loss HTHP Fluid Loss Cake APTIHT Unc Ret Solids Correct Solids Oil Uncorr Water OillWater Ratio Atkal Mud (Pom) CI- Whole Mud Salt Lime Emul Stability OF ft Iblgal slqt of cP Ibl10Dft2 Ibl10Dft2 ccl30min ccl30min 1/32" %Vol %Vol %Vol %Vol mgIL %wt Iblbb! MUD PROPERTIES pit 23:00 pit 13:00 nIa nIa 11387/9860 11387/9860 10.0@62 10.0@72 123 119 150 150 64/42 66/44 30/21 32122 14/11 15/12 22 22 20 22 11/12114 12113/15 6.2@250 /2 9 7.38 67 24 74/26 1.15 42500 21.7 1.5 868 6.2@250 /2 9 7.31 67 24 74/26 1.15 44000 22.29 1.5 898 Reserve Volume bbl 266 REMARKS AN"J TREA'fMENT No treatment last 24 hours. Daily vol. cuttings drilled= 0 Total vol. cuttings drilled=658 Daily vol. oil recovered=O Total vol. oil recovered=937 Daily downhole losses=18 Cummulative downhole 10sses=1316 MUD VOLUME (bbl) Hole I Active Pits 1284 268 Total Circulating Volume 268 Depth Drilled Last 24hr ft Volume Drilled Last 24hr 39 bbl 0:00 0:00 OIL-BASED MUD REPORT No. 54 DepthJTVD : 11387 ft I 9860 ft Date : 11/6/2004 Spud Date: 911712004 Mud Type: VersaDril Activity: Logging CIRCULATION DATA Pump Make EIio-..WH1000 TSM1000HP Pump Liner x Stk 4.5x10 in 5.5x9 in Pump Capacity gallstk 1.962 2.638 Pump stklmin 0@95% 0@95% Flow Rate gallmin Pump Pressure psi Bottoms Up Total Circulation PRODUCTS USED Last 24 hr Products Si:ze Amount ENGINEERING SERVICE 1 EA 2 /I SOLIDS CONTROL EQUIPMENT Last 24 hr Type ModellSi:ze Hrs Used Centrifuge 4.0 Derrick Shaker 1 210/210/210 Derrick Shaker 2 210/210/210 MUD PROPERTY SPECS Weight 10 Viscosity 70-90 Filtrate HTHP <8 Actual 10,0 123 6.2 / .O@ / .O@ REMARKS Continued tripping pipe out of hole. Lay down BHA before rigging up Schlumberger wireline... Ran pilottest with versathin. 2pþb gave PV=24,YP=13, Gels= 10s-5, 10m-12. /I .O@ / .O@ / TIME DISTRIBUTION Last 24 hrs MUD VOL ACCTG (bbl) SOLIDS ANALYSIS RHI:OLOGY & HYDRAULICS Rig UP/Service Oil Added Salt wt% 21.7 np/na Drilling "water Added SaItConc 23.29 KP/Ka Tripping 11 Mud Received Adjusted Solids 7.38 Bit Pressure Loss/% Non-Productive Ti Mud Returned OillWater Ratio 74/26 Bit HHPIHSI Wireline Logs 13 Dumped Average SG Solids 3.5 Jet Velocity Condition Hole Shakers 10 Low Gravity % 3.3 Va Pipe Testing Evaporation Low Gravity wt. 29.8 Va Collars Cementing Centrifuge 20 High Gravity % 4.1 Cva Pipe Wait on Cement Fonnation 18 High Gravity wt. 60.28 Cva Collars Rig Repair Left in Hole ECD at Shoe Other M-I ENGR I PHONE RIG PHONE WAREHOUSE PHONE DAILY COST CUMULATIVE COST Kenny Miller 0 Chad Rieger 907-776-7137 907-776-8680 $1.350.00 $624,966.41 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Mi SVV~CQ-~...- : -:~~;~~::".:::::'::.~ ,.~,,,-,,.-,-,~.,.,..,;¡._....,,,,. Operator: FOREST OIL CORP. Field/Area West Foreland Report For: Mr. Joe Harris Description Development Well Name: West Foreland # 2 Location West MacArthur River U Contractor: Kuukpik Drilling Water Depth 0 ft Report For: Mr. J.Otto I Mr. T.Knutson Ria Name: # 5 DRILLING ASSEMBLY CASING ("TVD) 8251 ft, 4.5-in DP 13.875-in @3OO3 ft (3001 TVD) 454 ft, 4.5-in HWDP 30 ft, 6.18-in Drill Jar 152 ft, 4.5-in HWDP 1 ft, 6.23-in XO Sub 6 ft, 6.9-in Stabilizer Nozzles 22x3 1132" Bit 9.875-in MX-S18 Sample From Flowline Temp DepthlTVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/R 1 00 R6/R3 PV YP 10s/10m/30m Gel API Fluid Loss HTHP Fluid Loss Cake APT/HT Unc Ret Solids Correct Solids Oil Uncorr Water OillWater Ratio Alkal Mud (Pom) CI- Whole Mud Salt Lime Emul Stability cP Ib/100ft2 Ib/100ft2 cc/30min cc/30min 1/32" %Vol %Vol %Vol %Vol OF ft Ib/gal s/qt of MUD PROPERTIES pit 21 :45 pit 15:00 nIa nIa 11387ffi860 11387ffi860 10.1@81 10.1@84 152 115 150 150 7&47 6~41 37~ 31n2 11/10 11/10 23 21 24 20 1m5l17 11/13/15 mg/L %Wt Ib/bbl 6.2@250 /2 11 11 67 22 75/25 2.8 50000 26.24 3.64 875 6.2@250 /2 10 8.15 68 22 76/24 2.3 47000 25.06 2.99 888 Reserve Volume bbl 266 REMARKS Ati) TREATMENT No treatment last 24 hours. Daily vol. cuttings drilled= 0 Total vol. cuttings drilled=658 Daily vol. oil recovered=O Total vol. oil recovered=937 Daily downhole losses=DH Cummulative downhole losses=1316+DH TIME DISTRIBUTION Last 24 hrs Rig Up/Service 2 Drilling Tripping 7 Non-Productive Tin Wireline Logs 10 Condition Hole Testing 5 Cementing Wait on Cement Rig Repair M-I ENGR I PHONE Kenny Miller 0 Chad Rieger MUD VOL ACCTG (bbl) Oil Added Water Added Mud Received Mud Returned Dumped Shakers Evaporation Centrifuge FOllTlation Left in Hole Other RIG PHONE 907-776-7137 MUD VOLUME (bbI) Hole I Active Pits 1218 337 Total Circulating Volume 1318 Depth Drilled Last 24hr ft Volume Drilled Last 24hr bbl 0:00 0:00 / .O@ / .O@ /I .Q@ /- .O@ / Oil-BASED MUD REPORT No. 55 DepthlTVD : 11387 ft I 9860 ft Date: 11m2004 Spud Date: 9/17/2004 Mud Type: VersaDril Activity : TrippinQ CIRCULATION DATA Pump Make EIs WiIams WHI000 TSM 1000 HP Pump Liner x Stk 4.5x10 in 5,5x9 in Pump Capacity gal/stk 1.962 2.638 Pump stklmin 0@95% 0@95% Flow Rate gaVmin Pump Pressure psi Bottoms Up Total Circulation PRODUCTS USED Last 24 hr Products Size Amount ENGINEERING SERVICE 1 EA 2 LIME 50 LB BG 8 CALCIUM CHLORIDE PWO 80 LB BG 16 /I SOLIDS CONTROL EQUIPMENT Last 24 hr Type Model/Size Hrs Used Centrifuge 0.5 Derrick Shaker 1 210/210/210 0.5 Derrick Shaker 2 210/210/210 0.5 MUD PROPERTY SPECS Weight 10 Viscosity 70-90 Filtrate HTHP <8 Actual 10.1 152 6.2 REMARKti Completed WireJine logs. Rigged down Schlumberger. Make up test plug and trip in hole with same. Tested BOP's. Make up hole opener and tripping in hole with same at time of report. NOTE: Rheology lower due to La-Vis Sweep "trapped" in surface pits. Will condition when eirculaing resumes. 21:45 Mud Check was done after 1st eirc. (100 bbls)while tripping in hole (Treated with lime and Calcium Chloride). SOLIDS ANALYSIS Salt Wt% Salt Cone Adjusted Solids OillWater Ratio Average SG Solids Low Gravity % Low Gravity Wt. High Gravity % High Gravity Wt. WAREHOUSE PHONE 907-776-8680 26.24 27.4 9,01 75/25 3.1 6.3 57.14 2.7 40.03 RHEOLOGY & HYDRAULICS np/na 0.575/0.272 Kp/Ka 1.39216.841 Bit Pressure Loss/% /1 Bit HHP/HSI /1 Jet Velocity Va Pipe Va Collars Cva Pipe 356 Cva Collars 383 ECD at Shoe 10.1 DAILY COST CUMULATIVE COST $2,218.16 $627,184,57 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · MíSW~~ Operator: FOREST OIL CORP. Field/Area: West Foreland Report For: Mr. Joe Harris Description : Development Well Name: West Foreland # 2 Location : West MacArthur River U Contractor: Kuukpik Drilling Water Depth : 0 ft Report For: Mr. J.Otto I Mr. T.Knutson Rig Name: # 5 DRILLING ASSEMBLY CASING ("TVD) 1 0265 ft, 4.5-in DP 13.875-in @3OO3ft (3001 TVD) 454 ft, 4.5-in HWDP 30 ft, 6.18-in Drill Jar 152 ft, 4.5-in HWDP 1 ft, 6.23-in XO Sub 6 ft, 6.9-in Stabilizer Nozzles 200 1/32" Bit 9.875-in MX-518 Sample From FlowLine Temp Depth/TVD 'Mud Weight Funnel VISCOSity Rheology Temp 'R6001R300 R2001R100 R61R3 PV YP 10s/10m/30m Gel API Fluid Loss HTHP Fluid Loss Cake APTIHT Unc Ret Solids Correct Solids Oil Uncorr Water ÒillWater Ratio Atkal Mud (Pom) CI- Whole Mud Salt Lime Emul Stability OF ft Iblgal slQt of cP Ibl100ft' 1b/100ft" ccl30min ccl30min 1/32" %Vol %Vol %Voi %Vol mg/L %wt Iblbbl MUD PROPERTIES pit 22:30 flow 7:40 118 122 11387/9860 11387/9860 10.2@118 10.1@122 115 99 150 150 81/55 80/54 45/33 44/32 15/13 14/13 26 26 29 28 15/19/22 14/17/20 6.4@250 /2 11 9.26 66 23 74/26 2.4 52500 26.32 3.12 931 6.4@250 /2 11 9.01 67 22 75/25 2.5 50000 26.24 3.25 921 MUD VOLUME (bbl) Hole I ActiVe Pits 1205 308 Total Circulating Volume 1476 Depth Drilled Last 24hr ft Volume Drilled Last 24hr bbl 0:00 0:00 OIL-BASED MUD REPORT No. 56 Depth/TVD : 11387 ft I 9860 ft Date : 11/812004 Spud Date: 9117/2004 Mud Type: VersaDril Activity: CirculatinQ Sweeps CIRCULATION DATA Pump Make EIs_...WHI000 TSMI000HP Pump LinerxStk 4.5x10 in 5,5x9 in Pump Capacity gaVstk 1.962 2.638 Pump stklmin 120@95% 105@95% Flow Rate 512 gaVmin Pump Pressure 2722 psi Bottoms Up 83.5 min 18789 stk Total Circulation 121.1 min 27241 stk PRODUCTS USED Last 24 hr Size Amount 50 LB BG 76 50LBBG 4 50LBBG 4 1EA 2 55 GA DM 2 50 LEI BG 96 50 LB BG 2 55GADM 4 50 LB BG 60 Products M-I BAR (4-PL Y LINED BAG PECAN NlIT PLUG FINE G-SEAL ENGINEERING SERVICE VERSATHIN HF LIME 1MG-400 VERSAMUL VERSATROL SOLIDS CONTROL EQUIPMENT Last 24 hr Type Model/Size Hrs Used Centrifuge 12.5 Derrick Shaker 1 210/210/210 12,5 Derrick Shaker 2 210/210/210 12.5 MUD PROPERTY SPECS Weight 10 Viscosity 70-90 Filtrate HTHP <8 Actual 10.2 115 6,4 / .O@ / .O@ Reserve Volume bbl 266 REMARKS Atl'J TREAI NlENT REMA~K~ M-I Bar for Weighted Sweep and slug. Lo-Vis w/ VersaThin. IMG-400 for Hi· Continued running in hole with Hole Opener to bottom while working thru tight spots Vis. Daily vol. cuttings drilled= 0 Total vol. cuttings drilled=658 Daily vol. @10716to 10900,..... Pumped LCM Sweep around before bipping to 9000'. Tripped oil recovered=16 Total vol. oil recovered =847 Daily downhole baek in hole to bottom. Mixed and pumped 20bbl Lo-Vis Pill followed with 10bbl OBM. losses=32 Cummulative downhole losses=1348 20bbl Weighted Hi-Vis Sweep @ 11.6 ppg, and chased same with 20 of Lo-Vis Sweep. CBU.....Tripped back to 10,990' and Pump Lo-Hi-Lo-vis sweep (same as above). CBU. /I /I TIME DISTRIBUTION Last 24 hrs MUD VOL ACCTG (bbl) SOLiDS ANALYSIS RHEOLOGY & HYDRAULICS Rig UP/Service Oil Added Salt wt% 26.32 np/na 0.558/0.266 Drilling Water Added Salt Cone 28.77 KplKa 1.80318.993 Tripping 8 Mud Received Adjusted Solids 8.9 Bit Pressure LossI% 199/7.3 Non-Productive Tirr MudRelumed OillWater Ratio 74/26 Bit HHP/HSI 59/,8 Reaming 3.5 Dumped Average SG Solids 3.2 Jet Velocity 148 Condition Hole 12.5 Shakers 15 Low Gravity % 5.5 Va Pipe 152.7 Testing Evaporation Low Gravity WI. 50.4 Va Collars 214.7 Cementing Cenlrifuge 20 High Gravity % 3.4 Cva Pipe 407 Wait on Cement Fonnation 32 High Gravity WI, 49.42 Cva Collars 437 Rig Repair Left in Hole ECD at Shoe 10.49 Other M-I ENGR I PHONE RIG PHONE WAREHOUSE PHONE DAILY COST CUMULATIVE COST Kenny Miller 0 Chad Rieger 907-776-7137 907-776-8680 $10.413.16 $637.597.73 .O@ / .O@ / · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H ·[]······_···-··__··Ru--~-..lf\.."-·Z·-_·····-...>o..[].__.'____.'-' N j~~f¡- Morning Report operator Forest oil well West Foreland #2 Location west Foreland Report For: Fred Brent Report No. : 1 Date: . 09/24/2004 Footage: Time: 00:00 Horizon Geologists: Lowell price Depth: i 3003 24 Hour Summary: Rig up logging unit: 9/23/2004. Latest Mud Report: ..~.......................~.........._-_..._-_......._.._...__...._................................... Latest Survey(s): DRILL RATE High: LOw: DITCH GAS m.. ............................ High: LOw: chrom comp: Trip Gas: Conn Gas: Average: Current: Average: Current: LITHOLOGY .m.............···.····........ Interval synopsis ...... ... ...m........................_. .................................. .................m........................................ HYDROCARBON SHOWS Interval i Gas Description ······........_.......··_..m...._m........····..·....·....mn_ Remarks: 13 3/8" casing @ 3003'. Rig up: $1250.00 (9/23/2004); Man hours charged: 12. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H·····,·····,······, .., .................... >'. " ""-""""--"""""--- N C R,slZ C operator Forest oil well West Foreland #2 Location West Foreland Report For: Fred Brent Report NO. : 2 Morning Report Date: 09/25/2004 Footage: Time: 00:00 Horizon Geologists: Lowell Price Depth: 3003 24 Hour Summary: Rig up logging unit & monitor well. Latest Mud Report: ...............................--.......-............-................. Latest survey(s): DRILL RATE High: LOW: DITCH GAS High: chrom Comp: Trip Gas: Conn Gas: LOw: Average: Current: Average: Current: LITHOLOGY ....................................................................... Interval synopsis Interval HYDROCARBON SHOWS Gas i Descri pti on .--.-....... .. ;...............--..--...--- Remarks: 13 3/8" casing @ 3003'. Daily Rate: $590.00; Man hours charged: 12. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H ·····..·~·,..·....·..········........··...-...;.i,.i.·."............,.......-.........-....... N IJ R "1;\ Z IJ ,t:~1~:l .r,;:. ¡\ Morning Report Date: 09/26/2004 Time: 00:00 Depth: 3003 24 Hour Summary: i Monitor well. operator Forest oi 1 well West Foreland #2 Location west Foreland Report For: Fred Brent Report No. : 3 Footage: Horizon Geologists: Lowell Price Latest Mud Report: ..........m.... .................................... Latest survey(s): DRILL RATE High: Low: Average: Current: DITCH GAS High: Low: Average: Current: LITHOLOGY ·.····....···..··.....··..·................H_m..mm....._........___ Interval synopsis ............................................ . ..m............................................ HYDROCARBON SHOWS Gas Interval Description ................................................ .......-................----: ..._n"·___·__m____._' chrom comp: Trip Gas: Conn Gas: ....m................................. ...m............................. on Remarks: 13 3/8" casing @ 3003'. Daily Rate: $590.00; Man hours charged: 12. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H ...........-..'.'.......-"'..'...'....""*.......~............'....,_........"'.,......_....,...-- N [J R ...'.... Z [J J~'~c,. ~ E Morning Report Date: 09/27/2004 Time: 00:00 Depth: 3003 24 Hour Summary: Monitor well. operator Forest oi 1 well west Foreland #2 Location west Foreland Report For: Fred Brent Report NO. : 4 Footage: Horizon Geologists: Lowell price Latest Mud Report: Latest survey(s): DRILL RATE High: Low: Average: ........................................ DITCH GAS High: LOW: Average: Current: ___........._................m_..._....·.·..·.. Current: LITHOLOGY Interval synopsis HYDROCARBON SHOWS Interval Gas Description ........................................ ..................................-....................... chrom comp: Trip Gas: Conn Gas: .....m...................................·m . Remarks: 13 3/8" casing @ 3003'. Daily Rate: $590.00; Man hours charged: 12. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H ,."'..,.....~.."'....,.......,...............;................"'~.m_...'"'.....~...., N eR<t'Ze -:4~~~ ~ :~f~ Morning Report Date: 09/28/2004 Time: 00:00 Depth: 3366 24 Hour summary: Monitor well. Latest Mud Report: Latest Survey(s): DRILL RATE High: Low: Average: Current: LITHOLOGY Interval operator Forest oi 1 well West Foreland #2 Location west Foreland Report For: Fred Brent Report No. : 5 Footage: Horizon GeóTogTsts: 363 Lowell Price DITCH GAS High: LOw: Average: Current: synopsis Interval HYDROCARBON SHOWS Gas I Descri pti on ~.._-_.._.-. Chrom Comp: Trip Gas: Conn Gas: ........................----....-............ Remarks: 13 3/8" casing @ 3003'. Daily Rate: $590.00; Man hours charged: 12. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · HrfR!í,zeN ¡ ~-fi~"~ Morning Report Date: Time: 09/29/2004 00:00 Footage: Horizon Geologists: 865 Lowell Price Depth: 4231 24 Hour Summary: Monitor well. Latest Mud Report: .m...m.m.m....m.._..~......_............................~..........._. Latest survey(s): DRILL RATE DITCH GAS High: LOw: High: Low: Average: Average: Current: .................----...--...-..--- Current: LITHOLOGY Interval synopsis .................................. HYDROCARBON SHOWS Gas ! Descri pti on Interval Operator Forest oi 1 well West Foreland #2 Location west Foreland Report For: Fred Brent Report No. : 6 ..mmmm...._.H...H..H....... Chrom comp: Trip Gas: Conn Gas: . ..... ................. Remarks: 13 3/8" casing @ 300"3'. Daily Rate: $590.00; Man hours charged: 12. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H ................... ..."...".._................;....'."...................................... N C Rß'~Z C operator Forest oil well west Foreland #2 Location west Foreland Report For: Fred Brent Report NO. : 7 ·~~€4 ~. Morning Report Date: 09/30/2004 Time: 06:00 Depth: 5000 24 Hour Summary: 769 Lowell price Footage: Horizon Geologists: i Logged interval: 4450' to 5000' (550') Latest Mud Report: Latest survey(s): DRILL RATE DITCH GAS High: 4914 9 @ 4459 67 134@ 5000 Chrom comp: C-l Trip Gas: Conn Gas: 95u @ 4943' High: 181 @ 4779 12 @ 4963 62 33 @ 5000 LOw: Average: Current: LOw: Average: Current: LITHOLOGY --~....._.__...._---- Interval synopsis Spot samples as indicated on log (sand, sandstone, claystone, and coal) 4450' to 5038' HYDROCARBON SHOWS .m................................ Interval I Descri pti on Gas .......................................... ...............--.-......--............................ None ____m......__._..; Remarks: 13 3/8" casing @ 3003'; High Gas: 4481'=150u (ss); 4528'=191u (ss); 4662'=175u (coal); 4834'=142u (coal); 4852'=121u (coal); 4914'=375u (coal); 4998'=140u (coal); 5032'=93u (coal/drilling break).Daily Rate: $590.00; Man Hours: 18. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H D~R~~,Z~[]N ~ ~ Morning Report operator Forest oi 1 well West Foreland #2 Location west Foreland Report For: Fred Brent Report NO. : 8 Date: 10/01/2004 Time: 03:00 Depth: 5218 24 Hour Summary: 218' Lowell price Footage: Horizon Geologists: Latest Mud Report: Latest survey(s): DRILL RATE POH for additional stabilizer; RIH; directionally drilled 5000' to 5218' MW 9.6 vis 95 PV 26 YP 24 Gels 16/18/20 Sol 6.3 oil 72 cl- 42500 .__.m..........._................ DITCH GAS High: 104 @ 5100 o @ 5195 o 46 @ 5194 Chrom comp: C-1 High: 138 @ 5090 4 @ 5176 60 33 @ 5218 Low: Average: Current: ;. ....__.....m....._.........~ Trip Gas: ! 48u @ 5000' conn-Gäs-:----T None LOw: Average: Current: LITHOLOGY Interval synopsis Spot sample as indicated on log (coal, claystone, sandstone, . sand) 5000'-5194' ..........-...........-...-........................... .............................................H. .........................-..--.--....... HYDROCARBON SHOWS Interval Gas Description None ........._m.._.......__ Remarks: 13 3/8" casing @ 3003'; High Gas: 5100'=104u; current background gas 48u; Daily Rate: $590.00; Man Hours: 20. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H ··[]····~·······,·········R···········,···..,_·.-.~.·.--Z·_~·_~[]_...._~.._.. N ./..;c:le;.--,\," operator Forest Oi 1 well west Foreland #2 Location west Foreland Report For: Fred Brent Report NO. : 9 Morning Report Date: 10/02/2004 Time: 03:00 Depth: 5871' 24 Hour summary: 653' Neil peterson (6PM-6AM) Lowell Price (6AM-6PM) Footage: Horizon Geologists: Dir. Drill fr/5218' t/5871'; Latest Mud Report: Latest survey(s): DRILL RATE MW 9.5 vis 7.4 PV 22 YP 23 Gels 15/17/18 SOL 7.4 oil 77 SAL 41000 ppm cl- DITCH GAS Hi gh : ! 461 u LOw: . ch rom Comp: ! Trip Gas: '·····connGás··:···m ] c-l I None .......;.._m................_ ! None High: LOw: 260'/hr 15'/hr ! 9 u mmmmmmm_-lT20u 1 t/5720' ; ! 300u from 15720'- ! 224 u ...................................-...... Average: 80'/hr Average: Current: 60'/hr LITHOLOGY , synopsi s . Spot sample as indicated on log. (coal, claystone, sandstone, saT1º. ) Current: Interval 5218'-xxxx' Interval HYDROCARBON SHOWS Gas Description ...H__.._..._.....H.........··__...~_·....~..._....__..._ ...................................................-. Remarks: 13.375" csg @3003'; High gas @5741' = 461 u; curro backgrnd gas Daily rate: $1300 + $15/man/day oil-based mud charge = $1330. Man Hours: 24 200 u. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · ~ H ......-.....'.-....'.'--........-'....-......,..................'......',... .....------.....----....---------. N [J R ;At" Z [J ,0(>. \'\ J~t~.\;- operator Forest oi 1 well West Foreland #2 Location West Foreland Report For: Fred Brent Report NO. : 10 ~ii'~ Morning Report Date: 10/03/2004 Time: 03:00 Depth: 6061' 24 Hour Summary: 190' Neil Peterson (6PM-6AM) Lowell Price (6AM-6PM) Footage: Horizon Geologists: Latest Mud Report: Latest survey(s): DRILL RATE Drill fr/5871' t/5995'; wipe Hole; Repair Top-Drive; RIH and drill t/6061' MW 9.8 vis 124 PV 35 YP 35 Gels 20/24/25 sol 7.5 oil 67 SAL 40000 ppm cl- DITCH GAS High: 272u Chrom comp: I c-1 @5906' Low: 3u Trip Gas: 316u @5995' Average: 5u Conn Gas: None Current: 5u High: 130' /hr 4'/hr 40'/hr 37'/hr LITHOLOGY Low: Average: Current: ---.-....-........---...... Interval synopsis Spot sample as i ndi cated on 1 o-g-rëoáT;-cTáysfone~'--sándstone ,-- sand) 5871'- .m.............m..mm....N.~__ HYDROCARBON SHOWS Interval Gas Description ..............................--........ Remarks: 13 3/8"csg @ 3003'; High gas: 272u @ 5906'; current background = 5u Daily rate: $1300/day + $15/man/day (oil-based mud charge) = $1330/day. Man Hours = 24. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H '~"""'-"""""''''''''''.''.'''''.'''''..'.'...........................................-......-........ N [J R .,Ì;' Z [J 1''''' ;,., };f~,. operator Forest 0; 1 well West Foreland #2 Location West Foreland Report For: Fred Brent Report No. : 11 ~, Morning Report Date: 10/04/2004 Time: 03:00 Depth: 6183' 24 Hour summary: 109' Neil peterson (6PM-6AM) Lowell price (6AM-6PM) Footage: Horizon Geologists: Latest Mud Report: Latest survey(s): DRILL RATE Drill fr/6078' t/6187'; circulate; Repair generator & pump #2 POOH for bit trip; MW 9.7 vis96 PV 21 YP 23 Gels 14/16/17 sol 7.57 oil 68 SA.h_3_ªº",00 _EP..'!1 C1- DITCH GAS High: Low: ................................. ! Ch rom Comp: I Tri p Gas: ""conn Gas: c-1 High: 181'/hr 6'/hr 40'/hr O'/hr LITHOLOGY 10u Ou 28u 1u LOW: Average: Current: Average: Current: Interval synopsis Spot samples as indicated on log. (coal, c1aystone,-sandstone, sand). 6061'- Interval HYDROCARBON SHOWS Gas Description Remarks: High Gas: 28u; Current Background gas: Ou Daily Rate: $1300 + $15/man/day (oil-based mud charge) $1330/day · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H···'··,·,····~··········..······.·....·......:..(."..m....,·····..··,....·........·..··N [J R"'t..··\ Z [J ~;f>.' '. J).',J, ..~_':~. ":;.J; operator Forest oi 1 well west Foreland #2 Location west Foreland Report For: Fred Brent Report No. : 12 ~, Morning Report Date: 10/05/2004 Time: 03:00 -.-......................--.- Depth: 6183' 24 Hour Summary: 0' Neil Peterson (6PM-6AM) Lowell price (6AM-6PM) Footage: Horizon Geologists: Latest Mud Report: Latest survey(s): DRILL RATE Svc rig; RIH t/shoe; circ and condition mud; Hold safety meeting; wait on parts for generator. MW 9.8 vis 141 PV 22 YP 22 Gels 14/16/17 Sol 6.78 Oil 68 SAL 38000 ppm c1- DITCH GAS High: Low: High: LOw: Average: Current: O'/hr O'/hr O'/hr O'/hr LITHOLOGY Chrom comp: Trip Gas: Conn Gas: Average: Ou Ou Ou Ou Ou .._._~__...._...."..._.m.___..m_ ............-----..... Current: Interval Synopsis HYDROCARBON SHOWS Interval Gas Description m..........................._............... Remarks: Daily rate: $1300 + ~15/man/day (oil based mud charge) = $1330/day Man Hours: 24 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H _~~o~_o,_~~~__ ~.·..·.·.:.·...·.i...'.·....·.~.-.''''''.'-'-'''''-'''''''-.''''''-'' N C RßtJ,Z C operator Forest oi 1 well West Foreland #2 Location west Foreland Report For: Fred Brent Report NO. : 13 Morning Report Date: Time: 10/06/2004 03:00 6183' summary: 0' Neil Peterson (6PM-6AM) Lowell Price (6AM-6PM) Footage: Horizon Geologists: Depth: 24 Hour ci rc Replaced injectors on HP generator; Stage in t/5075'; and condition mud; POOH t/shoe for generator repairs. MW 9.8 vis 113 PV 20 YP 20 Gels 12/14/15 sol 7.67 oil 69 SAL 410Q.~L!"g/1 Cl-:________.._______________.__________ Latest Mud Report: Latest survey(s): DRILL RATE DITCH GAS High: 39u chrom comp: C-1 LOW: OU Trip Gas: Ou Average: Ou conn Gas: Current: Ou High: LOw: O'/hr O'/hr O'/hr O'/hr LITHOLOGY Average: Current: Interval synopsis .__...n........._............._.HH...HH HYDROCARBON SHOWS Interval Description Gas ... ....m..m....m.~.__n"~.._._......·.···._m... Remarks: Max Gas: 39u (During circ @5020'-5075'). Background Gas=Ou. Daily rate: $1300 + $15/man/day (oil based mud charge) = $1330/day Man Hours: 24 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H ~C'~""---~-----R-----I-Z-'-'-'---------C"~----"--" N -/~ I.,~", operator Forest oil well West Foreland #2 Location West Foreland Report For: Fred Brent Report NO. : 14 ~ Ii Morning Report Date: Time: 10/07/2004 03:00 6183' Summary: Footage: Horizon Geologists: 0' Neil Peterson (6PM-6AM) Lowell price (6AM-6PM) Depth: 24 Hour Wait on HP supply parts; Service Rig. Latest Mud Report: Latest Survey(s): DRILL RATE MW 9.7 vis 147 PV 20 YP 20 Gels 13/14/16 Sol 9.0 Oil 69 SAL 40500 mg/l cl- High: LOw: O'/hr O'/hr O'/hr O'/hr LITHOLOGY DITCH GAS High: Ou chrom comp: LOw: Ou Trip Gas: Ou Average: Ou Conn Gas: Current: Ou Average: ····..._......n.".....~........·...·..··""_·."·"_ Current: Interval Synopsis HYDROCARBON SHOWS ..................................- .........H._..._.......··....·......._.............· Interval ¡Description i Gas ..........................................-... Remarks: Daily rate: $1300 + ~15/man/day (oil based mud charge) $1330/day Man Hours: 24 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H ..--------.---.-......-......'...;....;.~..........'.-'-,.."..,._......._-_......-...."," N [J Rß~Z [J Operator Well Forest oi 1 west Foreland #2 west Foreland Joe Harris Location ~. Report For: Morning Report Report NO.: 15 Date: 10/08/2004 Time: 03:00 Depth: 6183' 24 Hour Summary: Footage: 0 ' Horizon Geologists: ¡ Neil peterson (6PM-6AM) ¡ Lowell pri ce (6AM-6PM) Wait on HP supply parts; Install and repair; service Rig. Latest Mud Report: Latest survey(s): DRILL RATE MW 9.7 vis 145 PV 21 YP 24 Gels 12/14/16 sol 9.0 oil 69 SAL 40000 mg/l._s_l::______ High: O'/hr LOW: O'/hr Average: O'/hr Current: O'/hr DITCH GAS High: Ou Chrom comp: LOW: OU Trip Gas: Ou Average: Ou Conn Gas: Current: Ou Interval LITHOLOGY I synopsi s '--'''''---.,.--'--- HYDROCARBON SHOWS ········..····_...........H................... Interval Gas Description .........................----.. Remarks: Daily rate: $1300 + ~15/man/day (oil based mud charge) = $1330/day Man Hours: 24 ·········_................m..·······..m.. ................ . .............. ..._...._..._..__................m.... · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H ...,."..''".''..'''....~..,......,..............~:.¡:1~.·...'·..·..·,..·..·,........··..··,......,......- N [J R '"1,, ~1 Z [J },¡:;"' :;..,1 operator well Forest oi 1 West Foreland #2 west Foreland Joe Harris Location % Report For: Morning Report Report No.: 16 Date: 10/09/2004 Time: 03:00 Depth: 6183' 24 Hour Summary: 0' Neil Peterson (6PM-6AM) Lowell price (6AM-6PM) Footage: Horizon Geologists: Latest Mud Report: Latest survey(s): DRILL RATE Repair HP; circ and cond mud; stage in hole and circ every 1000' t/bottom; pump/HP probs; PU t/shoe; Service Rig. MW 9.8 vis 104 PV 21 YP 24 Gels 13/14/16 Sol 9.0 oil 69 SAL 39000 mg/l Cl- High: O'/hr O'/hr O'/hr 10' /hr LITHOLOGY DITCH GAS High: Ou chrom comp: C-1 LOw: Ou Trip Gas: 147u @6183 ' Average: Ou Conn Gas: Current: Ou LOW: Average: Current: Interval synopsis HYDROCARBON SHOWS Interval Gas Description Remarks: Trip Gas @6183': ; Max Gas after c.o.: 68u; Background Gas = 12u. Daily rate: $1300 + $15/man/day (oil based mud charge) = $1330/day Man Hours: 24 .........................._......,...._.._................ . .........._........................_......._..........__..._.._............._..m·_...._m...._......m...... · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H ....--.......-.. -1.'-.·-·'...-.·..--·····.······'·-'·'·- N [] R;t, Z [] operator Forest oil well west Foreland #2 Location west Foreland Report For: Joe Harris Report No. : 17 tE~ .~ :N ~. Morning Report Date: 10/10/2004 Time: 03:00 Depth: 6320' 24 Hour summary: Footage: : 137' Horizon Geologists: i Neil Peterson (6PM-6AM) I Lowell Price (6AM-6PM) RIH and circ bottoms up; Drill fr/6183, t/6320'; Latest Mud Report: Latest survey(s): DRILL RATE MW 9.7 vis 111 PV 20 YP 23 Gels 13/15/19 sol 10.0 oil 68 SAL 41000 mg/l cl- DITCH GAS High: 61u LOW: 6u Average: 30u Current: 46u i chrom Comp: C-1 _Jm~~~.~..~~:.~_. 147u @6183' ¡ Conn Gas: High: Low: 210'/hr 10'/hr 25'/hr 22' /hr LITHOLOGY Average: Current: Interval Synopsis SANDSTONE: It-med gry; well srtd; rnd-well rndd; grain sprtd. SAND: It-med gry; mod-well srtd; rnd-sbrnd; unconsl. CLAYSTONE: med gry and dusky brn-olive brn; mod firm-firm; earthy; waxy when scored; occ grdg w/siltstn. COAL: blk; firm-vry firm; subvit-vit luster; bituminous- lignitic HYDROCARBON SHOWS 3183'- Interval Gas Description Remarks: Trip Gas @6183': 147u; Max Gas: 61u; Background Gas = 30u. Daily rate: $1300 + $15/man/day (oil based mud charge) = $1330/day Man Hours: 24 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H .."..."..........,..........................'..'\.f.¡,.,:'...."..··_.........."··..·_···_·····... N [] R .'~'f~\ Z [] t··<.'r operator Forest oil well west Foreland #2 Location west Foreland Report For: Joe Harris Report No. : 18 Morning Report Date: 10/11/2004 Time: 03:00 Depth: 6766' 24 Hour Summary: Footage: I 446' Hori zon Geo 1 ogi sts: i Nei 1 Peterson (6PM-6AM) ! Lowell Price (6AM-6PM) Latest Mud Report: Latest survey(s): DRILL RATE Drill fr/6320' t/6696'; c.o.; wipe hole t/6000'MD; Drill t/6766' , MW 9.7 vis 68 PV 19 YP 20 Gels 10/13/25 sol 10.0 oil 69 SAL _4º~ºº....r.!1g/L_çI= see Mudlog High: LOw: 385'/hr 4'/hr 30'/hr O'/hr LITHOLOGY DITCH GAS High: 108u chrom Comp: C-1 Low: 9u wiper Gas: 168u @ 6696' Average: 35u Conn Gas: Current: 44u Average: Current: Interval synopsis SANDSTONE: It-med gry; well srtd; rnd-well rndd; grain sprtd. SAND: It-med gry; mod-well srtd; rnd-sbrnd; unconsl. CLAYSTONE: med gry and dusky brn-olive brn; mod firm-firm; earthy; waxy when scored; occ grdg w/siltstn. COAL: blk; firm-vry firm; subvit-vit luster; bituminous- lignitic HYDROCARBON SHOWS 6320'- Interval Gas ! Descri pti on Remarks: wiper Gas @6696': 168u; Max Gas: 108u; Background Gas = 25-30u Daily rate: $1300 + $15/man/day (oil based mud charge) = $1330/day Man Hours: 24 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H ·[]·····.-··"..··..R·····}i;\...·Z·-..·..·'..·..·....·[]..-..'--·....···..N ¡,it -c" I.i~' operator Forest oil well west Foreland #2 Location west Foreland Report For: Joe Harris Report NO. : 19 Morning Report Date: 10/12/2004 Time: 03:00 Depth: 7089' 24 Hour summary: 393' Neil peterson (6PM-6AM) Lowell price (6AM-6PM) Footage: Horizon Geologists: Drill fr/6696' t/7089'. Latest Mud Report: Latest Survey(s): DRILL RATE MW 9.7 vis 77 PV 21 YP 23 Gels 12/14/16 sol 8.35 oil 68 ~~L 50100 mg/l Cl- See Mudlog DITCH GAS High: 385'/hr LOw: 8'/hr ..................-..--..-.-....... Average: 30'/hr ..............................................................···········...·....m...·...._ ................................._. Current: O'/hr LITHOLOGY High: 258u Chrom Comp: C-1 Low: 19u wiper Gas: Average: 40u Conn Gas: Current: 44u Interval Synopsis SANDSTONE: It-med gry; well srtd; rnã~well rndd; grain sprtd. SAND: It-med gry; mod-well srtd; rnd-sbrnd; unconsl. CLAYSTONE: med gry ana-duSKY brn-olive brn; mod firm-firm; earthy; waxy when scored; occ grdg w/siltstn. COAL:..-blk;···..·"fìrm=vry'"'"TìrïTi·;'"..subvi t-vi t 1 usfè¡:;'; bi tumi nous- lignitic HYDROCARBON SHOWS 6320'- Interval Gas Description Remarks: Max Gas: 258u; Background Gas = 40-50u Daily rate: $1300 + $15/man/day (oil based mud charge) = $1330/day Man Hours: 24 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H·-- -- ~_d_ -- -~_.._--- -------N [J R:;~cZ [J ~ ~, Morning Report Operator Forest Oi 1 well West Foreland #2 Location west Foreland Report For: Joe Harri s Report No. : 20 Date: 10/13/2004 Time: 03:00 Depth: 7364' 24 Hour Summary: Footage: Horizon Geologists: 275' Neil peterson (6PM-6AM) Lowell Price (6AM-6PM) I Drill fr/7089' t/7364'. Latest Mud Report: Latest survey(s): DRILL RATE MW 9.7 vis 78 PV 21 YP 24 Gels 13/16/19 Sol 9.0 oil 69 SAL 50100 mg/l Cl- See Mudlog DITCH GAS High: High: 198u Chrom comp: C-1 @7294' LOW: 17u wiper Gas: 82u @7117' Average: 35-40u conn Gas: Current: 77u LOw: 429'/hr 8'/hr 25' /hr 23'/hr LITHOLOGY Average: ................................................. Current: ..........................................................-........ Interval Synopsis nSANDSTONE: It-med gry; well srtd; rnd-well rndd; grairi--sp,::;:¡:cr:- SAND: It-med gry; mod-well srtd; rnd-sbrnd; unconsl. mmm····__··CLAYSTONE: med gry and dusky brn-olive brn; mod firm=fìFm;-_·mm earthy; waxy when scored; occ grdg w/siltstn. .......................................--- 6320'- COAL: blk; firm-vry firm; subvit-vit luster; bituminous- lignitic HYDROCARBON SHOWS Interval Gas Description .........._m........._......._............. Remarks: Max Gas: 198u @ 7294'; Background Gas = 30u Daily rate: $1300 + $15/man/day (oil based mud charge) Man Hours: 24 $1330/day · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · HCRþ{~Z-cN ~š1 Morning Report operator Forest oil well West Foreland #2 Location west Foreland Report For: Joe Harri s Report NO. : 21 Date: 10/14/2004 Time: 03:00 Depth: 7648' 24 Hour summary: Footage: : 284' Horizon Geologists: i Neil Peterson (6PM-6AM) ¡ Lowell pri ce (6AM-6PM) Drill fr/7364' t/7648'; c.o.; wipe hole t/7000'. Latest Mud Report: Latest survey(s): DRILL RATE MW 9.7 vis 74 PV 21 YP 25 Gels 15/19/21 sol 10.0 oil 68 SA L 5 7.ººº..!!).9l.Jm..Ç]:::_m_m_mmm_____m..,__m__. See Mudlog High: 125'/hr 3'/hr 30'/hr O'/hr LITHOLOGY DITCH GAS High: 315u chrom comp: Cool @ 7516' Low: 22u wiper Gas: Average: 100u conn Gas: Current: Ou LOw: ........................-....-....._-- Average: Current: ......--...................-.... Interval synopsis SANDSTONE: It-med gry; pr-mod srtd; rnd-sbang; grain sprtd. SAND: It-med gry; mod-well srtd; rnd-sbrnd; unconsl. 6320'- CLAysl'ÒNE:med-gryái1d"aUsk"ym'brrï=òTìvembrn;rilüdfrrm- fi rm; earthy; waxy-gritty when scored; freq grdg w/siltstn. COAL: blk; firm-mod firm; subvit-vit luster; irreg, hackly fracture; bituminous-lignitic. HYDROCARBON SHOWS .....---....-.-.--- Interval Gas Description ...................-..--.-..-.........-............-..-..- Remarks: Max Gas: 315u @ 7516 ; Background Gas = 90u Daily rate: $1300 + $15/man/day (oil based mud charge) = $1330/day Man Hours: 24 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H·······,·····························.....·.···..'......::...........................,··..·····....··N IJ R ,,-, Z IJ /<' -;~-, -~I~\. operator Forest oi 1 well west Foreland #2 Location West Foreland Report For: Joe Harris Report No. : 22 Morning Report 10/14/2004 03:00 ----....---- Depth: 7648' 24 Hour Summary: Footage: I 284' Horizon Geologists: ¡ Neil peterson (6PM-6AM) . Lowell pri ce (6AM-6PM) Date: Time: Latest Mud Report: Latest survey(s): DRILL RATE Drill fr/7364' t/7648'; c.o.; wipe hole t/7000'; High amounts of wiper gas after 11581 strokes (~636.95 Bbls). 481u WG. MW 9.7 vis 74 PV 21 YP 25 Gels 15/19/21 Sol 10.0 oil 68 SAL 57000 mg/l Q.::::m_ See Mudlog DITCH GAS High: 315u @ 7516' High: 125' /hr 3'/hr ..-...----.-...........--....... 30'/hr O'/hr LITHOLOGY Ou 100u Chrom comp: wiper Gas: ............................................................ Conn Gas: c-1 I 481u @7648' .............................--....-. LOw: Average: Current: LOw: Average: Current: .m.....__. ._.__.__mm._....._......_........_...H._..._... .....................-.-.......-...-..-.........-.-.--.. Interval synopsis SANDSTONE: It-med gry; pr-mod srtd; rna-':::soang;--grain sprtd. SAND: It-med gry; mod-well srtd; rnd-sbrnd; unconsl. CLAYSTONE: med gryaï1d dusky"brn"':::61TvèO'r'ï1;iñOa"fì rm-fi rm; ....,..,...... earthy; waxy-gritty when scored; freq grd9 w/siltstn. Note: distinct change in lithologic character ln bottoms up sample prior to wiper trip at 7648'; claystones grdg to siltstone; Incrsgly crs and free of argillaceous material. "clean" siltstones and sandstones. 6320'- oJ: 'k .¡( oJ: "1: oJ: oJ: oJ: .¡( -l: COAL: blk; firm-mod firm; subvit-vit luster; irreg, hackly fracture; bituminous-lignitic; occ lrg pieces @ shakers; probable up-hole slough HYDROCARBON SHOWS Interval Gas Description .-----....--......."".,.-.........-- Remarks: Max Gas: 315u @ 7516'; Background Gas = 90u-~sinificant increase since 7508' MD. Daily rate: $1300 + $15/man/day (oil based mud charge) = $1330/day Man Hours: 24 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H···· .... .............................;...'.....~;......'....---.-.--..... N [] Ri~.Z [] operator Forest oil well west Foreland #2 Location west Foreland Report For: Joe Harri s Report No. : 23 ~.; § vi? Morning Report Date: 10/15/2004 Time: 03:00 Depth: 8021' 24 Hour Summary: 373' Neil Peterson (6PM-6AM) Lowell Price (6AM-6PM) Footage: Horizon Geologists: Drill fr/7648't/8021'. Latest Mud Report: Latest survey(s): DRILL RATE MW 9.7 vis 84 PV 24 YP 29 Gels 21/26/29 sol 8.33 oil 68 SAL 50000 mg/l Cl- See Mudlog DITCH GAS High: 226'/hr .....-..........-........ . Low: 4' /hr ........mm.m..........~nn_ ........................................__ Average: 50'/hr ....................................... Current: 51'/hr LITHOLOGY High: 486u Chrom comp: c-1 @7881' Low: 42u wiper Gas: Average: 100u Conn Gas: Current: 82u Interval ! synopsi s . SANDSTONE: It-med gry; pr-mod srtd; rnd-sbang; grain sprtd. SAND: It-med gry; mod-well srtd; rnd-sbrnd; unconsl; com coal partgs; mnr lithic frags. CLAYSToNE:"med gry and duskyorn-olive"orn and Tfm··gry·w/sTì----- brnsh cast; mod firm-firm; tuffaceous; wk vis lams; earthy; waxy-gritty when scored; freq grdg w/siltstn. SILTSTONE: It-med gry w/occ sli brnsh hue; prly ind-kaolinitic cmntd; tuffaceous; grdg w/claystn and sand/sandstn. COAL: blk; firm-mod firm; subvit-vit luster; irreg, hackly fracture; bituminous-lignitic. HYDROCARBON SHOWS ...............-.--..........-..... 7648'- .-......-.- Interval I Descri pti on Gas ...................................................................................-- ~ . Remarks: Max Gas: 486u @ 7881'; Background Gas = 80u Daily rate: $1300 + $15/man/day (oil based mud charge) = $1330/day Man Hours: 24 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H .~.._~ ·_·~--··...lC.··.··'-"'·~····':··"_·_··"··"·""· N [] RAt. Z [] Operator Forest oil well West Foreland #2 Location west Foreland Report For: Joe Harri s Report No. : 24 ~ Morning Report Date: 10/16/2004 Time: 03:00 Depth: 8277' 24 Hour Summary: Footage: Horizon Geologists: 256' Neil peterson (6PM-6AM) Lowell Price (6AM-6PM) Latest Mud Report: Latest Survey(s): DRILL RATE Drill fr/8021' t/8277'; POOH for bit/mud motor and weekly BOP test. MW 9.7 vis 82 PV 24 YP 27 Gels 22/25/27 sol 7.96 oil 68 SAL 50500 mg/l cl- See Mudlog DITCH GAS High: 174u @8273' 8u 20u Ou ......_......~ 239'/hr High: ...........................-..............-...... ................................................ 2'/hr LOw: ................................ mm......................_m....... ..................................... 50'/hr Average: O'/hr Current: LITHOLOGY I chrom Comp: c-1 wiper Gas: ............"........ ......... Conn Gas: _..........~._....._.._.- Low: Average: Current: ....................-......--- .........mm........................................___ Interval ! synopsi s "SANDSTONE: It-med gry; pr-mod srtd; rnd-sbang; grain sprtd. SAND: It-med gry; mod-well srtd; rnd-sbrnd; unconsl; com coal Partgs; mnr lithic frags. mCLAYSToNE:"med gryàïïd dusky brn-ol i vé"hrn and It gry"wlslT"'""- brnsh cast; mod firm-firm; tuffaceous; wk vis lams; earthy; waxy-gritty when scored; freq grdg w/siltstn. SILTSTONE: It-med gry w/occ sli brnsh hue; prly ind-kaolinitic cmntd; tuffaceous; grdg w/claystn and sand/sandstn. 1 COAL: blk; firm-mod firm; subvit-vit luster; irreg, hackly . fracture; bituminous to sub-bitumenous. HYDROCARBON SHOWS ........................._...__mmnmn__.__ 8021'- Interval Gas i Descri ption Remarks: Max Gas: 174u @ 827~'; Background Gas = IOu Daily rate: $1300 + $15/man/day (oil based mud charge) = $1330/day Man Hours: 24 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H '.~'~M~·~-····..·....·."...l.'.___··~~ N [J R;~Z [J operator Forest oil well west Foreland #2 Location west Foreland Report For: Joe Harri s Report No. : 25 Morning Report Date: 10/17/2004 Time: 03:00 Depth: 8393' 24 Hour Summary: 116' Neil Peterson (6PM-6AM) Lowell price (6AM-6PM) Footage: Horizon Geologists: Latest Mud Report: Latest survey(s): DRILL RATE Perform BOP test; m/u new BHA; RIH and c.o.; Drill fr/8277' t/8393' ; MW 9.7 vis 85 PV 25 YP 25 Gels 21/25/30 sol 10.0 oil 68 SAL 50500 mgn cl- see Mudlog DITCH GAS High: 123u @8282' 47u 85u 47u High: ! 266'/hr 3'/hr 150'/hr , 101' /hr LITHOLOGY Average: Current: chrom comp: ¡ C-1 .....-. Tri p Gas: ! 323u @8277' ........................................... Conn Gas: Low: Average: Current: LOw: Interval synopsis SANDSTONE: It-med gry; pr-mod srtd; rnd-sbang; grain sprtd. SAND: It-med gry; mod-well srtd; rnd-sbrnd; unconsl; com coal Partgs; mnr lithic frags. CLAYSTONE: med gry and dusky brn-oTive firn and It gry w/sli brnsh cast; mod firm-firm; tuffaceous; wk vis lams; earthy; waxy-gritty when scored; freq grdg w/siltstn. SILTSTONE: It-med gry w/occ sli brnsh hue; prly ind-kaolinitic cmntd; tuffaceous; grdg w/claystn and sand/sandstn. COAL: blk; firm-mod firm; subvit-vit luster; irreg, hackly fracture; bituminous to sub-bitumenous. HYDROCARBON SHOWS 8277' - Interval Gas Description Remarks: Max Gas: 123u @ 8282'; Background Gas = 40u Daily rate: $1300 + $15/man/day (oil based mud charge) = $1330/day Man Hours: 24 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · HtlR~tzcN I Morning Report operator Forest oil well west Foreland #2 Location West Foreland Report For: Joe Harri s Report NO. : 26 Date: 10/18/2004 Time: 03:00 Depth: 8677' 24 Hour Summary: 116' Neil peterson (6PM-6AM) Lowell price (6AM-6PM) Footage: Horizon Geologists: Drill fr/8393' t/8677'; Latest Mud Report: Latest survey(s): DRILL RATE MW 10.0 vis 85 PV 24 YP 30 Gels 19/27/31 sol 11.5 oil 66.5 SAL 51000 mg/l Cl- See Mudlog DITCH GAS High: 1694u @8496' .......... ..............._m.......___....... 64u 200u 67u Chrom Comp: i C-1 Trip Gas: .-................................. Conn Gas: LOw: 117'/hr High: ..............................................-.... .m_ 4'/hr LOW: 30'/hr Average: O'/hr Current: LITHOLOGY synopsis SANDSTONE: It-med gry; pr-mod srtd; rnd-sbang;---grãiñ sprtd. SAND: It-med gry; mod-well srtd; rnd-sbrnd; unconsl; com coal Partgs; mnr lithic frags. Average: Current: Interval 8393'- CLAYSTONE: med gry and dusky brn-olive brn and lt gry w/sli brnsh cast; mod firm-firm; tuffaceous; wk vis lams; earthy; waxy-gritty when scored; freq grdg w/siltstn. SILTSTONE: It-med gry w/occ sli brnsh hue; prly ind-kaolinitic cmntd; tuffaceous; grdg w/claystn and sand/sandstn. COAL: blk; firm-mod firm; subvit-vit luster; irreg, hackly fracture; bituminous to sub-bitumenous. HYDROCARBON SHOWS Interval I Descri ption Gas Remarks: Max Gas: 1694u @8496'; Background Gas = 50u Daily rate: $1300 + $15/man/day (oil based mud charge) Man Hours: 24 $1330/day · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H· ~.....'...,~... ......~~~._._~~.. ·····.......,....f. .---...---. N c R~Sþ,Z C operator Forest oi 1 well West Foreland #2 Location West Foreland Report For: Joe Harri s Report No. : 27 Morning Report Date: 10/19/2004 Time: 03:00 Depth: 8690' 24 Hour summary: Footage: i 13' Horizon Geologists: ¡ Neil Peterson (6PM-6AM) I Lowell Price (6AM-6PM) Latest Mud Report: Latest survey(s): DRILL RATE POOH; change out mud motor; RIH line; RIH; Drill t/8790'. MW 10.0 vis 110 PV 24 YP 31 Gels SAL 51000 mg/l cl- See Mudlog t/shoe; slip & cut drill 20/25/27 Sol 9.96 oil 66 DITCH GAS High: 13 ' /h r High: Ou Chrom Comp: c-1 Low: 8'/hr LOw: Ou Trip Gas: 212u @8677' Average: 10'/hr Average: Ou ' Conn Gas: 76u @8667' ............-..-.-- Current: O'/hr Current: 20u LITHOLOGY Interval Synopsis SANDSTONE: It-med gry; pr-mod srtd; rnd-sbang; grain sprtd. SAND: It-med gry; mod-well srtd; rnd-sbrnd; unconsl; com coal partgs; mnr lithic frags. CLAYSTONE: med gry and dusky brn-olive brn and lt gry w/sli brnsh cast; mod firm-firm; tuffaceous; wk vis lams; earthy; waxy-gritty when scored; freq grdg w/siltstn. SILTSTONE: It-med gry w/occ sli brnsh hue; prly ind-kaolinitic cmntd; tuffaceous; grdg w/claystn and sand/sandstn. COAL: blk; firm-mod firm; subvit-vit luster; irreg, hackly fracture; bituminous t/sub-bitumenous. HYDROCARBON SHOWS 8393'- Interval , Descri pti on Gas _____.__......H_._..HU................ ..................--..........-..-..--.--... .............................- Remarks: Max Gas: no formation gas circulated out by 3AM; Background Gas = 20u; Trip gas 212u @8677' Daily rate: $1300 + $15/man/day (oil based mud charge) = $1330/day Man Hours: 24 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H···· ......._...........................'.....;............_-_........ N [J R,,,cZ [J operator Forest oil well West Foreland #2 Location West Foreland Report For: Joe Harri s Report NO. : 28 Morning Report Date: 10/19/2004 Time: 03:00 Depth: 9230' 24 Hour Summary: 440' Neil Peterson (6PM-6AM) Lowell price (6AM-6PM) Footage: Horizon Geologists: Drill fr/8790' t/xxxx'. Latest Mud Report: Latest Survey(s): DRILL RATE MW 10.0 vis 100 PV 24 YP 35 Gels 21/26/30 sol 11.91 oil 66 SAL 56000 mglJ._5;l:::__ See Mudlog DITCH GAS High: 230'/hr High: 461u Chrom Comp: c-1 @9066' Low: 3'/hr LOw: 52u Trip Gas: Average: 25'/hr Average: 80u Conn Gas: m.......................................... Current: O'/hr Current: 61u LITHOLOGY ................................ Interval synopsis SANDSTONE: It-med gry; pr-mod srtd; rnd-sbang;-- grain sprtd. SAND: It-med gry; mod-well srtd; rnd-sbrnd; unconsl; com coal partgs; mnr lithic frags. CLAYSTONE: med gry and dusky brn-olive brn and lt gry w/sli brnsh cast; mod firm-firm; tuffaceous; wk vis lams; earthy; waxy-gritty when scored; freq grdg w/siltstn. SILTSTONE: It-med gry w/occ sli brnsh hue; prly ind-kaolinitic cmntd; tuffaceous; grdg w/claystn and sand/sandstn. COAL: blk; firm-mod firm; subvit-vit luster; irreg, hackly fracture; bituminous t/sub-bitumenous. HYDROCARBON SHOWS 8790'- Interval I Deseri pti on Gas -...----.----.-- ...........................- Remarks: Max Gas: 461u @ 9066'; Background Gas = 55u; Daily rate: $1300 + $15/man/day (oil based mud charge) Man Hours: 24 $1330/day · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · ~ili operator Forest oil well West Foreland #2 Location west Foreland Report For: Fred Brent Report No. : 29 H"""'''H''''·''''''''',''"t...,~,.""...,""',""""-""'''''''''''''' N [] R /=,1'::' Z [] !,,¢., .,...,.\ Morning Report Date: 10/21/2004 Time: 03:00 Depth: 9418' 24 Hour Summary: Footage: ! 98' Horizon Geologists: i Neil peterson (6PM-6AM) i Lowell pri ce (6AM-6PM) circ and cond mud; Drill fr/9320' t!9421'. Latest Mud Report: Latest survey(s): DRILL RATE MW 10.0 vis 95 PV 25 YP 30 Gels 20/25/30 sol 8.96 oil 67 SAL 52500 mg/l cl- See Mudlog DITCH GAS High: 40'/hr High: 130u i ch rom comp: c-1 @9384' Low: 4'/hr LOw: 23u ! Trip Gas: Average: 13' /hr Average: 45u Conn Gas: Current: 16'/hr Current: 59u LITHOLOGY mmmm.................___..__............ ..............................._....._........... .......-....--.-- Interval synopsis SANDSTONE: It-med grY-;"pr-mod s rtd; rnd-soang; grai n sprtd; com arg & friable. SAND: It-med gry bcmg pl yelsh to pl brnsh gry; mod-well srtd; rnd-sbrnd; unconsl; com coal partgs; mnr lithic frags. CLAysfoï\iË:mmedmgrym'and dusky brn-ol i ve brn and It' gry w/sl i brnsh cast; mod firm-firm; tuffaceous; wk vis lams; earthy; waxy-gritty when scored; freq grdg w/siltstn. SILTSTONE: It-med gry w/occ sli brnsh hue; prly ind-kaolinitic cmntd; tuffaceous; grdg w/claystn and sand/sandstn. COAL: blk; firm-mod firm; subvit-vit luster; irreg, hackly fracture; bituminous t/sub-bitumenous. HYDROCARBON SHOWS 9320'- Interval Gas Description Remarks: Max Gas: 130u @9384'; Background Gas = 25u; Daily rate: $1300 + $15/man/day (oil based mud charge) Man Hours: 24 $1330/day · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H"····...··-·'""··..·...·-·..'""·...',.··,·"·····"':··'····'.'.·..,~·_..·"'.._,·'"'..~....·'""'-..N [] R "..\ Z [] Jf, ""^ ßÞ:~ operator Forest oi 1 well west Foreland #2 Location west Foreland Report For: Fred Brent Report NO. : 30 Morning Report Date: 10/22/2004 Time: 03:00 Depth: 9438' 24 Hour Summary: 20' Neil Peterson (6PM-6AM) Lowell Price (6AM-6PM) Footage: Horizon Geologists: Drill fr/ 9418' t/9438'; POOH for new bit; RIH. Latest Mud Report: Latest survey(s): DRILL RATE MW 9.9 vis 94 PV 23 YP 34 Gels 20/26/30 sol 8.96 oil 68 sAL 51000 mg/l Cl- See Mudlog DITCH GAS High: 11'/hr High: 56u Chrom comp: C-1 3 ' Low: 2'/hr LOw: 40u Trip Gas: Average: 8'/hr Average: 45u Conn Current: O'/hr Current: Ou LITHOLOGY Interval "' Synopsi s I SANDSTONE: It-med gry; pr-mod srtd; rnd-sbang; grain sprtd; I com arg & friable. I SAND: It-med gry bcmg pl yelsh to pl brnsh gry; mod-well srtd; "' rnd-sbrnd; unconsl; com coal partgs; mnr lithic frags. """'TcLÄYSTONE: med gryàï1d duskÿbrn':'c)"Tìve'brn and lt gry'wlsTì"""--- I brnsh cast; mod firm-firm; tuffaceous; wk vis lams; I earthy; waxy-gritty when scored; freq grdg w/siltstn. I SILTSTONE: It-med gry w/occ sli brnsh hue; prly ind-kaolinitic cmntd; tuffaceous; grdg w/claystn and sand/sandstn. i COAL: blk; firm-mod firm; subvit-vit luster; irreg, hackly "' fracture; bituminous t/sub-bitumenous. HYDROCARBON SHOWS ................._.......___....mm............_....... 9418'- Interval Gas Description Remarks: Max Gas: 56u @9423'; Background Gas = 25u; Daily rate: $1300 + $15/man/day (oil based mud charge) Man Hours: 24 $1330/day · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H ,.'c,.,'c,",...,"'c..,.'c"'"...'.'.......'.'.......;......'.'.'.......,...,""""""""'''' N CRr·',ZC ,,112,., operator Forest oil well West Foreland #2 Location west Foreland Report For: Fred Brent Report No. : 31 ,~ Morning Report Date: 10/23/2004 Time: 03:00 Depth: 9615' 24 Hour summary: 277' Neil Peterson (6PM-6AM) Lowell price (6AM-6PM) Footage: Horizon Geologists: Drill fr/9438' t/9715'. Latest Mud Report: Latest survey(s): DRILL RATE MW 10.0 vis 95 PV 25 YP 30 Gels 19/24/28 sol 10.01 oil 66 SAL 51000 mg/l cl- See Mudlog DITCH GAS High: 241'/hr High: 152u chrom Comp: C-1 @9571' Low: 3'/hr Low: 14u Trip Gas: .............................................. Conn Gas: Average: 50'/hr Average: 45u Current: O'/hr Current: 21u LITHOLOGY Interval : synopsi s . SANDSTONE: It-med gry; pr-mod srtd; rnd-sbang; grain sprtd; com arg & friable. SAND: It-med gry bcmg pl yelsh to pl brnsh gry; mod-well srtd; rnd-sbrnd; unconsl; com coal partgs; mnr lithic frags. C LA YSTON E :"med 9 ry äna·····"dÙ5;kyhrn=üTì\le'Orri'an"dlt'gryw/sTì" brnsh cast; mod firm-firm; tuffaceous; wk vis lams; earthy; waxy-gritty when scored; freq grdg w/siltstn. SILTSTONE: It-med gry w/occ sli brnsh hue; prly ind-kaolinitic cmntd; tuffaceous; grdg w/claystn and sand/sandstn. ! COAL: blk; firm-mod firm; subvit-vit luster; irreg, hackly , fracture; bituminous t/sub-bitumenous. HYDROCARBON SHOWS 9438'- m........................................................................... .......................................................... .................................... Interval Gas Description Remarks: Max Gas: 152u @9571'; Background Gas = 25u; Daily rate: $1300 + $15/man/day (oil based mud charge) = $1330/day Man Hours: 24 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H ,._..."......-............_.................'.~:.i,...·.····.·----·''·..··'··..··..···· N [J R .G'I';¡, Z [J ¥ ~~1;~~~ operator Forest oil well west Foreland #2 Location west Foreland Report For: Fred Brent Report NO. : 32 ~ ~ Morning Report Date: 10/24/2004 Time: 03:00 Depth: 9930' 24 Hour Summary: Footage: Horizon Geologists: 215' Neil Peterson (6PM-6AM) Lowell price (6AM-6PM) Drill fr/9715' t/9930'; Problem w/ HP; circ btms up; POOH. Latest Mud Report: Latest survey(s): DRILL RATE MW 10.0 vis 91 PV 26 YP 28 Gels 18/24/26 sol 9.51 oil 66.5 SAL 50000 mg/l cl- See Mudlog DITCH GAS High: 163u @9920' 25u 40u Ou chrom comp: C-l Trip Gas: Conn Gas: 1126' /hr 7'/hr 18' /h r O'/hr LITHOLOGY High: ........................ ........_.........._........_ .mm........................... LOw: Average: Current: LOw: Average: Current: .--..........--............- Interval synopsis SANDSTONE:"Tt:::irïècr-gry;-pr:::-rñoamsrfd; rnd-s5àng; grai n sprtd; com arg & friable; wk calc/kaolin cmt. SAND: It-med gry bcmg pl yelsh to pl brnsh gry; mod-prly srtd; Fn-crsu; dom med-crsL; sbrnd-sbang; unconsl; com coal partgs; mnr lithic frags. mmmmm...mmmmm...m-CLÄYSTONE: It-med gry w/comhrÌ1sh hue; mod firm-friabTè-;m-géri msv w/occ wk vis lams; earthy lustr; grdg w/siltstn, sand- stn; SILTSTONE: It-med gry w/com brnsh hue; prly ind-argillaceous/ Kaolinitic; occ wk rxn w/HCl after washing; tuffaceous; grdg w/claystn and sand/sandstn. 9715'- i COAL: blk; firm-mod firm; subvit-vit luster; irreg, hackly 1 fracture; bituminous t/sub-bitumenous; com as thin string- ers or as lrg pieces of slough. HYDROCARBON SHOWS -...---...-.............---. Interval Gas Description .............nm._____.. Remarks: Max Gas: 163u @9920'; Background Gas = 25u; Daily rate: $1300 + $15/man/day (oil based mud charge) = $1330/day Man Hours: 24 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H········, .'-' ·"·"'·'·'.",',..'·.,.,·,:',C, ",-""'---"',,, N [J Ri$LZ [J operator Forest oil well west Foreland #2 Location west Foreland Report For: Fred Brent Report NO. : 33 Morning Report Date: 10/25/2004 Time: 03:00 Depth: 9930' 24 Hour Summary: Footage: Horizon Geologists: 10' Neil Peterson (6PM-6AM) Lowell Price (6AM-6PM) t/612Ò' . POOH; repalr HP; svc rig; RIH Latest Mud Report: Latest survey(s): DRILL RATE MW 10.0 vis 150 PV 26 YP 28 Gels 18/23/26 sol 11.5 oil 66.5 SAL 50500 mg/l Cl- See Mudlog DITCH GAS High: O'/hr High: Ou Chrom comp: LOw: O'/hr Low: Ou Trip Gas: .............................................. Conn Gas: Average: O'/hr Average: Ou Current: O'/hr Current: Ou LITHOLOGY : synopsi s SANDSTON-E:"mlt-med gry; 'pr=ÏÎÏod"5 rtcr; rnd-soang; grai n sprtd; com arg & friable; wk calc/kaolin cmt. SAND: It-med gry bcmg pl yelsh to pl brnsh gry; mod-prly srtd; Fn-crsu; dom med-crsL; sbrnd-sbang; unconsl; com coal partgs; mnr lithic frags. mmmmmm.....m-rc'LÄ YSTON E : mm, t - med 9 ryw/com·hrn·s·h····hÙé;ÏÎÏo"d·TìrÏÎÏ=frTáb 1 e; gen·mm.m.- I msv w/occ wk vis lams; earthy lustr; grdg w/siltstn, sand- i stn; I SILTSTONE: It-med gry w/com brnsh hue; prly ind-argillaceous/ I Kaolinitic; occ wk rxn w/Hcl after washing; tuffaceous; I grdg w/claystn and sand/sandstn. I COAL: blk; firm-mod firm; subvit-vit luster; irreg, hackly , fracture; bituminous t/sub-bitumenous; com as thin string- ers or as lrg pieces of slough. HYDROCARBON SHOWS Interval __...H................___.___.....__._m..__m.__.._..._._._......_ Interval ! Descri pti on Gas Remarks: Daily rate: $1300 + ~15/man/day (oil based mud charge) Man Hours: 24 $1330/day · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H ..·....·············,·······__..·'.·........'.7. :.........................--..........-.... N [] R+,Z [] operator Forest oil well west Foreland #2 Location West Foreland Report For: Fred Brent Report No. : 34 ~ !~ Morning Report Date: 10/26/2004 Time: 03:00 Depth: 10129' 24 Hour Summary: Footage: Horizon Geologists: 199' Neil peterson (6PM-6AM) Lowell price (6AM-6PM) RIH; Drill t/l0129'. Latest Mud Report: Latest Survey(s): DRILL RATE MW 10.0 vis 88 PV 26 YP 28 Gels 18/23/26 sol 9.71 oil 66 SAL 56150 mg/1 c1- See Mud10g DITCH GAS High: LOw: Average: Current: 85u @ 9934' 15u 28u 22u C-l 211u @ 9930' 8u @ 10119' 104'/hr 3'/hr 20'/hr 23'/hr LITHOLOGY High: chrom Comp: Trip Gas: Conn Gas: ··..·............................·.·.·.....··...······.....__m.... LOw: Average: Current: Interva 1 synopsis SANDSTONE: 1t-med gry; pr-mod srtd; rnd-sbang; grain sprtd; com arg & friable; wk calc/kaolin cmt. SAND: 1t-med gry bcmg p1 ye1sh to p1 brnsh gry; mod-pr1y srtd; Fn-crsu; dom med-crsL; sbrnd-sbang; uncons1; com coal partgs; mnr lithic frags. CLA YSfÓNE:mTf=ïïïèdçry"w/c6mmbFnsn'hùè;mïïïódfìrm=fFlab 1 e; gen msv w/occ wk vis lams; earthy 1ustr; grdg w/si1tstn, sand- stn; SILTSTONE: 1t-med gry w/com brnsh hue; pr1y ind-argi11aceous/ Kaolinitic; occ wk rxn w/Hc1 after washing; tuffaceous; grdg w/c1aystn and sand/sandstn. COAL: blk; firm-mod firm; subvit-vit luster; irreg, hack1y fracture; bituminous t/sub-bitumenous; com as thin string- ers or as 1rg pieces of slough. HYDROCARBON SHOWS .........m....__......___._.....__.._ 9930'- Interval Gas Description Remarks: Max Gas = 85u @9934'; Background Gas = IOu Daily rate: $1300 + $15/man/day (oil based mud charge) Man Hours: 24 $1330/day · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H .....---- .--. --.......c....... ,---..-.. . N [J RJ\,Z [J operator Forest oil well West Foreland #2 Location west Foreland Report For: Fred Brent Report No. : 35 «" .. " Morning Report Date: 10/27/2004 Time: 03:00 Depth: 10381' 24 Hour summary: 252' Neil Peterson (6PM-6AM) Lowell Price (6AM-6PM) Footage: Horizon Geologists: Drill fr/10129' t/10381'. Latest Mud Report: Latest survey(s): DRILL RATE MW 10.0 vis 84 PV 25 YP 27 Gels 15/19/24 sol 9.33 oil 67 SAL 50500 mg/l cl- See Mudlog DITCH GAS High: 1l0'/hr High: 185u Chrom comp: c-1 @10278' Low: 6'/hr LOW: 19u Trip Gas: ..- Average: 15'/hr Average: 60u Conn Gas: Current: O'/hr Current: 74u LITHOLOGY ..........-........-..-.......- Interval synopsis SANDSTONE: It-med gry; pr-mod srtd; rnd-sbang; grain sprtd; SAND: It-med gry bcmg med yelsh to med orgsh brn btwn 10355'- 10365'; mod-well srtd; Fn-crsL; dom fn-med; sbrnd-sbang; unconsl; com coal partgs; mnr lithic frags. CLAYSTONE: It-med gry w/com brnsh hue; mod firm-friable; gen msv w/occ wk vis lams; earthy-subresinous lustr; grdg w/ siltstn, sandstn SILTSTONE: It-med gry w/com brnsh hue; prly ind-argillaceous/ Kaolinitic; tuffaceous; grdg w/claystn and sand/sandstn. COAL: blk; firm-mod firm; subvit-vit luster; irreg, hackly fracture; bituminous t/sub-bitumenous; com as thin string- ers or as lrg pieces of slough. 10129'- HYDROCARBON SHOWS Interval Gas Description Remarks: Max Gas = 185u @10278'; Background Gas = 70u Daily rate: $1300 + $15/man/day (oil based mud charge) Man Hours: 24 $1330/day · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H _. .-......."A····..·..'........·....·'.·..·.··.,i...~~.¡:.......,...._...._.,._...,....."..,.., N [] R[i~Z [] operator Forest oil well west Foreland #2 Location west Foreland Report For: Fred Brent Report No. : 36 Morning Report Date: 10/28/2004 Time: 03:00 Depth: 10585' 24 Hour Summary: Footage: Horizon Geologists: 204' Neil peterson (6PM-6AM) Lowell Price (6AM-6PM) Drill fr/10381' t/10585'. Latest Mud Report: Latest Survey(s): DRILL RATE MW 10.0 vis 82 PV 26 YP 26 Gels 15/18/24 Sol 7.91 oil 68 SAL 52000 mg/l cl- See Mudlog DITCH GAS High: 171u @10461' 28u 35u 33u .........-.............---..-. 301'/hr 2'/hr 15'/hr 12'/hr High: Chrom Comp: c-1 Trip Gas: Conn Gas: Low: Average: Low: Average: Current: .......-....-..---.-- Current: LITHOLOGY Interval synopsis SANDSTONE: It-med gry; pr-mod srtd; rnd-sbang; grain sprtd; SAND: It-med gry bcmg med yelsh to med orgsh brn btwn 10355'- 10365'; mod-well srtd; Fn-crsL; dom fn-med; sbrnd-sbang; unconsl; com coal partgs; mnr lithic frags. CLAYSTONE: It-med gry w/com brnsh hue; mod firm-friable; gen msv w/occ wk vis lams; earthy-subresinous lustr; grdg w/ siltstn, sandstn SILTSTONE: It-med gry w/com brnsh hue; prly ind-argillaceous/ Kaolinitic; tuffaceous; grdg w/claystn and sand/sandstn. COAL: blk; firm-mod firm; subvit-vit luster; irreg, hackly fracture; bituminous t/sub-bitumenous; com as thin string- ers or as lrg pieces of slough. 10381'- HYDROCARBON SHOWS Interval Gas Description Remarks: Max Gas = 171u @10461'; Background Gas = 30u Daily rate: $1300 + $15/man/day (oil based mud charge) Man Hours: 24 $1330/day · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H··· ......."..... ........."............«....~..'...;........................."...................'0 N [] R,,~Z [] operator Forest Oil well west Foreland #2 Location west Foreland Report For: Fred Brent Report NO. : 37 "',,1 ~ ~J' Morning Report Date: 10/29/2004 Time: 03:00 Depth: 10717' 24 Hour Summary: Footage: Horizon Geologists: 132' Neil peterson (6PM-6AM) Lowell Price (6AM-6PM) Drill fr/10585' t/10717'; c.o. and wipe hole t/5200'. Latest Mud Report: Latest survey(s): DRILL RATE MW 10.0 vis 82 PV 26 YP 26 Gels 15/18/24 sol 7.91 oil 68 SAL 52000 mg/l cl- See Mudlog DITCH GAS High: 103'/hr High: 171u Chrom comp: C-1 @10679' ..........-.........-..-......... LOw: 3'/hr LOw: 27u Trip Gas: _m.. Conn Gas: Average: 20'/hr Average: 35u Current: O'/hr Current: Ou LITHOLOGY Interval synopsis SANDSTONE: It-med gry; pr-mod srtd; rnd-sbang; grain sprtd; SAND: It-med gry; mod-well srtd; Fn-crsL; dom fn-med; sbrnd- sbang; unconsl; com coal partgs; mnr lithic frags; com argillaceous. CLAYSTONE: It-med gry w/com brnsh hue; mod firm-friable; gen msv w/occ wk vis lams; earthy-subresinous lustr; grdg w/ siltstn, sandstn SILTSTONE: It-med gry w/com brnsh hue; prly ind-argillaceous/ Kaolinitic; tuffaceous; grdg w/claystn and sand/sandstn. COAL: blk; firm-mod firm; subvit-vit luster; irreg, hackly fracture; bituminous t/sub-bitumenous. 10381'- Interval HYDROCARBON SHOWS Gas ..m........................................................................................ i Descri pti on 'Remarks: Max Gas = 171u @106i9'; Background Gas = 30u Daily rate: $1300 + $15/man/day (oil based mud charge) Man Hours: 24 $1330/day · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H ...,....,...., .,....,...,........'.'....,':::;,",.,.. ~.'......"."........"..... N C R f:;:l'~;\ Z C ¡-:r:l':""\ operator Forest oil well West Foreland #2 Location west Foreland Report For: Fred Brent Report No. : 38 ~ Morning Report Date: 10/30/2004 Time: 03:00 Depth: 10717' 24 Hour Summary: Footage: ' 0' Horizon Geologists: i Neil peterson (6PM-6AM) i Lowell Price (6AM-6PM) Latest Mud Report: Latest survey(s): DRILL RATE High: wipe hole t/5200'; RIH; pump 3 round trip circulations (condition hole for schlumberger loggers); POOH; R/U loggers MW 10.1 vis 86 PV 24 YP 26 Gels 16/21/23 sol 8.37 oil 68.5 SAL 52200 mg/l cl- See Mudlog DITCH GAS .....................~......... . O'/hr High: Ou chrom comp: c-1 O'/hr Low: Ou Trip Gas: 239u @ 10717' O'/hr Average: Ou Conn Gas: O'/hr Current: Ou Low: Average: Current: LITHOLOGY Interval synopsis HYDROCARBON SHOWS __.____..............m._._..__ Interval Gas i Descri ption ..................................... Remarks: Tri p Gas = 239u @ 10"717' ".......--.. Daily rate: $1300 + $15/man/day (oil Man Hours: 24 .........................--.- --,---....-.--.- based mud charge) = $1330/day · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · HCR_.-zcN Morning Report operator Forest oil well west Foreland #2 Location West Foreland Report For: Fred Brent Report NO. : 39 Date: 10/31/2004 Time: 03:00 Depth: 10717' 24 Hour Summary: 0' Neil Peterson (6PM-6AM) Lowell Price (6AM-6PM) Footage: Horizon Geologists: Latest Mud Report: RIH w/logging tools; POOH @9650' MD; reconfig RIH t/9650'; POOH; RIH t/ream and condition. MW 10.2 vis 110 PV 25 YP 25 Gels 16/21/25 sol SAL 52000 mg/l c.J:__..._...__ See Mudlog DITCH GAS logging tool; 8.4 oil 68 nm.................................. Latest survey(s): DRILL RATE High: O'/hr High: Ou chrom Comp: C-1 O'/hr Low: Ou Trip Gas: Ou O'/hr Average: Ou Conn Gas: O'/hr Current: Ou Low: Average: m._._......___..m.___........... Current: LITHOLOGY ...-.--...........-.....---... Interval synopsis HYDROCARBON SHOWS __nomnm........................................ Interval Gas Description Remarks: Daily rate: $1300 + ~15/man/day (oil based mud charge) $1330/day Man Hours: 24 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H _.._.__..._........./:~.;'~\.'...~-_...__. N [J R/lI~Z [J ~-,,~ ._,,-~ iN Morning Report Date: 11/1/2004 Time: 03:00 Depth: 10717' 24 Hour Summary: operator Forest oil well West Foreland #2 Location West Foreland Report For: Fred Brent Report NO. : 40 Footage: Horizon Geologists: 0' Neil Peterson (6PM-6AM) Lowell price (6AM-6PM) O'/hr High: Ou chrom comp: C-1 O'/hr Low: Ou Trip Gas: Ou O'/hr Average: Ou Conn Gas: O'/hr Current: Ou Latest Mud Report: RIH t/ream and condition tools; RIH t/10650; circ MW 10.2 vis 110 PV 25 YP SAL 52000 mg/l Cl- See Mudlog DITCH GAS ............m......_._.H......_. Latest survey(s): DRILL RATE High: Low: _m_mmm...._._.__._~ Average: Current: LITHOLOGY Interval synopsis HYDROCARBON SHOWS .._n_.......m...m........................H...·~__. Interval Gas Description ...............................-....... for logs; POOH and p/u NB#7 and dir and cond mud. 25 Gels 16/21/25 sol 8.4 oil 68 -"Remarks: Daily rate: $1300 + $IS/man/day (oil based mud charge) $1330/day Man Hours: 24 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H IJ-R_ì-ZcN :iì Morning Report operator Forest oil well west Foreland #2 Location West Foreland Report For: Fred Brent Report NO. : 41 Date: 11/2/2004 Time: 03:00 Depth: 11066' 24 Hour Summary: 349' Neil Peterson (6PM-6AM) Lowell Price (6AM-6PM) Footage: Horizon Geologists: Latest Mud Report: Drill fr/10717' t/11066'; MW 10.2 vis 86 PV 24 YP 30 Gels 18/24/26 sol 9.65 oil 66 sAL 57500 mg/l cl- See Mudlog DITCH GAS .......H..._........_..H_...._.U........... Latest survey(s): DRILL RATE High: 97u High: @ 10988' Chrom comp: c-1 LOw: 21u Trip Gas: 412u Average: SOu conn Gas: Current: SOu 157'/hr Low: Average: Current: 2'/hr 25'/hr 14'/hr LITHOLOGY Interval Synopsis SAND: med gry w/sli brn hue; pr srtg; fnu-crs; rnd-sbang > ang; dom cloudy, trnsl, opaque w/ assoc grnsh and gry brn; poor srtg; fnu-crs; unconsol; mnr friable, kaolinitic sandstn; grdg dom w/siltstn and claystn COAL: blk; dull to subresinous, waxy luster; hard-brittle; irreg, hackly and subplanar to subconchoidal fracture; vis cleats esp on lrg ctgs; com to abundant as slough (.5-2" dia.) lignitic to bitumenous. 10717'- CLAYSTONE: dk yelish brn to med/dk gryish brn, brnish gry; firm to v firm; subblocky to subtabular ctgs; commonly massive with rare to v mnr laminations; grades to argillaceous siltstone. HYDROCARBON SHOWS Interval Gas Description Remarks: Trip Gas = 412u; Max Gas = 97u @10988'; Background Gas = 30u Daily rate: $1300 + $15/man/day (oil based mud charge) = $1330/day Man Hours: 24 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H >_»>M MM M»_.....~_~.~\W..>..._.._._.____"'................. N [] R;~.Z [] Operator Forest oil well west Foreland #2 Location West Foreland Report For: Fred Brent Report NO. : 42 ~ Morning Report Date: Time: 11/3/2004 03:00 Footage: Horizon Geologists: 218' Neil peterson (6PM-6AM) Lowell Price (6AM-6PM) Depth: 11284' 24 Hour Summary: Drill fr/11066' t/11284; c.o. and POOH. MW 10.0 vis 80 PV 26 YP 26 Gels 15/18/20 sol 8.89 oil 66 SAL 58000 mg/l cl- See Mudlog DITCH GAS Latest Mud Report: Latest Survey(s): DRILL RATE High: 108u High: @ 11105' chrom comp: LOw: 27u Trip Gas: Average: 40u Conn Gas: Current: 45u 14u 11123' 108'/hr c-1 LOw: l'/hr 10'/hr O'/hr Average: Current: Interval LITHOLOGY , synopsi s -'--SAND: med gry w/sli brn hue; pr srtg; fnu-crs; rnd-sbang > ang; dom cloudy, trnsl, opaque w/ assoc grnsh and gry brn; poor srtg; fnu-crs; unconsol; mnr friable, kaolinitic sandstn; grdg dom w/siltstn and claystn 11066'- I COAL: blk; dull to subresinous, -waxy luster; hard-brittle; ! irreg, hackly and subplanar to subconchoidal fracture; vis I cl eats esp on 1 rg ctgs; com to abundant as slough (.5-2" di a.) I lignitic to bitumenous. i CLAYSTONE: dk yelish brn to med/dk gryish brn, brnish gry; I firm to v firm; subblocky to subtabular ctgs; commonly massive ! with rare to v mnr laminations; grades to argillaceous ! si ltstone. HYDROCARBON SHOWS Interval Gas Description Remarks: Max Gas = 108u @11105'; Background Gas = 30u Daily rate: $1300 + $15/man/day (oil based mud charge) = $1330/day Man Hours: 24 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H _m_________mm_.,....................=\...-.. ._______m_m N [] R,5~~Z [] operator Forest oil well west Foreland #2 Location west Foreland Report For: Fred Brent Report NO. : 43 Morning Report Date: 11/4/2004 Time: 03:00 Depth: 11284' 24 Hour Summary: 0' Neil Peterson (6PM-6AM) Lowell price (6AM-6PM) Footage: Horizon Geologists: Latest Mud Report: Latest survey(s): DRILL RATE High: c.o. and POOH for NB#8; m/u new BHA; RIH t/2875; slip and cut drill line; RIH t/5400; break circulation. MW 10.3 vis 190 PV 26 YP 27 Gels 15/20/21 sol 10.01 Oil 66 SAL 500QQ mg/l c]:::m See Mudlog LOw: Average: Current: DITCH GAS O'/hr High: Ou chrom comp: C-1 O'/hr LOw: Ou Trip Gas: O'/hr Average: Ou Conn Gas: O'/hr Current: Ou Interval LITHOLOGY I synops is SAND: med gry w/sli brn hue; pr srtg; fnu-crs; rnd-sbang > ang; dom cloudy, trnsl, opaque w/ assoc grnsh and gry brn; poor srtg; fnu-crs; unconsol; mnr friable, kaolinitic sandstn; grdg dom w/siltstn and claystn 11066'- COAL: blk; dull to sub resinous , waxy luster; hard-brittle; irreg, hackly and subplanar to subconchoidal fracture; vis cleats esp on lrg ctgs; com to abundant as slough (.5-2" dia.) lignitic to bitumenous. _.._......_....m.....___ CLAYSTONE: dk yelish brn to med/dk grÿTshm6rn-;- brnish firm to v firm; subblocky to subtabular ctgs; commonly with rare to v mnr laminations; grades to argillaceous siltstone. HYDROCARBON SHOWS gry; massive Interval I Descri pti on Gas Remarks: Daily rate: $1300 + $15/man/day (oil based mud charge) Man Hours: 24 $1330/day · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H' , --- -, ,-- '" d-----N c R '~Z C operator Forest oil well West Foreland #2 Location West Foreland Report For: Joe Harri s Report No. : 44 ff:í)! Morning Report Date: 11/5/2004 Time: 03:00 Depth: 11388' 24 Hour Summary: Footage: Horizon Geologists: 104' Neil Peterson (6PM-6AM) Lowell Price (6AM-6PM) Latest Mud Report: Latest Survey(s): DRILL RATE RIH; C.O.; 455u TG; Drill t/11388' T.D.; wipe hole; circ and cond for loggers. MW 10.1 vis 82 PV 25 YP 28 Gels 15/20/21 Sol 9.89 oil 66 SAL 52500 mg/l Cl- see Mudlog DITCH GAS High: 51u @11294' C-1 455u @11284' 60u @11388' 278'/hr High: chrom comp: Low: l'/hr Low: 17u Trip Gas: Average: 60'/hr t/11347'--- 6'/hr Average: t/11388 ' O'/hr Current: 40u Conn Gas: t/11347' - 20u t/11388 ' Ou Current: LITHOLOGY Interval synopsis SAND: med gry w/sli brn hue; pr srtg; fnu-crs; rnd-sbang, incrsd crs ang grs and lithics after 11347'; dom cloudy, trnsl, opaque w/assoc grn, pale grn, blk metalith and red, brn, lith frags; poor srtg; fnu-crs; unconsol; com friable, tuffaceous sandstn; COAL: blk; dull to subresinous, waxy luster; hard-brittle; irreg, hackly and subplanar to subconchoidal fracture; vis cleats esp on lrg ctgs; gen as slough (.5-2" dia.) lignitic to bituminous; CLAYSTONE: dk yelsh brn to med/dk grysh brn, brnsh gry; firm to v firm; subblocky to subtabular ctgs; commonly massive with rare to v mnr laminations; grades to argillaceous siltstone. HYDROCARBON SHOWS 11284'- Interval ! Descri ption Gas Remarks: Max Gas = 51u @11294'; -trip Gas = 455u; Background = 15u after 11347'. Daily rate: $1300 + $15/man/day (oil based mud charge) = $1330/day Man Hours: 24 . NOTE: washed spls after 11347' have 100% dull yel sample fluorescence; Fluorescence from drilling fluid is milky wht to pale blue. possible Tyonek/Hemlock contact @11347'; assoc dcrs in Total Gas and Rate of penetration. Overall coarsening of lith. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H'·"·'··'············""·.· ::..~.:."""...."~.".,..,.,..""'. N [J R ';f'~( Z [J /~ ......., _._ ..J._ operator Forest oil well West Foreland #2 Location west Foreland Report For: Joe Harri s Report NO. : 45 Morning Report Date: 11/6/2004 Time: 03:00 Depth: 11388' 24 Hour Summary: 0' Footage: Horizon Geologists: Neil peterson Wlpe hole every 1000' t/9000'; circ and cond for loggers. Latest Mud Report: Latest Survey(s): DRILL RATE High: MW 10.1 vis 99 PV 25 YP 30 Gels 16/22/24 sol 9.52 oil 65.5 SAL 50000 mg/1 cl- See Mudlog LOw: DITCH GAS O'/hr High: Ou chrom comp: C-1 O'/hr Low: Ou Trip Gas: 36u @9000' 69u @11388 ' -.... ........-.........................-......--.......... O'/hr Average: Ou Conn Gas: O'/hr Current: Ou Average: ..........--..--.....-.....-.......-..-..-...................... Current: LITHOLOGY Interval Synopsis SAND: med gry w/sli brn hue; vry pr srtg; fnu-crs; rnd-ang, incrsd crs ang grs and 1ithics after 11347'; dom cloudy, trns1, opaque w/assoc grn, pale grn, b1k metalith and red, brn, 1 ~¿~Lf.r.=6tt ~~¥lÇ~%;s~b~~~'i~~¿s ~qæá~~5T§li~r~u~:~~=b~i t~~~~stn; irreg, hackly and subplanar to subconchoida1 fracture; vis cleats esp on lrg ctgs; gen as slough (.5-2" dia.) lignitic to bituminous; CLAYSTONE: dk ye1sh brn to med/dk grysh brn, brnsh gry; firm to v firm; subb10cky to subtabular; commonly massive with rare to v mnr laminations; assoc siltstone. HYDROCARBON SHOWS Interval Gas Description Remarks: ~rip Gas = 36u @9006'; 69u @11388'. Daily rate: $1300 + $15/man/day (oil based mud charge) = $1330/day Man Hours: 24 NOTE: abundant loose sand>coal»c1aystone at shakers during periods of ---- Circulation. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H ------- -- ----...-.!:.;.¡;.......~..!............................_......... N [] Ri',Z [] operator Forest oil well west Foreland #2 Location west Foreland Report For: Joe Harris Report No. : 46 ~ Morning Report Date: 11/7/2004 Time: 03:00 Depth: 11388' 24 Hour summary: 0' Footage: Horizon Geologists: Neil peterson Latest Mud Report: Latest Survey(s): DRILL RATE High: Low: i POOH; r/u schlumberger loggers; RIH and log t/10700'; POOH; i p/u MDT; run MDT t/10378' : MW 10.0 vis 123 PV 22 YP 20 Gels 11/12/14 Sol 7.38 oil 67 SAL 42500 mg/l__çI:::.... See Mudlog DITCH GAS Average: O'/hr High: Ou Chrom comp: c-1 O'/hr Low: Ou Trip Gas: ! Ou O'/hr Average: Ou cÓnn······Gás:--------'-- O'/hr Current: Ou ·.·.....m......._..........·___·_.HH.......H................"... Current: LITHOLOGY Interval synopsis HYDROCARBON SHOWS Interval Gas I Descri pti on -Remarks: Daily rate: $1300 + $15/man/day (oil based mud charge) $1330/day Man Hours: 24 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H· ·-·-·····-·-...··...".·.·..1.,..··.····.·.·.....·.M.·. N [] Rjt'cZ [] operator well Forest oil West Foreland #2 west Foreland Joe Harri s Location Report For: Morning Report Report NO.: 47 Date: 11/8/2004 Time: 03:00 Depth: 11388' 24 Hour Summary: Footage: I 0' Horizon Geologists: Neil Peterson Latest Mud Report: Latest survey(s): DRILL RATE High: Finish schlumberger logs; rig down loggers; test BOP; p/u hole opener; RIH for hole opener run; open hole t/l0850' . MW 10.1 vis 152 PV 23 YP 24 Gels 12/15/¡7 sol 11.0 oil 67 SAL 50000 mg/l cl- See Mudlog Low: DITCH GAS O'/hr High: Ou chrom Comp: c-l O'/hr LOw: Ou Trip Gas: 124u @10850' O'/hr Average: Ou Conn Gas: O'/hr Current: Ou Average: Current: LITHOLOGY Interval Synopsis ..H__...._H..........................................__.... HYDROCARBON SHOWS Interval ! Deseri pti on Gas Remarks: Max Trip Gas = 124u during circ @10850'. Daily rate: $1300 + $15/man/day (oil based mud charge) $1330/day Man Hours: 24 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · H ,,', """"--.........:....:.....'..............------.--'.-..-.'...-..--.-. N C R:iZ C operator Forest Oil well West Foreland #2 Location west Foreland Report For: Joe Harris Report No. : 48 Morning Report Date: 11/9/2004 Time: 03:00 Depth: 11387' 24 Hour Summary: 0' Footage: Horizon Geologists: Neil peterson Latest Mud Report: Latest Survey(s): DRILL RATE High: open hole t/11387'; c.o.; wipe hole t/9000'; pull tight @10800'; c.o. @9000'; run t/bottom; c.o.; cont circ and wipe program t/maintain hole; begin r/u and inventory of rcv'd products for casing and cementers. MW 10.2 vis 115 PV 26 YP 29 Gels 15/19/22 Sol 9.26 oil 66 ?.l\~?'''?.?º_Q!!1g/1 C 1 - See Mudlog LOw: DITCH GAS O'/hr High: Ou ! ch rom comp: C-1 O'/hr Low: Ou Trip Gas: 79u @11387' O'/hr Average: Ou Conn Gas: O'/hr Current: Ou Average: Current: LITHOLOGY Interval synopsis HYDROCARBON SHOWS Interval Gas Description Remarks: Max Trip Gas = 79u during circ @11387'. Daily rate: $1300 + $15/man/day (oil based mud charge) = $1330/day Man Hours: 24 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · 5pE!~~Y-5un CRILLING seRVices BHA Report BHAt# 1 : Date In :09/17/20C MD In (ft) : 0 BIT DATA I Bit # OD (In) 1 17.500 MFR Hughes MOTOR DATA I Run # OD (in) 1 8.000 MFR SSDS COMPONENT DATA Item Description # 1 2 3 4 5 6 7 8 9 10 Hughes Milltooth 8" SperryDrill Lobe 6/7 - 4.0 stg Float Sub Sleeve Type Stabilizer Non-Mag UaHO Sub Non-Mag Cross Over Sub 7x Spiral Drill collar Cross Over Sub Drilling Jar 19 x HWDP TVD In (ft) : 0 Style GTX-C1 Model SperryDrill Serial # 6027732 800326 0441 77009 2598 67571 Kuukpik Kuup #1 15161079 Operator: Forest Oil Well: West Foreland #2 Field: West McArthur River Unit Location: AK-MJ-0003281390 Rig: Kuukpik #5 Job #: AK-MJ-0003281390 BHA# 1 DateOut09/21/20Q.lMDOut(ft): 3003 TVDOut(ft): 3001 Serial# 6027732 Nozzles (/32'$) TFA (in2) Dull Condition 3x18,1x14 0.896 2-3-WT-A-F-3-ER-TD Serial# 800326 NzI (/32'$) Avg DII (psi) Cum Clrc Hrs I 120 83,59 Bend 1.15° OD ID Gauge Weight Top Con Length Bit - Center (In) (In) (In) (IbsIft) (ft) Blade (ft) 17.500 5.000 17 .500 752,80 P 6-5/8" Reg 1.40 8.000 5.250 17.250 97.54 a 6-518" H90 29,23 4.03 8.000 2.813 150,12 a 6-5/8" H90 2.22 8.000 2.813 17.312 150.12 a 6-5/8" H90 5.88 34.60 8.000 2,875 149.18 a 6-5/8" H90 2.99 8,020 3.250 143.89 a 6-5/8" Reg 1.38 8.000 2.810 150.00 a 6-5/8" Reg 209.68 8,030 2.813 151.41 a 4-1/2" XH 1,31 6.140 2.750 80.67 a 4-1/2" XH 30.47 5.000 3.000 49.30 a 4-1/2"XH 575.51 860.07 Parameter Min Max Ave Activity Hrs aHA Weight (Ib) Drill String OD(in) Len(ft) WOB (klbs) 2 28 13 Drilling: 47.17 In Air (Total) 68247 DP(S)-NC50(IF)-16.60# 4.500 2143 RPM (rpm) 60 90 86 Reaming: 0.00 In Mud (Total) 58677 Flow (gpm) 460 750 588 Clrc-Other : 36.42 In Air (Bel Jars) : 37416 SPP (psi) 320 3450 1345 Total: 83.59 in Mud (Bel Jars: : 32169 PERFORMANCE I In Out Distance (ft) ROP (ftlhr) Build (°/100') Tum (°1100') DLS (°/100') Inclination (deg) 0.00 2.01 Oriented : 509.00 70 Azimuth (deg) 0.00 70.61 Rotated : 2494.00 62 Total: 3003.00 64 0.07 0.00 0.07 COMMENTS · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · sper'r'\{-sun CRILL-INti seRVices Operator: Forest Oil Well: West Foreland #2 Field: West McArthur River Unit Location: AK-MJ-0003281390 Rig: Kuukpik #5 Job #: AK-MJ-0003281390 BHA# 2 BHA Report BHA# 2 : Date In :09/25/20C MD In (ft) : 3003 TVD In (ft) : 3001 Date Out 09/26/20~MD Out (ft): 3023 TVD Out(ft): 3021 BIT DATA I Bit # OD (in) 2 12.250 MOTOR DATA I Run #I OD (in) 2 MFR Hughes Style Serial# Nozzles (/32's) TFA (in") Dull Condition GTX-1 ZL V62Dv 3x20 0.920 Model Serial# Bend Nzl (/32's) Avg Dif (psi) Cum Circ Hrs I Serial OD ID Gauge Weight Top Con Length Bit· Center #I (In) (in) (In) (lbsIft) (ft) Blade (ft) ZLV62Dv 12.250 4.000 12.250 358.84 P 6-5/8" Reg 0.98 503.63 8.000 2.750 151.06 B 6-5/8" Reg 3.02 Kuup #1 8.030 2.813 151.41 B 4-112" XH 1.31 15161079 6.140 2.750 80.67 B 4-112" XH 30.47 4.500 2.750 41.00 B 4-1/2"XH 575.51 611.29 MFR COMPONENT DATA Item Description #I 1 2 3 4 5 Milltooth Bit Sub Cross Over Sub Drilling Jar 19x HWDP Parameter Min Max Ave Activity Hrs BHA Weight (Ib) Drill String OD(ln) Len (ft) WOB (klbS) 2 2 2 Drilling: 0.50 in Air (Total) 27060 DP{S)-NC50(IF)-16.60# 4.500 2412 RPM (rpm) 55 55 55 Reaming: 0.00 in Mud (Total) 23266 Flow (gpm) 560 560 560 Circ-Other : 10.75 in Air (Bel Jars) : 1006 SPP (psi) 2540 2540 2540 Total: 11.25 In Mud (Bel Jars : 865 PERFORMANCE I In Out Distance (ft) ROP (ftlhr) Build (°/100') Turn (°/100') DLS (°/100') Inclination (deg) 2.01 2.05 Oriented : 0,00 0 AzImuth (deg) 70.61 70.72 Rotated : 20.00 40 Total: 20.00 40 O.HI 0.53 0.18 COMMENTS Float in bit sub · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Operator: Forest Oil Well: West Foreland #2 Field: West McArthur River Unit Location: AK-MJ-0003281390 Rig: Kuukpik #5 Job #: AK-MJ-0003281390 5pE!~~V-5Un CRI L..L..I N 13 SERVICES BHA Report BHA# 3 BHA# 3 : Date In :09/26/20C MD In (ft) : 3023 TVD In(ft) : 3021 Date Out 1 0/04/2()().1MD ()ut (ft): 6183 TVD Out(ft): 6173 BIT DATA I Bit # OD (in) MFR Style Serlal# 3 9.875 Hughes HCM605 7102697 MOTOR DATA I Run # OD (in) MFR Model Serlal# 2 7.000 SSDS SperryDrill 700034 COMPONENT DATA Item Description Serial OD ID # # (in) (in) 1 PDC 7102697 9.875 3.000 2 7" SperryDril1 Lobe 7/8 - 6.0 stg 700034 7.000 4.753 3 Non-Mag Float Sub 0848 6.670 2.875 4 Integral Blade Stabilizer 2387 6.740 2.813 5 Non-Mag Flex Pony collar 172609 6.750 2.813 6 6-3/4" HOC 143792 6.750 2.875 7 1x Non-Mag Flex Drill Collar 172598 6.630 2.813 8 1x Non-Mag Flex Drill Collar 184656 6.650 2.875 9 1x Non-Mag Flex Drill Collar 192425 6.540 2.813 10 Integral Blade Stabilizer 2388 7.770 2.813 11 Cross Over Sub ku 6.230 3.000 12 4 x HWDP 4.500 2.750 13 Drilling Jar 15161079 6.140 2,750 14 15 x HWDP 4.500 2.750 Gauge (In) 9.875 9.750 9.875 9.813 Nozzles (/32's)1 TFA (in2) Dull Condition 2x12,5x13 0.869 1-1-CT-A -X-I-NO-RIG Bend 1.22° Nzl 11/32's) Avg Dif (psi) Cum Circ Hrs I 146 131.25 Weight Top Con Length Bit - Center (IbsIft) (ft) Blade (ft) 236.92~ P 6-5/8" Reg 1.00 70.651 B 4-112" IF 25.32 3.28 96.9€' B 4-1/2" IF 1.45 100.41 B 4-1/2" IF 5.55 30.67 101.0CI B 4-1/2" IF 15.23 99.8~' B 4-112" IF 9.95 96.41:, B 4-1/2" IF 31.07 96.2.11. 84-112" IF 31.06 93.3CI 84-1/2" IF 31.09 140.42~ 84-112" IF 5.59 154.72 79,80 8 4-112" XH 1.10 41.OCI B 4-112" XH 121.93 SO.67' 84-1/2" XH 30.47 41,OCI B 4-112" XH 453.58 764.39 Parameter Min Max Ave Activity Hrs BHA Weight (Ib) ~111 String OD(in) Len (ft) WOB (klbs) 2 12 4 Drilling: 63.59 in Air (Total) 41070 DP'(S)-NC50(IF)-16.60# 4.500 5419 RPM (rpm) 50 60 56 Reaming: 1.50 in Mud (Total) 34936 Flow (gpm) 555 570 563 Circ-Other: 66.16 in Air (Bel Jars) : 20016 SPP (psi) 2500 3220 2718 Total: 131.25 in Mud (Bel Jars: : 17026 PERFORMANCE I Inclination (deg) Azimuth (deg) In Out 2.05 13.10 70.72 346,92 Oriented : Rotated : Total: Distance(ft) 452,00 2708.00 3160.00 COMMENTS Revs/Gal = .33 ROP (ftlhr) 34 52 50 Build ("/100') Turn (°/100') DLS (°/100') 0.3:5 -2.65 0.41 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Operator: Forest Oil Well: West Foreland #2 Field: West McArthur River Unit Location: AK-MJ-0003281390 Rig: Kuukpik #5 Job #: AK-MJ-0003281390 SpSr'r'y-sun CRI LL.I N G SERVICES BHA Report BHA# 4 BHA# 4 Date In :10/04/2OC MD In (ft) : 6183 TVD In (ft) : 6173 Date Out 10/16120~MD Out (ft): 8277 TVD Out(ft): 7834 BIT DATA I Bit # OD (in) MFR Style Serial# 3rr1 9.875 Hughes HCM605 7102697 MOTOR DATA I Run # OD (in) MFR Model Serial# 3 7.000 SSDS SperryDrill 700034 COMPONENT DATA Item Description Serial OD ID # # (in) (in) 1 PDC 7102697 9.875 3.000 2 7" SperryDrill Lobe 7/8 - 6.0 stg 700034 7.000 4.753 3 Non-Mag Float Sub 0848 6,670 2.875 4 Non-Mag Flex Pony collar 172609 6.750 2.813 5 6-314" HOC 143792 6.750 2.875 6 1x Non-Mag Flex Drill Collar 172598 6.630 2.813 7 1x Non-Mag Flex Drill Collar 184656 6.650 2.875 8 1 x Non-Mag Flex Drill Collar 192425 6.540 2.813 9 Integral Blade Stabilizer 2388 7.770 2.813 10 Cross Over Sub ku 6.230 3.000 11 4 x HWDP 4.500 2.750 12 Drilling Jar 15161079 6.140 2.750 13 15 x HWDP 4.500 2,750 Gauge (in) 9.875 9.750 9.813 Nozzles (132's) TFA (in2) Dull Condition I 2x12,5x13 0.869 2-4-CT-A -X-4-WT-BHA Bend 1.22° Nzl (132's) Avg Dif (psi) Cum Circ Hrs I 194 266.58 Weight Top Con Length Bit - Center (1bs1ft) (ft) Blade (ft) 236.92 P 6-5/8" Reg 1.00 70.69 B 4-1/2" IF 25.32 3.28 96.96 B 4-1/2" IF 1.45 101.00 B 4-112" IF 15.23 99.83 B 4-112" IF 9.95 96.48 B 4-112" IF 31.07 96.24 B 4-1/2" IF 31.06 93.30 B 4-1/2" IF 31.09 140.42 B 4-1/2" IF 5.59 149.17 79.80 B 4-112" XH 1.10 41.00 B 4-1/2" XH 121.93 80.67 B 4-112" XH 30.47 41.00 B 4-1/2" XH 453.58 758.84 Parameter Min Max Ave Activity Hrs BHA Weight (Ib) Drill String OD(in) Len (ft) WOB (klbs) 5 18 11 Drilling: 67.33 in Air (Total) 40513 DP(S)-NC50(IF)-16.60# 4.500 7518 RPM (rpm) 60 60 60 Reaming: 3.50 in Mud (Total) 34523 Flow (gpm) 500 560 525 Circ-Other: 64.50 In Air (Bel Jars) : 19458 SPP (psi) 2850 3500 3149 Total: 135.33 in Mud (Bel Jars: : 16582 PERFORMANCE I Inclination (deg) Azimuth (deg) In Out 13.10 47.12 346,92 348.61 Distance(ft) 1196.00 898.00 2094.00 Oriented : Rotated : Total: COMMENTS Revs/Gal = .33 Bit/Dir = 43.27 ROP (ftlhr) 20 47 31 Build (°1100') Tum (°/100') DLS (°1100') 1.62 1.63 0.08 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Operator: Forest Oil Well: West Foreland #2 Field: West McArthur River Unit location: AK-MJ-0003281390 Rig: Kuukpik #5 Job #: AK-MJ-0003281390 sper-r-\l-sun CRIL.L.ING SERVICES BHA Report BHA# 5 BHA# 5 : Date In : 1 0/16/20C MD In (ft) : 8277 TVD In (ft) : 7834 Date Out 1 0/18120Q4 MD Out (ft): 8677 TVD Out (ft): 8085 BIT DATA I Blt# OD (In) MFR Style Serlal# 4 9.875 Security FS2653 5013150 MOTOR DATA I Run # OD (in) MFR Model Serial# 4 7,000 SSDS SperryDrill 700025 COMPONENT DATA Item Description Serial OD ID # # (In) (In) 1 PDC 5013150 9.875 3.000 2 Bit Sub 0445 8.060 2.250 3 7" SperryDrill Lobe 7/8 - 6.0 stg 700025 7.000 4.753 4 Non-Mag Float Sub 0848 6.670 2.875 5 Non-Mag Flex Pony collar 172609 6.750 2.813 6 6-3/4" HOC 143792 6.750 2,875 7 1x Non-Mag Flex Drill Collar 172598 6.630 2.813 8 1 x Non-Mag Flex Drill Collar 184656 6.650 2.875 9 1 x Non-Mag Flex Drill Collar 192425 6.540 2.813 10 Welded Blade Stabilizer 192461 6.900 2.813 11 Cross Over Sub ku 6.230 3.000 12 4 x HWDP 4.500 2.750 13 Drilling Jar 15061082 6.180 2.750 14 15 x HWDP 4.500 2.750 Gauge (In) 9.875 9.750 8.375 Nozzles (132's) TFA (In2) Dull Condition 6x14 0.902 1-1-ER-A -X-I-NO-DTF Bend 1.50° Nzl (132's) Avg Dif (psi) Cum Circ Hrs I 229 29.25 Weight Top Con Length Bit - Center (Ibs/ft) (ft) Blade (ft) 236.92 P 6-5/8" Reg 1.14 160.33 P 4-1/2" Reg 1.00 70.69 B 4-1/2" IF 24.99 4.14 96.96 B 4-1/2" IF 1.45 101.00 B 4-1/2" IF 15.23 99.83 B 4-1/2" IF 9.95 96.48 B 4-1/2" IF 31.07 96.24 B 4-1/2" IF 31.06 93.30 B 4-112" IF 31.09 106.25 B 4-112" IF 5.62 149.48 79.80 B 4-1/2" XH 1.10 41.00 B 4-1/2" XH 121,93 81.99 B 4-112" XH 30,08 41.00 B 4-112" XH 453.58 759.29 Parameter Min Max Ave Activity Hrs BHA Weight (Ib) Drill String OD(in) Len (ft) WOB (klbs) 5 10 9 Drilling : 11.75 in Air (Total) 40504 DP(S)-NC50(IF)-16.60# 4.500 7918 RPM (rpm) 60 60 60 Reaming: 1.00 In Mud (Total) 34515 Flow (gpm) 440 500 484 Clrc-other : 16.50 in Air (Bel Jars) : 19441 SPP (psi) 3200 3300 3256 Total: 29.25 in Mud (Bel Jars: : 16567 PERFORMANCE I Inclination (deg) Azimuth (deg) In 47.12 348.61 Dlstance(ft) 78.00 322.00 400.00 Out 52.66 352.69 Oriented : Rotated : Total: COMMENTS Revs/Gal = .33 Dir = 44.08 ROP (ftIhr) 11 40 34 Build (°/100') Turn (°/100') DLS (°/100') 1.38 1.02 1.59 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Operator: Forest Oil Well: West Foreland #2 Field: West McArthur River Unit Location: AK-MJ-0003281390 Rig: Kuukpik #5 Job # : AK-MJ-0003281390 sper'r'y-sun CFU L..L..I N G SEAV I c: E 5 BHA Report BHA# 6 BHAII 6 : Date In 101 18/20C MD In (ft) : 8677 TVD In (ft) : 8085 Date Out 1 0/21 1200tMD Out (ft): 9430 TVD Out(ft): 8624 BIT DATA I Bit # OD (In) MFR Style Serial# 4rr1 9.875 Security FS2653 5013150 MOTOR DATA I Run # OD (In) MFR Model Serial# 5 7.000 SSDS SperryDrill 700055 COMPONENT DATA Item Description Serial OD ID # # (in) (In) 1 PDC 5013150 9.875 3.000 2 Bit Sub 0445 8.060 2.250 3 7" SperryDrill Lobe 7/8 - 6.0 stg 700055 7.000 4.753 4 Non-Mag Float Sub 0848 6.670 2.875 5 Non-Mag Flex Pony collar 172609 6.750 2.813 6 6-3/4" HOC 143792 6.750 2.875 7 1x Non-Mag Flex Drill Collar 172598 6.630 2.813 8 1x Non-Mag Flex Drill Collar 184656 6.650 2,875 9 1x Non-Mag Flex Drill Collar 192425 6.540 2.813 10 Welded Blade Stabilizer 192461 6.900 2.813 11 Cross Over Sub ku 6.230 3.000 12 4 x HWDP 4.500 2.750 13 Drilling Jar 15061082 6.180 2.750 14 15 x HWDP 4.500 2.750 Gauge (In) 9.875 9.750 8,375 Nozzles (/32's) TFA (In2) Dull Condition 6x14 0.902 2-3-BT-A -X-3-LT-PR Bend 1.50° Nz! (/32's) Avg DIf (psi) Cum Clrc Hrs I 277 55.33 Weight Top Con Length Bit - Center (lbsIft) (ft) Blade (ft) 236,92 P 6-5/8" Reg 1.14 160.33 P 4-112" Reg 1.00 70.69 B 4-1/2" IF 24.68 4.14 96.96 B 4-1/2" IF 1.45 101.00 B 4-1/2" IF 15.23 99.83 B 4-1/2" IF 9.95 96.48 B 4-1/2" IF 31.07 96,24 B 4-1/2" IF 31,06 93.30 B 4-1/2" IF 31.09 106,25 B 4-1/2" IF 5.62 149.17 79.80 B 4-1/2" XH 1.10 41.00 B 4-1/2" XH 121.93 81,99 B 4-1/2" XH 30.08 41.00 B 4-1/2" XH 453.58 758.98 Parameter Min Max Ave Activity Hrs BHA Weight (Ib) Drill String OD(in) Len (ft) WOB (klbs) 8 10 9 Drilling: 26.91 in Air (Total) 40482 DP(S)-NC5O(IF)-16.60# 4.500 8671 RPM (rpm) 60 60 60 Reaming: 0.25 in Mud (Total) 34312 Flow (gpm) 430 500 486 Circ-Other : 28.17 in Air (Bel Jars) : 19419 SPP (psi) 3000 3500 3355 Total: 55.33 In Mud (Bel Jars: : 16459 PERFORMANCE I Inclination (deg) Azimuth (deg) In Out 52.66 39.90 352.69 352.86 Distance(ft) 350.00 403.00 753.00 Oriented : Rotated : Total: COMMENTS Revs IGal = .33 Dir = 43.77 ROP (ftlhr) 13 41 28 Build (°/100') Turn (°/100') DLS (°/100') -1.69 0.02 1.69 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Operator: Forest Oil Well: West Foreland #2 Field: West McArthur River Unit Location: AK-MJ-0003281390 Rig: Kuukpik #5 Job #: AK-MJ-0003281390 sper'r'y-sun CRILLI NG SERVIC:ES BHA Report BHA# 7 BHA# 7 : Date In :10/21/20C MD In (ft) : 9430 TVD In (ft) : 8624 Date Out 10/24/2(().(MD Out (ft): 9930 TVD Out(ft): 8962 BIT DATA I Bitt OD (In) MFR Style Serial# 5 9.875 Hughes MX-20 5052355 MOTOR DATA I Run# OD (in) MFR Model Serial# 6 7.000 SSDS SperryDrill 700055 COMPONENT DATA Item Description Serial OD ID # # (In) (in) 1 Roller Cone Insert 5052355 9.875 3.000 2 Bit Sub 0445 8.060 2.250 3 7" SperryDrill Lobe 7/8 - 6.0 stg 700055 7.000 4.753 4 Non-Mag Float Sub 0848 6.670 2.875 5 Non-Mag Flex Pony collar 172609 6.750 2.813 6 6-314" HOC 143792 6.750 2.875 7 1x Non-Mag Flex Drill Collar 172598 6.630 2.813 8 1x Non-Mag Flex Drill Collar 184656 6,650 2.875 9 1x Non-Mag Flex Drill Collar 192425 6.540 2.813 10 Welded Blade Stabilizer 192461 6.900 2.813 11 Cross Over Sub ku 6.230 3.000 12 4 x HWDP 4.500 2.750 13 Drilling Jar 15061082 6.180 2.750 14 15x HWDP 4.500 2.750 Nozzles (/32's) TFA (in') Dull Condition 3x22 1.114 3-3-BT -A -E-2-ER-RIG Bend 1.50· Nzl (/32's) Avg Dlf (psi) Cum Clrc Hrs I 174 93,08 Gauge (In) 9.875 Weight Top Con Length Bit - Center (lbsIft) (ft) Blade (ft) 236.92 P 6-5/8" Reg 0.85 160.33 P 4-112" Reg 1.00 70.69 B 4-1/2" IF 24.68 3.85 96.96 B 4-1/2" IF 1.45 101.00 B 4-1/2" IF 15.23 99.83 B 4-1/2" IF 9.95 96.48 B 4-112" IF 31.07 96.24 B 4-1/2" IF 31.06 93.30 B 4-1/2" IF 31,09 106.25 B 4-1/2" IF 5.62 148.88 79.80 B 4-1/2" XH 1.10 41.00 B 4-1/2" XH 121.93 81.99 B 4-1/2" XH 30,08 41.00 B 4-1/2" XH 453.58 758.69 9.750 8.375 Parameter Mln Max Ave Activity Hrs BHA Weight (Ib) Drill String OD(ln) Len (ft) WOB (klbs) 8 28 20 Drilling: 20.75 In Air (Total) 40413 DP(S)-NC50(IF)-16.60# 4.500 9171 RPM (rpm) 60 80 77 Reaming: 7.00 in Mud (Total) 34253 Flow (gpm) 500 500 500 Clrc-Other : 10.00 in Air (Bel Jars) : 19350 SPP (psi) 3050 3300 3256 Total: 37.75 In Mud (Bel Jars: : 16401 PERFORMANCE I In Out DIstance(ft) ROP (ftlhr) Build (°/100') Tum (°/100') DLS (°/100') Inclination (deg) 39,90 50.51 Oriented : 86.00 19 Azimuth (deg) 352.86 355.35 Rotated : 414.00 25 Total: 500.00 24 2.12 0.50 2.15 COMMENTS · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Operator: Forest Oil Well: West Foreland #2 Field: West McArthur River Unit Location: AK-MJ-0003281390 Rig: Kuukpik #5 Job #: AK-MJ-0003281390 SpSr'r'v-sun CRILLING SERVICES BHA Report BHA# 8 BHA# 8 : Date In .10/24/2OC MD In (ft) : 9930 TVD In (ft) : 8962 Date Out 1 0130120Q.t MD Out (ft): 10717 TVD Out (ft): 9457 BIT DATA I BiU OD (In) MFR Style Serial# 6 9.875 Hughes MX-518 5052355 MOTOR DATA I Run # OD (in) MFR Model Serial# 7 7.000 SSDS SperryDrllI 700055 COMPONENT DATA Item Description Serial OD ID # # (In) (In) 1 Roller Cone Insert 5052355 9.875 3.000 2 8itSub 0445 8.060 2.250 3 7" SperryDrlII Lobe 7/8 - 6.0 stg 700055 7.000 4.753 4 Non-Mag Float Sub 0848 6.670 2.875 5 Non-Mag Flex Pony collar 172609 6.750 2.813 6 6-3/4" HOC 143792 6.750 2.875 7 1x Non-Mag Flex Drill Collar 172598 6.630 2.813 8 1x Non-Mag Flex Drill Collar 184656 6.650 2.875 9 1x Non-Mag Flex Drill Collar 192425 6.540 2.813 10 Welded 81ade Stabilizer 192461 6.900 2.813 11 Cross Over Sub ku 6.230 3.000 12 4 x HWDP 4.500 2.750 13 Drilling Jar 15061082 6.180 2.750 14 15 x HWDP 4.500 2.750 Nozzles (/32's) TFA (In2) Dull Condition 3x22 1.114 2-3-8T-0 -E-1-L T-LOG Bend 1.50° NzI (/32's) Avg Dif (psi) Cum Clrc Hrs I 209 182.51 Gauge (in) 9.875 Weight Top Con Length Bit· Center (lbsIft) (ft) Blade (ft) 236.92 P 6-518" Reg 0.85 160.33 P 4-1/2" Reg 1.00 70.69 84-1/2" IF 24.68 3.85 96.96 B 4-lIZ'IF 1.45 101.00 84-1/2" IF 15.23 99.83 B 4-1/2" IF 9.95 96.48 84-1/2" IF 31.07 96.24 8 4-1/2" IF 31.06 93.30 B 4-112" IF 31.09 106.25 B 4-112" IF 5,62 148.88 79.80 B 4-1/2" XH 1.10 41.00 B 4-1/2" XH 121.93 81.99 B 4-1/2" XH 30.08 41.00 8 4-112" XH 453.58 758.69 9.750 8.375 Parameter Mln Max Ave Activity Hrs BHA Weight (Ib) Drill String OD(in) Len (ft) WOB (klbs) 28 28 28 Drilling : 43.01 In Air (Total) 40413 DP(S)-NC50(IF)-16.6O# 4.500 9958 RPM (rpm) 80 80 80 Reaming : 3.50 in Mud (Total) 34253 Flow (gpm) 500 500 500 Circ..()ther: 42.92 in Air (Bel Jars) : 19350 SPP (psi) 3050 3500 3464 Total: 89.43 in Mud (Bel Jars: : 16401 PERFORMANCE I In Out Distance(ft) ROP (ftlhr) Build (°/100') Turn (°/100') DLS (°/100') Inclination (deg) 50.51 53.59 Oriented : 217.00 10 Azimuth (deg) 355.35 358.84 Rotated : 570.00 21 Total: 787.00 18 0.39 0.44 0.53 COMMENTS Operator: Forest Oil Well: West Foreland #2 Field: West McArthur River Unit Location: AK~MJ-0003281390 Rig: Kuukpik #5 Job #: AK-MJ-0003281390 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · 5pE!~~V-5Un CAI LLI N G SEAVI C:E 5 BHA Report BHA# 12: Date In. BIT DATA I Bit # OD (in) MD In (ft) : TVD In (ft) Date Out MFR Style Serial# MOTOR DATA I Run # OD (in) MFR Model Serial# COMPONENT DATA Item Description # 1 2 3 4 5 6 7 8 9 10 11 Serial OD ID # (in) (in) 255718 8.020 2.750 38376 8.090 2,810 3706 6.720 2.810 172598 6.630 2.813 184656 6.650 2.875 192425 6.540 2.813 192461 6.900 2.813 ku 6.230 3.000 4.500 2.750 15061082 6.180 2.750 4.500 2,750 Hole Opener (4x 20's) Bit Sub wlFloat Cross Over Sub 1x Non-Mag Flex Drill Collar 1x Non-Mag Flex Drill Collar 1x Non-Mag Flex Drill Collar Welded Blade Stabilizer Cross Over Sub 5 x HWDP Drilling Jar 15xHWDP MD Out (ft) : 12 (Proposed) TVD Out (ft) : Nozzles (/32's) TFA (in2) Dull Condition Gauge (in) 9.875 8.375 Bend Nzl (/32's) Avg Dif (psi) Cum Circ Hrs I Weight (Ibslft) 151.92 154.05 99.74 96.48 96.24 93.30 106.25 79.80 41.00 81.99 41.00 Top Con P 6-5/8" Reg B 6-5/8" H90 B 4-112" IF B 4-112" IF B 4-1/2" IF B 4-1/2" IF B 4-1/2" IF B 4-112" XH B 4-1/2" XH B 4-112" XH B 4-112" XH Length Bit - Center (ft) Blade (ft) 8.05 2.83 3.05 31.07 31.06 31,09 5.62 109.65 1.10 151.78 30.08 453.58 749.31 Parameter Min Max Ave Activity Hrs BHA Weight (Ib) Drill String OD(in) Len (ft) WOB (klbs) Drilling : in Air (Total) 38822 DP(S)-NC50(IF)-16.60# 4.500 RPM (rpm) Reaming: in Mud (Total) Flow (gpm) Circ-Other : in Air (Bel Jars) : 17759 SPP (psi) Total: 0.00 in Mud (Bel Jars: : PERFORMANCE In Out Distance(ft) ROP (ftlhr) Build (°/100') Tum (°/100') DLS (°/100') Inclination (deg) Oriented : Azimuth (deg) Rotated : Total: COMMENTS DgAJ 1289~ cd!. 1 i st Ó(OC('- (Yi DN i~ volume in drive D is Forestoil_WF#2 volume serial Number is 115F-94E4 Directory of D:\ 01/11/2005 02:55 PM 01/12/2005 03:24 PM <DIR> 01/12/2005 03:26 PM <DIR> 01/12/2005 03:24 PM <DIR> 01/12/2005 03:23 PM <DIR> 1 File(s) 118,272 completionsummary_DrillingReports.doc Formation water Analysis Gas Analysis Gas well Test PBU Data 118,272 bytes Directory of D:\Formation Water Analysis 01/12/2005 01/12/2005 01/04/2005 12/21/2004 03:24 PM 03:24 PM 10:36 AM 01:10 PM 2 File(s) <DIR> <DIR> Directory of D:\Gas Analysis 01/12/2005 03:26 PM <DIR> 01/12/2005 03:26 PM <DIR> 12/14/2004 05:54 PM 12/14/2004 05:54 PM 12/14/2004 05:54 PM 12/14/2004 05:54 PM 4 File(s) Directory of D:\Gas well Test 01/12/2005 03:24 PM <DIR> 01/12/2005 03:24 PM <DIR> 01/06/2005 02:54 PM 01/06/2005 02:41 PM 01/03/2005 11:44 AM 12-17-04.pdf 01/06/2005 05:08 PM 4 File(s) Directory of D:\PBU Data 01/12/2005 03:23 PM 01/12/2005 03:23 PM 01/11/2005 04:59 PM 1 File(s) 22,528 10725-60' west Foreland #2 water Analysis.doc 1,048,942 10725-60' west Forland #2 Water Analysis.pdf 1,071,470 bytes 42,538 8500 sample #3.pdf 42,766 8500 sample #4.pdf 43,538 9200 Lower sample#2.pdf 42,836 9200 sample #1.pdf 171,678 bytes 58,368 AOGCC 10-421 WF#2 Lower (wF#I-9200TVDSS).xls 59,392 AOGCC 10-421 wF#2 upper (WF#2-8500MD).xls 936,373 Forw.Forelands #2 - Gas Test 11-24 - 31,744 summary of WF#2 Testing.doc 1,085,877 bytes <DIR> <DIR> 6,280,704 WFU # 2 SRT Pressure DataI2-12-2004.xls 6,280,704 bytes Total Files Listed: 12 File(s) 12 Dir(s) 8,728,001 bytes o bytes free page 1 volume in drive D is ForestOil_WF#2 volume serial Number is 6825-3C33 Directory of D:\ J)5JJ J 2. f? (, 11/06/2004 03:27 PM 11/06/2004 03:27 PM 11/06/2004 06:30 PM 11/06/2004 06:02 PM 11/06/2004 06:02 PM 11/23/2004 12:10 PM 11/06/2004 06:24 PM 11/06/2004 06:28 PM 11/23/2004 12:10 PM 11/06/2004 06:14 PM 11/06/2004 06:27 PM 11/06/2004 06:22 PM 11/06/2004 06:28 PM 11/07/2004 07:12 AM 11/06/2004 06:27 PM 11/06/2004 06:16 PM 01/12/2005 08:42 AM 01/12/2005 10:15 AM 12/03/2004 11:20 AM 01/12/2005 11:09 AM 12/27/2004 12:45 PM 10/30/2004 10:02 AM 22 File(s) Total Files Listed: 22 File(s) o Di res) ;;?tJ f~ (13 cd2.list (") ('W] U (j t;V Inl 157,067,604 AIT_DSI_TLD_MCFL_002PUP.DLIS 5,120 AIT_DSI_TLD_MCFL_002pUP.DLIS.FMA 2,490,472 AIT_DSI_TLD_MCFL_002pup.las 25,025,664 AIT_DSI_TLD_MCFL_013PUP.DLIS 5,120 AIT_DSI_TLD_MCFL_013puP.DLIS.FMA 16,846,748 combined_CBL.PDS 260,750 CombinedNGTTvD.PDS 4,096 combinedNGTTvD.PDS.FMA 4,096 combined_CBL.PDS.FMA 2,891,003 CombinedDsI.PDS 4,096 CombinedDsI.PDS.FMA 1,949,114 CombinedDsITVD.PDS 4,096 CombinedDSITvD.PDS.FMA 9,973,134 combinedMDT.PDS 4,096 CombinedNGT.PDS.FMA 346,776 combinedNGT.PDS 6,896,168 Final_Quad_TvD.pds 6,937,088 Final_Quad_MD.pds 6,234,579 westForeland2_Final_Log_Data.las 15,093 WF#2_dirsurvey.dat 79,521 WF#2_dirsurvey.pdf 6,004,188 wf2_run1AIT_DSI_TLD_MCFL_008PUP.las 243,048,622 bytes 243,048,622 bytes o bytes free Page 1