Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
204-259
· . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ Q Lt - a§ -9 Well History File Identifier o Two-sided 1111111111111111111 Production Scanning Stage 1 Page Count from Scanned File: ~5 .3 (Count does include cover sheet) Page Count Matches Number in scan~rg Prep'aration: ¿ YES BY ~ Da,eSjtJ-q/07 Stage 1 If NO in stage 1, page(s) discrepancies were found: Organizing (done) RjSCAN \6 Color Items: if Greyscale Items: o Poor Quality Originals: DIGITAL DATA ~kettes, No.\ o Other, NolType: o Other: NOTES: DateSI d-.1/0 7 Date 0/8--1/D7 g BY: ~ Project Proofing BY: ~ Scanning Preparation BY: BY: Maria Date: Scanning is complete at this point unless rescanning is required. o Rescan Needed 11111111I1111111111 OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ~09S of various kinds: ~therß1~c-G f~p~ 151 rýY\ ,~IIIIIIIIIII~ 11111 mf + I d- = TOTAL PAGES d-.6 d- (Count does not include cover sheet) ¥J 151 , 11111111111111 "'II NO YES 151 mp NO 151 1111111111111111111 ReScanned BY: Maria Date: 1111111111111111111 Comments about this file: 1111111111111111111 151 Quality Checked 10/6/2005 Well History File Cover Page.doc • ~f~~- ~~ M1CR~FILMED 0 3/01 /2008 • ~. :_ DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\CvrPgs_InsertstMicrofilm Marker.d~oc ~ ~ - (Vta."1 DATA SUBMITTAL COMPLIANCE REPORT 5/2/2007 Sp¿ 7 ~~..tt6 ,- Permit to Drill 2042590 Well Name/No. KOKODA 5 Operator CONOCOPHILLlPS ALASKA INC API No. 50-279-20012-00-00 ~~---~-- MD 11122 -- TVD 10301"--- Completion Date 4/25/2005 .-- Completion Status P&A Current Status P&A UIC N REQUIRED INFORMATION M"~_ Samples No Directiona~ S~ ~~-_.,---- DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Newtron/Density Well Log Information: Log/ Data Digital Type Med/Frmt ~ j~ .~ ~CPdt I I I I Directional Survey 0 11122 Open Directional Survey 0 11122 Open Lis 13179 I nd uction/Resistivity 107 11122 Open ~/~ Density Mb ~ 'tIlD l-e¡ ) 25 Col 107 10300 Open J.e( Sonic M~ ~~ìV'~~ç 25 Col 107 11122 Open I nd uction/Resistivity /V)Ò Ov-..J. 'tV 6 ~), 25 Col 107 11122 Open ~ See Notes 6760 11055 Open ~- See Notes 500 11070 ~--- ~-'--'---'----~-_. (data taken from Logs Portion of Master Well Data Maint Electr Dataset Number Name Mud Log See Notes See Notes Report: Final Well R For~lma ~ (~'1 ForllkttiulI Micro Ima Mu& k¢ 1 See Notes 13123 Report: Final Well R e Log Log Run Interval OHI Scale Media No Start Stop CH 2 Col 108 11122 Open 2 Col 108 11122 Open 2 Col 108 11122 Open 0 0 Open Received Comments 6/23/2005 LWD Combo Log 6/23/2005 Gas Ratio Log 6/23/2005 Pore Pressure Log - --------¡ 6/23/2005 formation log,drilling dynamics, gas ration logs formation log-MD formation log-MD Drilling Dynamics Log DML Data, Final Well Report, LAS Data, Morning Reports, PDF files, remarks file 2 Col 108 11122 Open 6/23/2005 2 Col 108 11122 Open 6/23/2005 2 Col 108 11122 Open 6/23/2005 0 0 Open 6/24/2005 -- BAT EWR POR GR plus graphics .emf & .pdf Thermal Neutron Porosity, Stabalilzed Litho-Density, DGR, Acoustic Caliper Bi-Modal Acoustic DGR DGR, EWR, ROP Biostratigraphic Synthesis MGIL Analysis .( DATA SUBMITTAL COMPLIANCE REPORT 5/2/2007 Permit to Drill 2042590 Well Name/No. KOKODA 5 Operator CONOCOPHILLlPS ALASKA INC API No. 50-279-20012-00-00 MD 11122 TVD 10301 Completion Date 4/25/2005 Completion Status P&A Current Status P&A UIC N Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments i i 1_ Cores and/or Samples are required to be 1 submitted. This record automatically created I from Permit to Drill Module on: 1/13/2005------J ADDITIONAL INFORM~~N Well Cored? vQ..r:!) Daily History Received? Qw ~/N e Chips Received? . V,' n-- Formation Tops Analysis Received? ~_. Comments: ~~-~'"'-,._._~._-- ftom Compliance Reviewed By: _ Date: tÀ>~ IfiJ ~? e e e ConocJ'Phillips TRANSMITTAL CONFIDENTIAL DA TA FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TO: Howard Okland State of Alaska - AOGCC 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Kokoda 5 Permit: 204-259 DATE: 5/25/2007 Hand deliver Kokoda 5, NPRA, Alaska 502792001200 Schlumberger (CD reqjstribution) reauested by AOGCC to replace missing CDROM digital data CD~ .. . ~ LDWG OH EDITS; Digital pdsvlews; Logged 4122J2oo5 -# /3/7; Please check off each item as received, promptly sign and return one of the two transmittals to address below. The other copy is for your records. To all data recipients: A/I data is confidential until State of Alaska designated AOGCC release date Data marked ro rieta is indefinite! confidential and is available onl to owners and artners CC: Greg Wilso ,CPAI Geologist 1 Date: ConocoPhillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage. AK 99501 Jv-1 ~ ~7 Receipt: Return re eipt to: GIS-Technical Data Management 1 ConocoPhillips 1 Anchorage/ Alaska 1 Ph: 907.265.69471 Sandra.D.Lem.ke(á)conocophillitJs.com ;\ Ú 'l-2 r-c¡ · . Conoc~illips TRANSMITTAL CONFIDENTIAL DA TA FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Kokoda 5 Permit: 204-259 DATE: 2/23/2006 TO: Celesta Tolley Nat Resources Tech 333 w. th Ave, Suite 100 Anchorage, Alaska 99501 Hand deliverv Transmitted: Kokoda 5, NPRA, Alaska 502792001200 Report VBiostratigraphic Synthesis of the ConocoPhillips Kokoda 5 Well (6760-11055' md); December 2005; the ifr group, inc. V"MGIL Analysis of the Kokoda 5 well, North Slope, Alaska; Terra Nova Tech.; LeRoy Ellis, January 20006 Please check off each item as received, promptly sign and return one of the two transmittals to address below. The other copy is for your records. To all data recipients: All data is confidential until State of Alaska designated AOGCC release date CC: Greg yvilson, çeAI Geologist / (\1\ Receipt: /_~; ¡,:t(ï¡CYVt ¡ t) , ~~J \-../ Date: ;}j ~81bG GI5- Technical Data Management I ConocoPhil/ips I Anchorage, Alaska I Phone: 907.265.6947 5andra.D.Lemke(ã)Conocoohillios.com ì? 1 ;1 i~ ¡¡ :~ .. 'w FRANK H. MURKOWSKI, GOVERNOR AI,ASKA OIL AlO) GAS CONSERVATION COJDIISSION ,; 333 W. T'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 December 29,2005 Paul Mazzolini ConocoPhillips Alaska Inc. POBox 100360 Anchorage, AK 99510 Re: Location Clearances Kokoda # 1 (PTO 204-253) Kokoda# 5 (PTD 204-259) Iapetus # 2 (prO 204-254) Dear Mr. Mazzolini: The Alaska Oil and Gas Conservation Commission ("AOGCC") has completed its location clearance inspection of the above reference wells. The AOGCC inspection shows the locations to be in compliance with 20 AAC 25.170, Onshore Location Clearance. The Commission requires no further work on the subject well or location. However, ConocoPhillips Alaska Inc. will remain liable if any problems should occur in the future with these wells. Final location clearance is hereby APPROVED for the above listed wells. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, -; "J ' P.I. Supervisor Kr?111(~~~ DATE: August 13, 2005 THRU: FROM: Chuck Scheve, Petroleum Inspector SUBJECT: Location Inspection Conoco Phillips #1 PTO 204-253 #2 PTO 204-254 Saturdav, Auaust 13. 2005; i made a Location Clearance Inspection of the Conoco Phillips exploratory wells Kokoda #1, Kokoda #5 and Iapetus #2. I was accompanied today by Chris Brown (Conoco environmental). The exploratory locations were clean with no evidence of past drilling activity other than a small mound of dirt over the cellar area of the two Kokoda Wells and a slight depression in the cellar area of the Iapetus Well SUMMARY: I made a Location Inspection of the Conoco Phillips abandoned Exploratory wells Kokoda #1, Kokoda #5 and Iapetus #2 Iapetus #2 I ..J2 -:;~ 2005-0813 _Location_Clear _lapetus2_ cs.doc · ~illips ~f-¿51 TRANSMITTAL CONFIDENTIAL DATA Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Kokoda 5 Permit: 204-259 DATE: 6/29/2005 Hand deliver TO: Helen Warman State of Alaska - AOGCC 333 w. J'h Avenue, Suite 100 Anchorage, Alaska 99501 Transmitted: Kokoda 5, NPRA, Alaska 502792001200 Epoch Mudloa hardcopy report &CDROM _ Kokoda #5 Epoch Final Well Report Mudlogging Data; includes color Formation 10g(MD), Formation Log (TVD), Drilling Dynamics, LWD Combo, Pore Pressure, and Gas Ration Log; CDROM contains reports, LAS data, PDF images and DML data; lithology remarks files, 4/10/2005. Please check off each item as received, promptly sign and return one of the two transmittals to address below. The other copy is for your records. To all data recipients: All data is confidential until State of Alaska designated AOGCC release date Data marked proDrietarv is indefinitelv confidential and is available onlv to owners and Dartners Date: ConocoPhillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 é/hðk- t ¡ GIS-Technical Data Management I ConocoPhillips I Anchorage¡ Alaska 1 Ph: 907.265.69471 Sandra. D. Lem, ke(éi)conoco/Jhilli/Js. com Revised surface location for Kokoda 5 . . Bob - The attached form shows the surface location for Kokoda 5 with the ASP coordinates in NAD27, zone 5. «Kokoda 5 rev surface.doc» Thanks, Sharon office phone: 263-4612 fax: 265-6224 5 rev Content-Description: Kokoda 5 rev surface.doc Content-Type: applicationlmsword Content-Encoding: base64 1 of 1 5/24/20057:20 AM Kokoda 5 revised TPI and BHL . . Bob - attached are the revised ASP coordinates for the top of the productive interval and bottom hole location for Kokoda 5 «Kokoda 5 rev TPl.doc» «Kokoda 5 BHL.doc» Thanks, Sharon office phone: 263-4612 fax: 265-6224 Content-Description: Kokoda 5 rev TPI.doc. 5 rev TPI.doc Content-Type: application/msword Content-Encoding: base64I Content-Description: Kokoda 5 BHL.doc 5 Content-Type: application/msword Content-Encoding: base64 1 of 1 5/24/2005 7: 17 AM Kokoda 5 - TPI . Conoc6Phillips . Paul Mazzolini Exploration Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4603 May 11, 2005 RECEIVED MAY .I 3 2005 Alaska ail &':' 'f' ÒlIS van" Com . . An"h .:>. .mlsSIClrt flu Drage Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for Kokoda 5 (204-259 I 305-098) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent work on the exploration well Kokoda #5. The attachments include a summary of the daily drilling operations, a directional survey, an as-built, a summary of the P&A operations, photos of the site and a schematic. We request that this data be held confidential as required under AS 31.05.035(c) and 20 AAC 25.537(d). This data is from federal lands. By submitting this data in compliance with the regulatory data submission requirements, ConocoPhillips Alaska, Inc. is not agreeing or acquiescing to the potential future application of the provisions of AS 31.05.035(c) and 20 AAC 25.537(d) that might allow the data to be disclosed to the public after the initial 24 month confidentiality period. ConocoPhillips Alaska, Inc. reserves all rights to dispute or appeal any attempt to apply those provisions to this data in the future. If you have any questions regarding this matter, please contact me at 263-4603. Sincerely, '~~Y1~ P. Mazzolini Exploration Team Leader CPAI Drilling PM/MC/skad · STATE OF ALASKA . RECEI\/ED ALASKA OIL AND GAS CONSERVATION COM SION . WELL COMPLETION OR RECOMPLETION REPO~f ÀNI30~OG 1a. Well Status: Oil 0 Gas U Plugged l.:j Abandoned l.:j Suspended 0 WAG ~Iask¡;¡ D"' 8'eßfi!9~un;;. Commission 0 20AAC 25.105 20AAC 25.110 Devel'1fffiffibr~ Exploratory J GINJ 0 WINJ 0 WDSPL 0 No. of Completions Other Service Stratigraphic Test 0 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. .- 204-259 / 305-098 or Aband.: April 25, 2005 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 March 7, 2005 , 50-279-20012-00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: / / / Kokoda #5 Surface: / 3143' FNL, 1709' FEL, Sec. 5, T11 N, R5W, UM April 4, 2005 At Top Productive 8. KB Elevation (ft): 15. Field/Pool(s): Horizon: 2151' FSL, 1724' FEL, Sec. 5, T11 N, R5W, UM 28' RKB /150' GL Total Depth: 9. Plug Back Depth (MD + lVD): NPRA Exploratsion 673' FNL, 1306' FEL, Sec. 5, T11 N, R5W, UM surface 4b. L~Iio:¡; (Slale B~ P.... Co,m"_, \ NAD'¡¡¡¡"& 7 10. Total Depth (MD + lVD): 16. Property Designation: Surface' X-1738385~~Y- '97~ Z"e-' / 11122' MD /10301' TVD .- ALK AA081737 & AA081840 TPI: x-1738371~ ~y- 5972 ~ Zone-5 11. Depth where SSSV set: 17. Land Use Permit: Total Depth: x- 17387496'1730 y- 597 Zone- 5 N/A ADL L300841 18. Directional Survey: Yes 0 NoU 19. Water Depth, if Offshore: 20. Thickness of N/A feet MSL Permafrost: 910' MD 21. Logs Run: GRlRes, Neutron/Density 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH lVD HOLE AMOUNT CASING SIZE wr. PER FT. CEMENTING RECORD GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 20" 94# B 28' 108' 28' 108' 30" 163 sxAS I 13-3/8" 68# L-80 28' 2609' 28' 2609' 16" 340 bbls AS Lite, 101 bbls DeepCrete 9.625" 40# L-80 28' 8031' 28' 7895' 12.25" 190 bbls Class G 23. Perforations open to Production (MD + lVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET none none 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. *NOTE* DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Top of plugs tagged and witnessed ·Plug #1 TOC @ 8326' 169 sx (46 bbls) Class G ·Plug #2 TOC @ 8190' 210sx (57 bbls) Class G / ·Plug #3 TOC @ 7311' 500 sx (103 bbls) Class G ·Plug #5 TOC @ surface w/180 sx (30 bbls) AS 1 ·Plug #4 TOC @ surface 142sx (23.5 bbls) AS 1 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Plugged and Abandoned Date of Test Hours Tested Production for OIL-BBL GAS-MCF WA TER-BBL CHOKE SIZE GAS-OIL RATIO Test Period --> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WA TER-BBL OIL GRAVITY - API (corr) press. psi 24-Hour Rate -> 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~~~:-<-:::':~,"""'-7-- '1 rChì~"~eL\"~ ~ ):C¡~~ \ J r'. ~,; ~,"'" J ~ if '%š:t ~ RBDMS BFL MAY 1 6 2005 ~ .. "~--j t \- None ¡ ::JjJEO¡ t _ --.-- i ~ .', ....L...,......._",·<·_·,,,¡. :,-..~..--.,.-.".-,., .. . . Gf Form 10-407 Revised 12/2003 ~.' P~TfHU~..o¡çl.. . J R.~. VrE "".' ".... .\ ¡\ ¡\i\..JI'¡ 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Kokoda 5 Nanushuk Fm Torok Fm HRZ Shublik TO 1390' 3254' 7618' 11032' 11122' 1390' 3254' 7545' 10227' 10301 ' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, As-Built, P&A Summary, P&A photos, Schematic 31 . I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mark Chambers @ 265-1319 Printed Na~ f) p~~ Signature ~ 1 h Title: Drillina Team Leader Phone 2"''3 - 4{.,Q3 Date 6S /1/ / ZooS Prepared by Sharon Allsup-Drake 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. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour 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, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 Conductor (80'): 20",94.00#, B Set @ +/- 108' MD / TVD Surface Casing: 13-3/8", 68.00#, L-80, BTC Set @ +/- 2609' MD / TVO Intermediate Casing #1: 9-5/8", 40.00#, L-80, BTC Set @ +/- 8031' MD / 7895' TVD Fish: Estimated Top @ +9036' Total Length 1227' Deepest Point During Fishing was 9036'. Did Not Encounter Top of Fish. TO (Estimated): @ +/- 11,122' MD /10,301' TVD Kokoda 5 - P&A Schematic v1.0 Prepared by Mark Chambers 05/10/05 12.50 PPG 6% KCl Kill Weight Mud 12.50 PPG 6% KCl Kill Weiaht Mud II ips 9-5/8" Casing /.0758 bbl/ft): 311' Cement Plug Set From Surface t0311' MD 142 Sacks (23.5 bbl) Arctic Set 1 Slurry Weight Slurry Yield Thickening Time 15.8 ppg 0.93 cu-ftIsk 2.50 hrs 13-3/8" x 9-5/S" Annulus /.0597 bbl/ft): 500' Cement Plug Set From Surface to 500' MD 180 Sacks (30 bbl) Arctic Set 1 Slurry Weight Slurry Yield Thickening Time 15.7 ppg .93 cu-ftIsk 2.50 hrs Marker Plate Information: ;¡"" Plate Thickness Operator Name: ConocoPhillips Alaska, Inc. Well Name: Kokoda #5 Permit to Drill Number: 204-259 API Number: 50-279-20012-00 SHL: 3143' FNL, 1709' Sec 5, T11 N, R5W Note: Weep Hole in plate as per BlM Regulations Bottom Plug Spotted in 3-Staaes as Outlined below: Pilla #3 500 Sacks (103 bbl) Class G "Alpine Intermediate Cement" Slurry Weight 15.8 ppg Slurry Yield 1.17 cu-ftIsk TOC Tagged and Witnessed @ 7,311' MD (720' Above 9-5/8" Shoe) Plug #2 210 Sacks (57 bbl) Class G w/ Silica + Additives Slurry Weight 15.8 ppg Slurry Yield 1.53 cu-ftIsk TOC Tagged and Witnessed @ 8,190' MD Plua #1 169 Sacks (46 bbl) Class G w/ Silica + Additives Slurry Weight 15.8 ppg Slurry Yield 1.53 cu-ftIsk TOC Tagged and Witnessed @ 8,326' MD · Halliburton Company. Global Report Survey: Start Date: Company: Tool: Engineer: Tied-to: Field: Zone 5 (Nad 83) Exploration ".' Map System:US State Plane Coordinate System 1983 Goo Datum: GRS 1980 Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Modet: Alaska, Zone 5 Well Centre bggm2004 Site: Kokoda Site Position: Northing: 5972477.00 ft Latitude: 70 20 4.687 N From: Map Easting: 1738386.00 ft Longitude: 153 12 18.693 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.00 deg Well: Kokoda #5 Stot Name: Kokoda Well Position: +N/-S -0.25 ft Northing: 5972476.74 ft Latitude: 70 20 4.685 N +E/-W -0.60 ft Easting : 1738385.40 ft Longitude: 153 12 18.711 W Position Uncertainty: 0.00 ft Wellpath: Kokoda #5 Drilled From: Well Ref. Point 502792001200 Tie-on Depth: 27.11 ft Cnrrent Datum: Kakoda #5 : Height 161.51 ft Above System Datum: Mean Sea Level Magnetic Data: 3/4/2005 Dectination: 22.47 deg Fietd Strength: 57426 nT Mag Dip Angte: 80.37 deg Verticat Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft 27.11 0.00 0.00 9.10 Snrvey Program for Definitive Wellpath Date: 12/7/2004 Validated: Yes Version: 3 Actual From To Survey Tootcode Toot Name ft ft 107.00 11052.91 Kokoda #5 (107.00-11052.91) MWD MWD - Standard Survey 27.11 0.00 0.00 27.11 -134.40 0.00 0.00 5972476.74 1738385.40 TIE LINE 107.00 0.00 0.00 107.00 -54.51 0.00 0.00 5972476.74 1738385.40 MWD 205.91 0.14 161.68 205.91 44.40 -0.11 0.04 5972476.63 1738385.44 MWD 297.77 0.00 247.75 297.77 136.26 -0.22 0.07 5972476.52 1738385.48 MWD 385.76 0.31 133.16 385.76 224.25 -0.38 0.25 5972476.36 1738385.65 MWD 479.23 0.38 186.44 479.23 317.72 -0.87 0.40 5972475.88 1738385.81 MWD 569.56 0.22 227.13 569.56 408.05 -1.28 0.24 5972475.46 1738385.65 MWD 659.63 0.36 263.67 659.63 498.12 -1.43 -0.17 5972475.31 1738385.25 MWD 750.31 0.12 267.15 750.30 588.79 -1.47 -0.55 5972475.27 1738384.87 MWD 840.81 0.25 301.87 840.80 679.29 -1.37 -0.81 5972475.36 1738384.61 MWD 931.51 0.06 341.26 931.50 769.99 -1.22 -1.00 5972475.51 1738384.42 MWD 1023.61 0.22 339.56 1023.60 862.09 -1.01 -1.07 5972475.72 1738384.34 MWD 1116.58 0.31 204.23 1116.57 955.06 -1.07 -1.24 5972475.66 1738384.18 MWD 1201.99 0.53 201.45 1201.98 1040.47 -1.65 -1.48 5972475.08 1738383.94 MWD 1303.26 0.44 228.69 1303.25 1141.74 -2.34 -1.94 5972474.38 1738383.49 MWD 1396.03 0.48 226.10 1396.01 1234.50 -2.84 -2.49 5972473.86 1738382.95 MWD 1488.71 0.57 235.50 1488.69 1327.18 -3.37 -3.15 5972473.33 1738382.30 MWD 1581.75 0.48 267.60 1581.73 1420.22 -3.65 -3.92 5972473.04 1738381.53 MWD 1674.18 0.74 264.62 1674.15 1512.64 -3.72 -4.90 5972472.95 1738380.55 MWD · Halliburton Company. Global Report 1766.29 0.68 267.82 1766.25 1604.74 -3.80 -6.04 5972472.86 1738379.41 MWD 1857.47 0.53 278.25 1857.43 1695.92 -3.76 -7.00 5972472.89 1738378.45 MWD 1951.31 0.25 220.73 1951.27 1789.76 -3.85 -7.56 5972472.79 1738377.89 MWD 2046.84 0.44 257.08 2046.80 1885.29 -4.09 -8.05 5972472.54 1738377.40 MWD 2136.23 0.36 261.54 2136.18 1974.67 -4.21 -8.67 5972472.42 1738376.79 MWD 2232.77 0.44 267.94 2232.72 2071.21 -4.27 -9.34 5972472.35 1738376.12 MWD 2324.93 0.48 284.44 2324.88 2163.37 -4.19 -10.06 5972472.42 1738375.39 MWD 2415.55 0.36 292.72 2415.50 2253.99 -3.98 -10.69 5972472.62 1738374.76 MWD 2509.22 0.25 320.26 2509.16 2347.65 -3.71 -11.10 5972472.89 1738374.35 MWD 2576.21 0.20 327.75 2576.15 2414.64 -3.50 -11.25 5972473.09 1738374.20 MWD 2664.50 0.19 3.59 2664 .44 2502.93 -3.22 -11.32 5972473.37 1738374.12 MWD 2757.69 0.17 359.29 2757.63 2596.12 -2.93 -11 .32 5972473.66 1738374.12 MWD 2850.85 0.14 18.03 2850.79 2689.28 -2.68 -11.28 5972473.91 1738374.15 MWD 2941 .34 0.12 29.84 2941.28 2779.77 -2.50 -11.20 5972474.10 1738374.23 MWD 3035.44 0.12 4.34 3035.38 2873.87 -2.31 -11.15 5972474.28 1738374.29 MWD 3129.42 0.09 339.55 3129.36 2967.85 -2.15 -11.16 5972474.45 1738374.27 MWD 3219.32 0.14 281.87 3219.26 3057.75 -2.06 -11.30 5972474.54 1738374.13 MWD 3307.06 0.28 234.38 3307.00 3145.49 -2.16 -11 .57 5972474.43 1738373.86 MWD 3404.57 0.33 228.81 3404.51 3243.00 -2.48 -11.98 5972474.10 1738373.45 MWD 3495.94 0.43 218.34 3495.88 3334.37 -2.93 -12.39 5972473.65 1738373.05 MWD 3586.84 0.47 219.69 3586.78 3425.27 -3.48 -12.84 5972473.09 1738372.61 MWD 3683.21 0.53 225.35 3683.14 3521.63 -4.10 -13.41 5972472.47 1738372.05 MWD 3775.07 0.44 220.57 3775.00 3613.49 -4.66 -13.94 5972471.89 1738371.52 MWD 3858.81 0.31 229.34 3858.74 3697.23 -5.06 -14.32 5972471.50 1738371.15 MWD 3961.20 0.45 260.58 3961.12 3799.61 -5.30 -14.93 5972471.24 1738370.54 MWD 4053.74 0.58 281.78 4053.66 38.92.15 -5.27 -15.75 5972471.27 1738369.73 MWD 4147.14 0.64 282.59 4147.06 3985.55 -5.06 -16.72 5972471.47 1738368.75 MWD 4239.50 0.67 297.46 4239.41 4077.90 -4.69 -17.70 5972471.82 1738367.76 MWD 4332.88 0.36 294.03 4332.79 4171.28 -4.32 -18.45 5972472.18 1738367.01 MWD 4427.00 0.56 300.24 4426.90 4265.39 -3.97 -19.12 5972472.52 1738366.33 MWD 4518.90 0.40 329.28 4518.80 4357.29 -3.47 -19.67 5972473.01 1738365.78 MWD 4611.20 0.61 323.76 4611.10 4449.59 -2.80 -20.13 5972473.68 1738365.31 MWD 4703.33 0.66 325.42 4703.22 4541.71 -1.96 -20.72 5972474.51 1738364.71 MWD 4797.11 0.88 347.68 4796.99 4635.48 -0.81 -21.18 5972475.65 1738364.24 MWD 4890.21 0.76 348.81 4890.08 4728.57 0.49 -21 .45 5972476.95 1738363.95 MWD 4983.09 0.83 331.85 4982.95 4821 .44 1.69 -21.89 5972478.14 1738363.49 MWD 5075.50 0.57 59.18 5075.36 4913.85 2.51 -21.81 5972478.97 1738363.56 MWD 5168.90 0.56 52.46 5168.75 5007.24 3.03 -21.05 5972479.49 1738364.32 MWD 5262.12 0.74 71.00 5261.97 5100.46 3.50 -20.12 5972479.98 1738365.24 MWD 5353.33 0.75 75.60 5353.17 5191.66 3.84 -18.98 5972480.33 1738366.37 MWD 5447.33 0.66 74.84 5447.16 5285.65 4.14 -17.86 5972480.64 1738367.48 MWD 5537.97 0.50 95.58 5537.80 5376.29 4.23 -16.97 5972480.75 1738368.38 MWD 5631.46 0.63 80.56 5631.28 5469.77 4.28 -16.05 5972480.81 1738369.29 MWD 5725.07 0.44 101.24 5724.89 5563.38 4.29 -15.19 5972480.83 1738370.15 MWD 5818.04 0.59 103.98 5817.86 5656.35 4.11 -14.38 5972480.66 1738370.97 MWD 5910.47 0.59 115.72 5910.28 5748.77 3.79 -13.49 5972480.35 1738371.86 MWD 6003.68 0.37 115.44 6003.49 5841.98 3.45 -12.78 5972480.02 1738372.57 MWD 6093.00 0.72 120.88 6092.80 5931 .29 3.04 -12.04 5972479.62 1738373.32 MWD 6189.56 0.83 116.08 6189.35 6027.84 2.42 -10.89 5972479.02 1738374.48 MWD 6282.99 0.81 151.25 6282.78 6121.27 1.54 -9.97 5972478.15 1738375.41 MWD 6369.93 0.72 140.34 6369.71 6208.20 0.58 -9.32 5972477.20 1738376.07 MWD 6461.71 0.36 355.93 6461.49 6299.98 0.43 -8.98 5972477.05 1738376.42 MWD -----, · Halliburton Company. Global Report 6554.22 3.53 338.51 6553.93 6392.42 3.37 -10.04 5972479.98 1738375.32 MWD 6647.26 6.13 340.17 6646.63 6485.12 10.71 -12.78 5972487.28 1738372.49 MWD 6734.53 9.65 346.74 6733.07 6571.56 22.21 -16.03 5972498.74 1738369.08 MWD 6832.68 12.47 351.28 6829.38 6667.87 40.70 -19.53 5972517.18 1738365.34 MWD 6925.71 15.53 359.65 6919.65 6758.14 63.09 -21.13 5972539.54 1738363.45 MWD 7017.42 17.18 6.09 7007.65 6846.14 88.84 -19.77 5972565.30 1738364 .48 MWD 7110.87 20.91 10.72 7095.98 6934.47 118.96 -15.20 5972595.48 1738368.65 MWD 7203.83 25.41 12.18 7181.42 7019.91 154.77 -7.90 5972631.38 1738375.48 MWD 7296.40 27.35 13.77 7264.35 7102.84 194.84 1.35 5972671.57 1738384.21 MWD 7390.66 27.93 14.34 7347.85 7186.34 237.26 11.97 5972714.12 1738394.27 MWD 7483.05 29.46 14.75 7428.90 7267.39 280.20 23.12 5972757.19 1738404.85 MWD 7575.33 30.63 14.99 7508.77 7347.26 324.85 34.98 5972801.99 1738416.13 MWD 7662.36 31.28 15.30 7583.41 7421.90 368.06 46.67 5972845.35 1738427.26 MWD 7761.65 31.60 15.54 7668.12 7506.61 417.99 60.44 5972895.44 1738440.37 MWD 7854.77 31.93 15.74 7747.29 7585.78 465.19 73.66 5972942.81 1738452.97 MWD 7947.27 32.47 13.87 7825.57 7664.06 512.84 86.25 5972990.62 1738464.93 MWD 8122.47 34.08 13.73 7972.04 7810.53 606.19 109.17 5973084.25 1738486.64 MWD 8209.75 35.36 14.84 8043.78 7882.27 654.36 121 .45 5973132.57 1738498.28 MWD 8306.17 36.39 15.09 8121.91 7960.40 708.95 136.04 5973187.34 1738512.16 MWD 8400.40 37.01 14.16 8197.46 8035.95 763.44 150.25 5973242.01 1738525.66 MWD 8493.22 38.96 12.44 8270.61 8109.10 819.03 163.38 5973297.76 1738538.05 MWD 8585.55 40.18 9.54 8341.79 8180.28 876.75 174.57 5973355.62 1738548.48 MWD 8678.76 39.62 9.27 8413.30 8251.79 935.74 184.34 5973414.72 1738557.48 MWD 8772.87 39.84 9.23 8485.67 8324.16 995.11 194.01 5973474.21 1738566.38 MWD 8860.48 39.65 10.4 7 8553.04 8391.53 1050.30 203.59 5973529.51 1738575.23 MWD 8958.61 39.64 9.50 8628.60 8467.09 1111.96 214.44 5973591.30 1738585.28 MWD 9050.85 41.33 8.32 8698.75 8537.24 1171.12 223.71 5973650.58 1738593.77 MWD 9143.01 40.29 10.04 8768.51 8607.00 1230.57 233.31 5973710.15 1738602.59 MWD 9235.25 40.05 8.51 8839.00 8677 .49 1289.29 242.90 5973768.98 1738611.42 MWD 9328.27 41.68 7.43 8909.34 8747.83 1349.56 251.33 5973829.35 1738619.06 MWD 9421.60 40.61 7.02 8979.62 8818.11 1410.48 259.05 5973890.36 1738625.98 MWD 9514.22 39.58 6.77 9050.47 8888.96 1469.70 266.21 5973949.66 1738632.37 MWD 9607.02 38.79 8.08 9122.40 8960.89 1527.84 273.79 5974007.89 1738639.18 MWD 9699.72 38.96 7.66 9194.57 9033.06 1585.47 281.75 5974065.62 1738646.39 MWD 9792.15 39.14 6.97 9266.35 9104.84 1643.23 289.16 5974123.46 1738653.05 MWD 9885.15 38.89 7.05 9338.61 9177.10 1701.34 296.31 5974181.65 1738659.44 MWD 9977 .87 39.60 8.04 9410.42 9248.91 1759.49 304.02 5974239.89 1738666.38 MWD 10070.73 40.93 7.42 9481.28 9319.77 1818.96 312.08 5974299.46 1738673.67 MWD 10163.72 41.83 8.65 9551.05 9389.54 1879.82 320.68 5974360.42 1738681.47 MWD 10253.23 41.60 7.12 9617.87 9456.36 1938.82 328.85 5974419.51 1738688.87 MWD 10348.47 40.83 8.26 9689.51 9528.00 2001.00 337.25 5974481.80 1738696.45 MWD 10436.10 40.32 8.11 9756.07 9594.56 2057.42 345.36 5974538.31 1738703.83 MWD 10534.07 39.35 7.35 9831.30 9669.79 2119.60 353.81 5974600.60 1738711.46 MWD 10626.82 38.40 6.42 9903.51 9742.00 2177.39 360.79 5974658.47 1738717.69 MWD 10718.28 38.30 8.35 9975.24 9813.73 2233.66 368.08 5974714.82 1738724.24 MWD 10812.47 36.95 7.42 10049.84 9888.33 2290.62 375.98 5974771.87 1738731.39 MWD 10904.08 35.78 7.67 10123.61 9962.10 2344.47 383.11 5974825.80 1738737.82 MWD 10997.28 36.03 4.65 10199.10 10037.59 2398.79 388.97 5974880.20 1738742.97 MWD 11052.91 35.05 5.45 10244.37 10082.86 2431.00 391.81 5974912.44 1738745.39 MWD / 11122.00 35.05 5.45 10300.93 /10139.42 2470.50 395.58 5974951.98 1738748.64 PROJECTED to TD DESCRIPi10N Per K05015ACS 1. COORDINATES OBTAINED BY GPS RAPID STATIC METHODOLOGY, USING LEICA SERIES 500 RECEIVERS. DATA PROCESSED BY NATIONAL GEODETIC SURVEY "ON-UNE POSITIONING USER SERVICE" (OPUS), RESOLVED FROM THE FOLLOWING BASE STATIONS: A. PBOC (PRUDHOE BAY CORS) B. FAIR (GILMORE CREEK OBS CORS) C. CENA (CENTRAL ALASKA CORS) 2. HORIZONTAL DATUM IS NAD83, ZONE 5, ALASKA. 3. VERTICAL DATUM IS ORTHOMETRIC REFERENCED TO GEOID 99. 4. ALL DISTANCES ARE TRUE. KOKODA 5 LOCATED WITHIN PROTRACTED SEC. 5, T 11 N, R 5 W, UMIA T MERIDIAN. 2136' F.S.L., 1,709' F.E.L. .; LA T = 70'20'04.802" N LONG = 1S3ï2'18.60S" W Y = 5.972.476.74' .; X = 1.738.385.40' , TOP CONDUCTOR ELEV.= 133.6' TOP OF RIG PAD ELEV. = 134.4' GROUND ELEVATlON= 131.6'. SCALE: 1- = 200' (\ ~~0 ~'f.- O'f.- Ot;) p.. \ ~ I · ~ ~. ~t <3 '£ ~J>-Q~ ,,\G .-:-- ~ to I") .- N 0\ot.\~S \ct. ~;Q OC) £. O· 00 _t ~1 fly ~ ConocoPhillips Alaska, Inc. DRAWING NO: CADD FILE NO. LK601 D601 N AREA: 00 DESCRIPi10N N + BEAUFORT SEA HARRISON SAY PRUDHOE Y . __ SA ~ -' VICINITY MAP NOT TO SCALE MODULE: XXXX KOKODA 5 EXPLORATORY WELL CONDUCTOR AS-BUILT LOCATION CEA-M1 XX-601 0601 PART: 1 OF 1 ~~""..., ~·~c OF ~..-. ..~::\ \:" ........... ~.... . /(. ..... ..... ..... ·r_' ... ....".... ; -- J ... ..... .... . ~ ..... ". "- II : . ¡ " : . :òIII _........... ... .. .. ......... II """"i ~ ~ !......II.... ....................._ fI!:;X!~ :Çk:_ i1 ìG\ ':.. L J. ROOKUS .:þ0" ~/....... .. . " Û'A ". ~~8 35 ..' . t.. ~ð····..:?o'£J r¿)~....·· c:>.s;.~ t. () A 'f/)q,. .r¿. ~{:J,. -tl. :t?" £ ION"'\. ;,.... ...",,~~ SURVEYOR'S CERTlFICA TE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THA T THIS PLA T REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THA TALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF MARCH I, 2005. 5 4 8 9 ßl LOUNSBURY '" ASSOCIATES, INC. smmmJRS BNGIIŒER8 PLANNERS ~ UNIT: M1 REV: 1 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KOKODA #5 KOKODA #5 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 3/6/2005 Rig Release: 4/25/2005 Rig Number: Spud Date: 31712005 End: 4125/2005 Group: 3/6/2005 04:00 - 06:00 2.00 MOVE RURD MOVE Stage pipe shed complex and rockwasher on edge of pad. 06:00 - 07:00 1.00 MOVE MOVE MOVE Peak load and move boiler module, motor module, pump module, pit module 07:00 - 08:00 1.00 MOVE MOVE MOVE Prep sub for move. Install tow bar. Fuel peak trucks. 08:00 - 09:30 1.50 MOVE MOVE MOVE Peak move boiler module, motor module, pump module, and pit module to Kokoda #5 location. (5 mile move). 09:30 - 12:00 2.50 MOVE MOVE MOVE Peak load both pipe sheds. Load counter weights on Sows for moving sub. Hook up to sub. Move sub off well, spot sub down pad. 12:00 -13:00 1.00 MOVE MOVE MOVE Peak move sub base f/ Kokoda #1 to Kokoda #5. 5 mile move. 13:00 - 17:30 4.50 MOVE MOVE MOVE Maneuver sub over hole. Set pit module, pump module, motor module, boiler module. Set rockwasher in berm, set pipe shed halves. Set tioga air heater in berm. Set Rain f/ Rent 500 bls diesel tank in 48' x 24' x 3' I tall berm, berm can hold 615 bbls. Set Epoch mud logging shack. Set I I Sperry sun MWD shack. 17:30 - 22:00 I 4.50 MOVE RURD MOVE Rig up, connect module utilities, complete rig acceptance check list. @ 2200 hrs 3/6/2005. Rig accepted @ 2200 hrs 3/6/2005. Moving camp f/ Kokoda #1 to Kokoda #5, start camp move off pad @ 1800 hrs, set camp, receive 100 bbls potable water @ 2000 hrs, receive fuel f/ camp and rig @ midnight. North Slope Telecom hook up communications. 22:00 - 00:00 2.00 WELCT NUND SURFAC I NU 21 1/4" diverter and 16" knife valve and line and MU riser. 3/7/2005 00:00 - 04:00 4.00 WELCT NUND SURFAC NU 21 1/4" diverter and 16" knife valve and line and MU riser. Install 4" valves on conductor. Add 30' section to diverter line. Hook up cellar pump. Check cellar alarm. Loading BHA & DP in pipe shed. Add 100 bbls water to rockwasher pit, check f/leaks, OK. Transfer water back to pits. I 04:00 - 04:30 0.50 DRILL RIRD SURFAC Continue to load pipe shed w/ 5" dp. Mixing mud. 04:30 - 10:15 I 5.75 DRILL PULD SURFAC PUlMU 5" dp f/ pipe shed, stand back in derrick. Rabbit dp. 10:15-11:00 0.75 WELCT BOPE SURFAC Diverter test of 21 1/4" system and 16" knife valve. Accumulator test. Witness of test by AOGCC inspector John Crisp. 11 :00 - 13:00 2.00 DRILL PULD SURFAC Continue PU/MU 5" dp f/ pipe shed, stand back in derrick. Rabbit dp. PUlMU 5" HWDP. 13:00 - 14:00 1.00 DRILL PULD SURFAC PUlMU stand flex collars. 14:00-15:15 1.25 DRILL PULD SURFAC PU BHA tools to floor. Clear floor. 15:15 - 16:45 1.50 DRILL PULD SURFAC PU/MU BHA #1. 16:45 - 17:00 0.25 DRILL SFTY SURFAC Pre spud meeting w/ drilling team. 17:00 - 18:30 1.50 DRILL PULD SURFAC Make up BHA #1. 18:30 - 19:30 1.00 DRILL OTHR SURFAC Upload Sperry Sun MWD tools. 19:30 - 20:15 0.75 DRILL CIRC SURFAC Fill hole. Check f/leaks. OK. Tag cement in conductor @ 88'. Pressure test mud lines to 3500 psi. OK. 20: 15 - 20:45 0.50 DRILL CIRC SURFAC Clean out 20" conductor (19.124" ID). Drill cement in conductor w/ 71 spm (300 gpm), 165 psi, 39% flow, MW 9.8 ppg, 60 rpm, WOB 4K, Rot wt 45k, PU wt 45k, SO wt 45k. 20:45 - 00:00 3.25 DRILL DRLG SURFAC Drill 16" hole f/1 08' to 155' w/71-83 spm (300-350 gpm), 165 psi, 39%- 146% flow, MW 9.8 ppg, 60 rpm, WOB 4-10 K, Rot wt 45k, PU wt 45k, IDRLG I SO wt 45k. 3/8/2005 00:00 - 01 :00 1.00 DRILL SURFAC Drill 16" hole f/155' to 180' w/83 spm (350 gpm), 260 psi, 46% flow, MW 9.8 ppg, 60 rpm, WOB 10 K, Rot wt 45k, PU wt 45k, SO wt 45k. ADT .5 hrs 01 :00 - 02:00 1.00 DRILL TRIP SURFAC POOH f/155' to 62', MU 1 stand 8" flex collars, MU stand HWDP. 02:00 - 06:00 4.00 DRILL DRLG SURFAC Drill 16" hole f/180' to 336' while staging pumps up f/83- 120 spm (350-500 gpm), 260-660 psi, 50%-53% flow, MW 9.8 ppg, 120 rpm, Printed: 5/2/2005 2:02:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KOKODA #5 KOKODA #5 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 3/6/2005 Rig Release: 4/25/2005 Rig Number: Spud Date: 3/712005 End: 4/25/2005 Group: 07:30 - 12:00 4.50 DRILL DRLG SURFAC 12:00 - 15:00 3.00 DRILL DRLG SURFAC 15:00 - 21 :15 6.25 DRILL DRLG SURFAC 21:15-22:45 1.50 DRILL CIRC SURFAC 22:45 - 00:00 1.25 DRILL WIPR SURFAC 3/9/2005 00:00 - 01 :00 1.00 DRILL WIPR SURFAC 01 :00 - 01 :45 0.75 DRILL WIPR SURFAC 01 :45 - 02:00 0.25 DRILL REAM SURFAC 02:00 - 02:30 0.50 DRILL CIRC SURFAC 02:30 - 02:45 0.25 DRILL OBSV SURFAC 02:45 - 04:45 2.00 DRILL TRIP SURFAC 04:45 - 05:15 0.50 DRILL PULD SURFAC 05:15 - 00:00 18.75 WAlTON WOW SURFAC 3/10/2005 00:00 - 12:00 12.00 WAlTON WOW SURFAC 12:00 - 00:00 12.00 WAlTON WOW SURFAC 3/11/2005 17.50 WAlTON WOW SURFAC 00:00 - 17:30 17:30 - 18:45 IpULD TRIP i SURFAC 1.25 DRILL SURFAC ,18:45 - 19:30 0.75 DRILL WOB 15k K, Rot wt 45-60k, PU wt 45-60k, SO wt 45-60k. No torque. Drill 16" hole f/336' to 380' while staging pumps up f/120- 166 spm (500-700 gpm), 660-1130 psi, 53%-51% flow, MW 9.8 ppg, 133 rpm, WOB 15k K, Rot wt 63k, PU wt 63k, SO wt 63k. No torque. Drill 16" hole f/380' to 608' while pumping 166 spm (700 gpm), 1130-1275 psi, 50%-48% flow, MW 9.8 ppg, 133-140 rpm, WOB 15-20k Rot wt 63-77k, PU wt 63-76k, SO wt 63-80k, torque 2k. Max gas 12 units @ 604'. Drill 16" hole f/608' to 879' while pumping 166 spm (700 gpm), 1130-1275 psi, 50%-48% flow, MW 9.8 ppg, 133-140 rpm, WOB 15-20k Rot wt 63-77k, PU wt 63-76k, SO wt 63-80k, torque 2k Max gas 24 units @ 809'. Drill 16" hole f/879' to 1061' while pumping 166 spm (700 gpm), 1130-1275 psi, 50%-48% flow, MW 9.8 ppg, 133-140 rpm, WOB 15-20k Rot wt 63-77k, PU wt 63-76k, SO wt 63-80k, torque 2k Background gas @ 20 units. Circ 2 bottoms up, while working pipe f/1061' to 970', circ while working pipe f/ 970' to 875' Wiper Trip f/ 875' to 430' @ midnight. No problems. Pulling slow (Weather conditions phase 3). Continue wiper trip f/430' to 60'. Phase 3 weather. Calc fill 14.92 bbls, Actual 13.0 bbl RIH f/60' to 970'. No problems. Calc displacement 16.7 bbls, Actual 10.0 bbls. Break circ wash down last stand @ 5 bpm f/970' to 1061'. No fill. PU wt 80k, SO wt 85k. Circ 2 BU. Rotate @ 40 rpm, circ @ 700 gpm, 1300 psi. Monitor well. Blow down top drive. POOH slow f/1061' to 248', UD 3 HWP, stand back stand of 8" flex collars, MU single HWDP. Pull up to Sperry sun MWD. Calc fill 21.6 bbls, actual 19.5 bbls. Download MWD/LWD tools, turn off batteries. Wait on weather, phase 3 weather conditions. Wait on weather, phase 3 weather conditions. Service top drive. PU (19) 13 3/8" centralizers. Transfering mud @ injection tank to clean up solids, put mud back on vac trucks. (2) vac trucks making their way w/ blade and blower escort to Kokoda, arrived Empty rock washer. Load a vac truck load of mud f/ rockwasher onto vac truck. Wait on weather, phase 3 weather conditions. Maint. and houskeeping. 3 Vac trucks w/liquid left location approx noon w/ escort blade and blower. Made it 27 miles to midway camp @ 1845 hrs. Wait @ midway camp f/ blowing snow to die down. Wait on weather, phase 3 weather conditions. Maint. and houskeeping. Service drawworks, service pipe skate, repair gunline in rockwasher. Clean out suction line in pit # 5. Wind died down. Started cleaning ice roads @ 0600 hrs, group of blade and blowers working f/ midway to Kokoda. Group of blade and blowers working towards Colville/laputus. (3) vac truck loads staged @ midway going to Alpine to offload. Arrived back to Kokoda approx 1700 hrs first one, 1800 hrs next one arrived. Upload Sperry Sun MWD tools. UD single HWDP, MU stand of 8" flex DC's, PU/MU 3 HWDP f/ pipe shed. RIH w/ BHA to 971', wash 971 to 1061' precautionary (slow pump), no Printed: 5/2/2005 2:02:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KOKODA #5 KOKODA #5 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 3/6/2005 Rig Release: 4/25/2005 Rig Number: Spud Date: 3/712005 End: 4/25/2005 Group: 3/11/2005 18:45 - 19:30 0.75 DRILL TRIP SURFAC fill. No problems on trip in hole. 19:30 - 19:45 0.25 DRILL CIRC SURFAC Circ bottoms up staging pumps up. Pumping @ 400 gpm w/600 psi, up to 500 gpm w/ 800 psi, up to 650 gpm w/1200 psi. Circ total of 4000 strokes. MW 9.8 + ppg. Vis 150. Temp out 30 deg. Max 6 units of gas. 19:45 - 00:00 4.25 DRILL DRLG SURFAC Dri1l16" hole f/1061' to 1260'(199') ADT= 3.0 hrs while pumping 170 spm (719 gpm), 1400-1450 psi, 58%-59% flow, MW 9.8-9.9 ppg, 140 I rpm, WOB 25k K, Rot wt 85k, PU wt 86k, SO wt 90k, torque on bottom 3k, torque off bottom 0, ECD 10.3-10.4 ppg, background gas 30 units. 3/12/2005 00:00 - 11 :30 11.50 DRILL DRLG SURFAC Drill 16" hole f/1260' to 1803'(543') ADT= 8.81 hrs while pumping 170-183 spm (719-775 gpm), 1450-1550 psi, 58%-59% flow, MW 9.8-9.9 ppg, 140 rpm, WOB 10-30k, Rot wt 85-98k, PU wt 86-95k, SO wt 90-100k, torque on bottom 3-4k, torque off bottom 0, ECD 10.3-10.4 ppg, background gas 50 units. I Had max 1130 units w/ drilling @ 1600' 11 :30 - 12:30 1.00 DRILL CIRC SURFAC Circ @ 725 gpm w/1500 psi. Circ hole clean. 12:30 - 14:15 1.75 DRILL DRLG SURFAC Drill 16" hole f/1803' to 1896'(93') ADT= 1.77 hrs while pumping 170 spm (719 gpm), 1500 psi, 58%-59% flow, MW 9.8-9.9 ppg, 140 rpm, WOB 25-35k , Rot wt 100k, PU wt 98k, SO wt 101 k, torque on bottom 2-3k, torque off bottom 0, ECD 10.3-10.4 ppg, background gas 50 units. 14:15 - 15:45 1.50 DRILL DRLG SURFAC Circ @ 725 gpm w/1500 psi. Circ hole clean. 15:45 - 16:45 1.00 DRILL WIPR SURFAC POOH f/1896' to 966'., Wiper trip (10 stands). 16:45 - 17:00 0.25 DRILL WIPR SURFAC Trip in hole to 1836' 17:00 - 17:30 0.50 DRILL REAM SURFAC Wash 60' to bottom. WOB 7K f/1865' to 1896'. Mx gas CBU 38 units 17:30 - 00:00 6.50 I DRILL DRLG SURFAC Drill 16" hole f/1896' to 2179'(93') ADT= 4.67 hrs while pumping I 170-179 spm (757 gpm), 1550-1800 psi, 58%-59% flow, MW 9.8-9.9 ppg, 140 rpm, WOB 10-35k, Rot wt 1 04-1 07k, PU wt 97-102k, SO wt 102-106k, torque on bottom 3-4k, torque off bottom 0, ECD 10.3 ppg, background gas 30 units, max gas 82 units @ 1970'. 3/13/2005 00:00 - 12:00 12.00 DRILL DRLG SURFAC Drill 16" hole f/2179 to 2453 (274') ADT= 7.19 hrs while pumping 170-179 spm (757 gpm), 1750-1800 psi, 58%-59% flow, MW 9.8-9.9 ppg, 140 rpm, WOB 15-40k , Rot wt 106-11 Ok, PU wt 102-11 Ok, SO wt 107-112k, torque on bottom 2-4k, torque off bottom 0-1k, ECD 10.1-10.3 ppg, 52 units of gas maximum @ 2339', background 30 units. 12:00 -17:00 5.00 DRILL DRLG SURFAC Drill 16" hole f/2453 to 2615 (162') ADT= 5.26 hrs while pumping 179-186 spm (788 gpm),1950-1975 psi, 59 % flow, MW 9.8-9.9 ppg , 140 rpm, WOB 15-35k, Rot wt 114, PU wt 11 Ok, SO wt 114k, torq on bottom 2k, torq off bottom O-k. 17:00 - 19:00 2.00 DRILL CIRC SURFAC 145 units of gas max @ 2480', background 25 units. CBU, Pump sweep, circ sweep out of hole. Circ @ 196 spm w/1975 psi. 19:00 - 22:30 3.50 DRILL WIPR SURFAC Wiper trip f/2615' to 600'. Tight spots on trip out @ 2350'-2265', 1982'-1960',1926'-1922',1801'-1794', 1650'-1620'. Calculated fill 20.33 bbls, actual fill 27 bbls. 22:30 - 00:00 1.50 DRILL WIPR SURFAC RIH f/ 600' to 1685'. Reamed 1712' w/680 gpm 1400 psi. PU wt 111 k, so wt 115k, rot wt 115k. Tight spots on trip in @ 1498', 1560'-1565', 1666', 1685'. 3/14/2005 00:00 - 01:15 1.25 DRILL REAM SURFAC RIH f/1685'-1695'. Set down. MU top drive. Reamed 1680' -1804 w/ 680 gpm 1400 psi, 100 rpm Circ total of 375 bbls (3733 strokes). PU wt 111k, so wt 115k, rot wt 115k. 01 :15 - 01 :30 0.25 DRILL TRIP SURFAC RIH f/1804' to 2555'. Wash down last 60' f/2555' to 2615' @ 5 bpm. No apparant fill. 01 :30 - 03:00 1.50 DRILL CIRC SURFAC Stage pumps up to final of 180 spm w/1850-1900 psi. Circ total of 1208 Printed: 51212005 2:02:27 PM Legal Well Name: Còmmon Well Name: Event Name: Contractor Name: Rig Name: KOKODA #5 KOKODA #5 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 3/6/2005 Rig Release: 4/25/2005 Rig Number: Spud Date: 3/712005 End: 4/25/2005 Group: 3/14/2005 01 :30 - 03:00 1.50 DRILL CIRC SURFAC bbls (12000 strokes). Rotate @ 100 rpm and recip pipe 62' (2553' to 2615'). 03:00 - 04:15 1.25 DRILL CIRC SURFAC Stand stand back. Pump 33 bbls hi vis sweep @ 6 bpm & 400 psi. Recip and work pipe 93' f/2551' to 2458'. Follow sweep w/9.9 ppg mud 0.251 DRILL pumping @ 180 spm (761gpm) and 1850-1900 psi. Circ total of 1410 bbls (14,000 strokes). 04:15 - 04:30 TRIP SURFAC Shut down pumps, MU stand RIH to bottom. Tag fill w/o pump @ 2611'. 04:30 - 08:15 3.75 DRILL TRIP SURFAC POOH w/16" bit, BHA #1, to run 13 3/8" casing. 08:15 - 08:45 0.50 DRILL PULD SURFAC Download Sperry Sun MWD/LWD tools. 08:45 - 10:15 1.50 DRILL PULD SURFAC IUD BHA#1. 10:15 - 10:30 0.25 CASE OTHR SURFAC Clean & clear Rig floor. Dummy run FMC 13 3/8" hanger & landing joint. 10:30 - 12:00 1.50 CASE RURD SURFAC Clean floor. RU to run 133/8",68 #/ft, L-80 BTC casing. 12:00 - 12:30 0.50 CASE SFTY SURFAC PJSM on running 133/8" casing. 12:30 - 19:30 7.00 CASE RUNC SURFAC Run 133/8",68 ppf, L-80, BTC casing to 290'.set down hard. work thru. cont. RIH w/ csg. pipe set down solid @t 620' PU clean, worked pipe down, set down hard at 1015', worked pipe down, ran in hole and set down at 1215'.worked pipe down, RIH to 2408'. 19:30 - 20:15 0.75 CASE CIRC SURFAC Brk circ and slowly increase rate to 150 gpm @ 450 psi for 185 bbls. 20:15 - 22:15 2.00 CASE RUNC SURFAC Wash 3 jts. to bottom f/2408'-2572'@ 125 gpm w/450 psi 22:15 - 23:00 0.75 CASE RUNC SURFAC PU csg hanger and torq running tool/landing jt. RIH land hanger @ 2609' 125k down, 155k up. Lost 12 bbls mud while running casing. Ran total of 62 jts w/ bow spring centralizers on stop rings on jts. 1,2 &3 and across the collars on jts #9,11, 15, 19, 23, 27, 31, 35, 39, 43,47, 51,55, and 59 for a total of 17. 08:15 -10:30 1.00 CEMEN CIRC SURFAC Circulate thru fill-up tool 1-1/2 BU. starting at 2 bpm w/130 psi and finish w/6.5 bpm W 400 psi. Circ total of 3381 strokes. 340 bbls. Annular capacity of 16" x 13 3/8" = 196 bbls. Note: 12-14 bbls mud lost to hole while running casing and circ casing. Calc displ 64.64 bbls, actual 51 bbls. Note: Spill drill W/ ADEC involement and IMT deploment held 3/14/2005. RID 10' pup jt on top of landing joint. RID Doyon casing equip and Frank's fillup tool. Ru 5" handling tools PJSM on running Weatherford seal assembly and centralizer f/ stab in job. RIH w/ seals on 5" dp, centralizer 4' above tooljoint. Run 27 stands 5" dp and 2 pup joints. I Space out w/2' pup joints (6.77' and 14.74'). Tag and stab into Weatherford FC @ 2523'. st wt up 78K, dn wt 76K I RU circ head, swing, valve and Tee and cont to circ and condition mud i for cementing. Circ @ .5 bpm to fill 13 3/8" csg, stab into Float collar I and stage pumps f/ 2 bpm to 8 bpm w/ 450 psi. Held pre job safety I meeting on cement job while circ. Circ total of 131 bbls, then pumped 11310 bbls pretreated mud at 9.8 ppg w/ reduced YP to 23. Returns out at @ 9.9 ppg 25 YP. 2.25 CEMEN PUMP SURFAC Turned over to Dowell and pumped 10 bbls of CW 100 with red dye at 8.3 ppg, pressure tested lines to 3,000 psi, pumped add. 40 bbls of CW 100 (50 bbls Total), then pumped 50 bbls of 10.5 ppg Mudpush, ave 5.8 bpm at 185 psi" began mixing and pumping lead cement, pumped until we got cement returns @ 340 bbls, 460 sxs of 10.7 ppg, 4.45 yield Arctic set Lite III cmt with add., ave 7 bpm at 370 psi, followed with 101 bbls, 335 sxs of LiteCrete tail cmt at 12.0 ppg with add. ave 5 bpm at 23:00 - 00:00 3/15/2005 00:00 - 01 :30 1.50 CASE RURD SURFAC 01 :30 - 02:00 0.50 CEMEN1¡ OTHR SURFAC 02:00 - 03:45 1.75 CEMEN~TRIP SURFAC 03:45 - 04:45 1.00 CEMEN~TRIP SURFAC í 04:45 - 08:15 3.50 CEMENliCIRC SURFAC Printed: 5/2/2005 2:02:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KOKODA #5 KOKODA #5 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 3/6/2005 Rig Release: 4/25/2005 Rig Number: Spud Date: 3/712005 End: 4/25/2005 Group: 3/15/2005 08:15 - 10:30 2.25 CEMEN PUMP SURFAC 350 psi, with full returns, Break off head pin drop drillpipe wiper dart. 10:30 - 11 :00 0.50 CEMEN DISP SURFAC Displace w/ rig pumps at 6 bpm for 36 bbls, max pressure 635 psi, then slowed to 2 bpm at 525 psi., Did not see wiper dart land. Pumped calculated displacement 446 stks (44.8 bbls) plus? shoe track for a total of 500 stks (50bbls.) CIP @ 11:00 hrs and had 121 bbls of 10.7 ppg cement back to surface, Dowell washed up to cellar and Tim Lawlor with BLM witnessed cement job 11 :00 - 12:00 1.00 CEMEN OTHR SURFAC LD 2- DP pup jts and check floats and held, flushed out diverter 12:00 - 13:45 1.75 CEMEN TRIP SURFAC POOH with 5" DP and LD stab in sub and centralizer 13:45 - 14:30 0.75 CEMEN PULD SURFAC LD 13 3/8" landing jt 14:30 - 17:00 2.50 WELCT NUND SURFAC ND 21 1/4" 2M diverter and 16" line 17:00 - 18:00 1.00 WELCT NUND SURFAC NU FMC 13 5/8" 5M Unihead wellhead and tested seal to 1,000 psi for I 10 min I '18:00 - 20:30 2.50 WELCT NUND SURFAC NU 13 5/8" 5M BOP stack and lines 20:30 - 23:00 2.50 DRILL PULD SURFAC RU and LD 27 stds of 5" DP used to cement 133/8" csg 23:00 - 00:00 1.00 WELCT BOPE SURFAC RU and performed a full body test on BOP equipment to 3,500 psi and ck ok 3/16/2005 00:00 - 04:30 4.50 DRILL PULD SURFAC Strapped 5" DP in pipe shed then PU and stood back 87 Jts (29 stds) of DP in derrick 04:30 - 10:45 6.25 WELCT BOPE SURFAC RU and Tested BOPs, tested rams, valves and manifold to 250 psi low I and 5,000 psi high psi, tested annular to 250 psi low and 3,500 psi high, I Test witnessed by Tim Lawlor w/ BLM and waived by Chuck Scheve w/ AOGCC. 10:45 -11:15 0.50 DRILL PULD SURFAC Installed wear bushing 11:15 -13:00 1.75 RIGMNT RSRV SURFAC Service TD and drawworks, inspected saver sub and cut and slip 79' of drilling line 13:00 - 17:45 4.75 DRILL PULD SURFAC MU 12 1/4" BHA #2 and RIH to 300', MU bit #2 with 8" motor with 1.15 deg bend, MWD, density nuetron and PWD, oriented and uploaded MWD, held PJSM and loaded radioactive sources, RIH with 1 std of 17:45 - 18:30 0.75 DRILL DEQT SURFAC I HWDP to 300' Shallow tested MWD and telemetry module (TM) failed 18:30-21:45 3.25 DRILL PULD SURFAC POOH from 300' to 112', removed radioactive sources, then changed out TM module, shallow tested tool and ck ok 21 :45 - 22:30 0.75 DRILL PULD SURFAC Held PJSM and reloaded radioactive sources RIH to 300' 22:30 - 23:30 1.00 DRILL TRIP SURFAC RIH with 12 1/4" BHA #2 from 300' with HWDP to 1,158' and MU ghost reamer 23:30 - 00:00 0.50 DRILL TRIP SURFAC RU and RIH with BHA #2 PU 3 jts of 5" DP from pipe shed, RIH from 1 ,158' to 1 ,250' 3/17/2005 00:00 - 01 :45 1.75 DRILL TRIP SURFAC RIH with 12 1/4" BHA #2 from 1,250' and tagged float collar at 2,523', PU 30 jts of 5" DP from pipe shed while RIH 01 :45 - 02:30 0.75 DRILL CIRC SURFAC Circ 1 complete circ evening MW in and out at 9.9 ppg, circ at 450 gpm I at 900 psi 02:30 - 03:30 1.00 CASE DEQT SURFAC RU and tested 13 3/8" csg to 2,500 psi for 30 min 03:30 - 05:00 1.50 CEMEN DSHO SURFAC Drilled out float collar at 2,523', shoe track and float shoe at 2,609', I cleaned out to TD at 2,615' then drilled 20' of new formation to 2,635', 05:00 - 06:151 drilled out at 2-5K wob, 60 rpm's, 450 gpm at 900 psi 1.25 DRILL CIRC SURFAC Displaced out 9.9 ppg mud in hole with reconditioned 9.7 ppg mud, circ at 450 gpm, 900 psi, rot st wt 125K 06:15 - 06:45 ' 0.50 DRILL FIT SURFAC RU and performed FIT to 16.1 ppg EMW, 9.7 ppg MW, 2,609' TVD and 875 psi 06:45 - 10:45 4.00 DRILL DRLG INTRM1 Drilled 12 1/4" hole from 2,635' to 2,920' MD/2,920' TVD (285') ART 3 IINTRM1 hrs. 10:45 - 11 :15 0.50 DRILL CIRC Circ btms up and performed PWD baseline, with 9.5 ppg MW at 600 i Printed: 5/212005 2:02:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KOKODA #5 KOKODA #5 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 3/6/2005 Rig Release: 4/25/2005 Rig Number: Spud Date: 31712005 End: 4125/2005 Group: 3/17/2005 10:45-11:15 0.50 DRILL CIRC INTRM1 gpm, clean hole ECD was 9.7 ppg 11:15-00:00 12.75 DRILL DRLG INTRM1 Drilled 12 1/4" hole from 2,920' to 3,667' MD/3,667' TVD, (747'), ART 8.72 hrs, 5-12K wob, 95 rpm's, 147 spm, 625 gpm, off btm pressure 1,600 psi, on btm pressure 1,800 psi, off btm torque 1 K ft-Ibs, on btm 7K ft-Ibs, rot wt 145K, up wt 140K, dn wt 145K, 9.6 ppg mw, ave ECD 10.1 ppg, mud loggers ave BGG 35 units, max gas 78 units from 3,285', pumped weighted hi vis sweep at 3,570' and had 10-20% increase in cuttings, at approx 19:30 hrs while drlg at 3,450' was notified by Sperry Sun that pulser unit on MWD tool was only functioning intermittently 3/18/2005 00:00 - 00:45 0.75 DRILL DRLG INTRM1 Drilled 12 1/4" hole from 3,667' to 3,755' MD/3,755' TVD, (88'), ART .5 hrs, 5-12K wob, 95 rpm's, 147 spm, 625 gpm, off btm pressure 1,600 psi, on btm pressure 1,800 psi, off btm torque 1 K ft-Ibs, on btm 7K ft-Ibs, rot wt 145K, up wt 140K, dn wt 145K, 9.6 ppg mw, ave ECD 10.1 ppg, mud loggers ave BGG 32 units, Sperry Sun's pulser unit on MWD/LWD tool not functioning properly, decision made to POOH and change out tools 00:45 - 01 :45 1.00 DRILL CIRC INTRM1 Pumped hi vis sweep and circ hole clean for trip out, had 10% increase in cuttings back from sweep, circ 2X btms up and clean at shakers, circ at 625 gpm at 1,650 psi, monitored well-static 01 :45 - 06:45 5.00 DRILL TRIP INTRM1 POOH from 3,755' to BHA at 240', POOH on elevators from 3,755' to 3,477' and hole didn't take calc fill due to 25-30K drag & swabbing, pumped and rotated out of hole from 3,477' to inside csg at 2,543', circ btms up while pulling last 2 stds to shoe and had a large amount of clay back, once inside csg pulled 3 stds to 2,363' and hole took calc fill, pumped dry job and fin POOH to BHA at 240' standing back HWDP, rotated at 50 rpm's and pumped out 420 gpm at 850 psi 06:45 - 09:30 2.75 DRILL PULD INTRM1 Held PJSM and removed radioactive sources, LD BAT tool, downloaded MWD/LWD tools and LD TM, Neutron, DM and PWD tool, ck motor and bit and ck ok. I NOTE: Sperry Sun determined that the HCIM tool that distributes pulse comands to the MWD/LWD tools had failed, to send tool to shop for further evaluation 09:30 - 12:30 3.00 DRILL PULD INTRM1 ,MU BHA #3 and RIH to 240', MU PWD, DM, Neutron, TM and BAT tool, I shallow tested tool and ck ok, held PJSM and loaded radioactive I sources and RIH with std of flex DC's to 240' 12:30 -14:45 2.25 DRILL TRIP INTRM1 RIH with BHA #3 from 245' to 3,665' with no problems 14:45 -15:15 0.50 DRILL CIRC INTRM1 Washed 90' to btm from 3,665' to 3,755' with no problems, circ btms up and had a large amount of clay back at btms up, circ at 625 gpm at 1,650 psi and 95 rpm's, rot wt 148K, up wt 143K, dn wt 147K, trip gas 77 units 15:15 - 00:00 8.75 DRILL DRLG INTRM1 Drilled 12 1/4" hole from 3,755' to 4,300' MD/4,300' TVD, (545"), ART 7.58 hrs, 8-15K wob, 100 rpm's, 151 spm, 640 gpm, off btm pressure 1,800 psi, on btm pressure 2,000 psi, off btm torque 1.5K ft-Ibs, on btm 6-9K ft-Ibs, rot wt 156K, up wt 152K, dn wt 154K, 9.7 ppg mw, ave ECD 10.1 ppg, mud loggers ave BGG 30 units, max gas 59 units and no conn gas, pumped weighted hi vis sweep at 4,033' and had 15-20% increase in cuttings 3/19/2005 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Drilled 12 1/4" hole from 4,300' to 4,869' MD/4,869' TVD, (569'), ART 9.43 hrs, 8-12K wob, 100 rpm's, 151 spm, 640 gpm, off btm pressure 1,875 psi, on btm pressure 2,100 psi, off btm torque 1 K ft-Ibs, on btm 4-8K ft-Ibs, rot wt 169K, up wt 163K, dn wt 169K, 9.7 ppg mw, ave ECD 10.0 ppg, mud loggers ave BGG 30 units, max gas 51 units and no conn gas, pumped weighted hi vis sweep at 4,683' and had no increase Printed: 51212005 2:02:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KOKODA #5 KOKODA #5 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 3/6/2005 Rig Release: 4/25/2005 Rig Number: Spud Date: 3/712005 End: 4/25/2005 Group: 3/19/2005 00:00 - 12:00 12.00 DRILL DRLG INTRM1 in cuttings 12:00 - 19:00 7.00 DRILL DRLG INTRM1 Drilled 12 1/4" hole from 4,869' to 5,241' MD/5,241' TVD, (372'), ART 5.57 hrs, AST .4 hrs, 8-11 K wob, 100 rpm's, 151 spm, 640 gpm, off btm pressure 1,975 psi, on btm pressure 2,150 psi, off btm torque 1 K ft-Ibs, on btm 4-8K ft-Ibs, rot wt 177K, up wt 170K, dn wt 175K, 9.7 ppg mw, ave ECD 10.0 ppg, mud loggers ave BGG 30 units, max gas 50 units and no conn gas, pumped hi vis sweep at 5,148' and had no increase in cuttings 19:00 - 20:30 1.50 DRILL CIRC INTRM1 Circ hole clean for wiper trip, circ 2X btms up and was clean at shakers, circ at 640 gpm, 1,950 psi, 100 rpm's with 2k ft-Ibs torque, ECD after circ hole clean 9.88 ppg, monitored well-static 20:30 - 22:00 1.50 DRILL WIPR INTRM1 Wiped hole 14 stds from 5,241' to 3,945', POOH from 5,241' to 4,400', pumped out of hole due to 25-30K drag and swabbing from 4,400' to 4,315', POOH from 4,315' to 4,210' then pumped out 4,210' to 4,120', POOH from 4,120' to 3,945' with no problems, pumped out at 460 gpm at 1,150 psi 22:00 - 22:45 0.75 DRILL WIPR INTRM1 RIH from 3,945' to 5,148' with no problems 22:45 - 23:30 0.75 DRILL CIRC INTRM1 Washed 93' to btm to 5,241' with no problems and circ btms up, circ btms up at 640 gpm, 2,050 psi and 100 rpm's, max gas at btms up 155 units, Initial ECD 10.29 ppg, final ECD 9.86 23:30 - 00:00 0.50 DRILL DRLG INTRM1 Drilled 12 1/4" hole from 5,241' to 5,269' MD/ 5,269' TVD (28') ART .10 hrs 3/20/2005 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Drilled 12 1/4" hole from 5,269' to 5,745' MD/5,745' TVD, (476'), ART 9.85 hrs, 8-15K wob, 100 rpm's, 154 spm, 650 gpm, off btm pressure 2,025 psi, on btm pressure 2,300 psi, off btm torque 1.5K ft-Ibs, on btm 4-8K ft-Ibs, rot wt 186K, up wt 179K, dn wt 182K, 9.7 ppg mw, ave ECD 9.98 ppg, mud loggers ave BGG 20 units, max gas 34 units and no conn gas 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drilled 12 1/4" hole from 5,745' to 6,240' MD/6,240' TVD, (495'), ART 10.25 hrs, 8-15K wob, 105 rpm's, 154 spm, 650 gpm, off btm pressure 2,125 psi, on btm pressure 2,300 psi, off btm torque 2K ft-Ibs, on btm 4-8K ft-Ibs, rot wt 194K, up wt 189K, dn wt 192K, 9.7 ppg mw, ave ECD 9.90 ppg, mud loggers ave BGG 20 units, max gas 33 units and no I conn gas, pumped hi vis sweep at 6,110' and had a 15% increase in cuttings back from sweep 3/21/2005 00:00 - 07:00 7.00 DRILL DRLG INTRM1 Drilled 12 1/4" hole from 6,240' to 6,384' MD/6,384' TVD, (144'), ART 6.45 hrs, 8-15K wob, 105 rpm's, 154 spm, 650 gpm, off btm pressure 2,200 psi, on btm pressure 2,300 psi, off btm torque 2K ft-Ibs, on btm 4-8K ft-Ibs, rot wt 197K, up wt 192K, dn wt 194K, 9.7 ppg mw, ave ECD 9.90 ppg, mud loggers ave BGG 20 units, max gas 39 units and no conn gas, penetration rate decreased from an ave of 50'/ hr to 10-15'/hr 07:00 - 08:15 1.25 DRILL CIRC INTRM1 Circ hole clean for trip out of hole, circ 1 1/2X btms up and clean at shakers, circ at 650 gpm at 2,200 psi, Monitored well-static 08:15 - 12:45 4.50 DRILL TRIP INTRM1 I POOH," elevatms nom 6,384' to 5,400', pomped oot of hole doe to drag and swabbing from 5,400' to 5,100', cont to POOH wet on elevators from 5,100' to inside csg shoe at 2,577', had 25K drag at 3,800' and worked thru spot and ck ok 12:45 - 13:15 0.50 DRILL OBSV INTRM1 Monitored well at shoe, well-static, pumped dry job and blow down top drive 13:15 -13:45 0.50 DRILL TRIP INTRM1 POOH from 2,577' to BHA at 1,158' 13:45 - 18:45 5.00 DRILL PULD INTRM1 LD ghost reamer and POOH standing back HWDP, jars and flex DC's, held PJSM and removed radioactive sources, LD BAT tool and downloaded MWD/LWD, stood back MWD/LWD and LD motor and bit, Printed: 51212005 2:02:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KOKODA #5 KOKODA #5 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 3/6/2005 Rig Release: 4/25/2005 Rig Number: Spud Date: 3/712005 End: 4/25/2005 Group: 3/21/2005 13:45 - 18:45 5.00 DRILL PULD INTRM1 bit had slight wear on cutters and was able to turn motor by hand, no other indications with BHA in reduced pentration rate 18:45 - 22:00 3.25 DRILL PULD INTRM1 MU 12 1/4" BHA #4 RIH to 1,152', MU new bit #3 on new 8" motor with 1.5 deg bend, oriented MWD and uploaded same, MU BAT tool and tested tools, held PJSM and loaded radioactive sources, RIH with NM Flex Dc's, jars and HWDP to 1 ,152' 22:00 - 22:30 0.50 DRILL TRIP INTRM1 RIH from 1,152' to 2,545' and shallow tested MWD/LWD and ck ok, 575 0.50 I RIGMNT RSRV gpm at 1,400 psi, st wt up 119K, dn wt 123K 22:30 - 23:00 INTRM1 Serviced top drive 23:00 - 00:00 1.00 DRILL TRIP INTRM1 RIH from 2,545' to 4,309', while RIH at 3,530' began taking wt, worked thru spot several times and checked ok 3/22/2005 00:00 - 01 :00 1.00 DRILL TRIP INTRM1 RIH from 4,309' to 6,166', began to see 20-25K drag at 6,166' 01:00 - 02:15 1.25 DRILL REAM INTRM1 Pre-cautionary washed and reamed from 6,166' to btm at 6,384' with no problems, washed and reamed at 50 rpm's, 580 gpm at 1,650 psi 02:15 - 03:00 0.75 DRILL CIRC INTRM1 Circ btms up after washing to btm, max gas at btms up 200 units, circ at 640 gpm, 2,450 psi at 80 rpm's 03:00 - 12:00 9.00 DRILL DRLG INTRM1 Drilled 12 1/4" hole per directional plan from 6,384' to 6,595' MD/ 6,594.6' TVD (211') ART 5.14 hrs, AST 2.16 hrs, 35K wob, 80 rpm's, 154 spm, 650 gpm, off btm pressure 2,375 psi, on btm pressure 2600 psi, off btm torque 1.5K ft-Ibs, on btm 4K ft-Ibs, rot wt 201 K, up wt 195K, dn wt 198K, 9.8 ppg MW, ave ECD 9.9 ppg, Epoch mudloggers ave bgg 13 units, max gas 18 units 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drilled 12 1/4" hole per directional plan from 6,595' to 6,905' MD/6,899' TVD (310') ART 6.28 hrs, AST 4.27 hrs, 40-45K wob, 80 rpm's, 154 spm, 650 gpm, off btm pressure 2,550 psi, on btm pressure 2,725 psi, off btm torque 2K ft-Ibs, on btm 7K ft-Ibs, rot wt 204K, up wt 201 K, dn wt 200K, 9.8 ppg MW, ave ECD 9.95 ppg, Epoch mudloggers ave bgg 30 units, max gas 311 units from 6,712', conn gas at 6,812' and 6,905' was 5 units over BGG 3/23/2005 00:00 - 03:00 3.00 DRILL DRLG INTRM1 Drilled 12 1/4" hole per directional plan from 6,905' to 6,970' MD/6,962' TVD (65') ART 1.06 hrs, AST 1.58 hrs, 40-45K wob, 80 rpm's, 154 spm, 650 gpm, off btm pressure 2,550 psi, on btm pressure 2,750 psi, off btm torque 2K ft-Ibs, on btm 4-9K ft-Ibs, rot wt 204K, up wt 204K, dn wt 201K, 9.8 ppg MW, ave ECD 9.95 ppg, ave bgg 20 units, had an increase in drlg rate for 20' 03:00 - 04:00 1.00 DRILL CIRC INTRM1 Circ btms up to check for gas and had no increase, circ at 650 gpm, 2,550 psi at 80 rpm's 04:00 - 12:00 8.00 DRILL DRLG INTRM1 Drilled 12 1/4" hole per directional plan from 6,970' to 7,125' MD/ 7,109' TVD (155') ART 3.22 hrs, AST 3.21 hrs, 40-45K wob, 80 rpm's, 154 spm, 650 gpm, off btm pressure 2,550 psi, on btm pressure 2,775 psi, off btm torque 2.5K ft-Ibs, on btm 4-1 OK ft-Ibs, rot wt 207K, up wt 208K, dn wt 205K, 10.0 ppg MW, ave ECD 10.1 ppg, Epoch mudloggers ave bgg 20 units 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drilled 12 1/4" hole per directional plan 7,125' to 7,355' MD/7,313' TVD (230') ART 9.11 hrs, AST 2 hrs, 40-45K wob, 80 rpm's, 154 spm, 650 gpm, off btm pressure 2,575 psi, on btm pressure 2,725 psi, off btm torque 3K ft-Ibs, on btm 4-10K ft-Ibs, rot wt 212K, up wt 213K, dn wt 204K, 10.0 ppg MW, ave ECD 10.15 ppg, Epoch mud loggers ave bgg 40 units, max gas 154 units from 7,173', ave conn gas 30 units over BG, pumped hi vis sweep at 7,220' with no increase in cuttings Note: Received 24 hr. extension from Chuch Scheve W/AOGCC on testing of BOP's 3/24/2005 00:00 - 02:30 2.50 DRILL DRLG INTRM1 Drilled 12 1/4" hole per directional plan from 7,355' to 7,400' MD/7,355' Printed: 5/2/2005 2:02:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KOKODA #5 KOKODA #5 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 3/6/2005 Rig Release: 4/25/2005 Rig Number: Spud Date: 3/712005 End: 4/25/2005 Group: 3/24/2005 00:00 - 02:30 2.50 DRILL DRLG INTRM1 TVD (45') ART 1.31 hrs, 40-45K wOb, 80 rpm's, 154 spm, 650 gpm, off btm pressure 2,575 psi, on btm pressure 2,725 psi, off btm torque 3K ft-Ibs, on btm 4-10K ft-Ibs, rot wt 212K, up wt 216K, dn wt 202K, 10.0 ppg MW, ave ECD 10.15 ppg, Epoch mudloggers ave bgg 40 units, max gas 180 units from 7,388', conn gas 30 units over BG, planned trip for bit due to hrs and to test BOP's 02:30 - 05:00 2.50 DRILL CIRC INTRM1 Pumped hi vis sweep and circ hole clean for trip out of hole, had no increase in cuttings from sweep and circ a total of 2X btms up and was clean at shakers, stood back 1 std every 30 min while circ hole and I POOH to 7,090', circ at 650 gpm at 2,500 psi, 80 rpm's with 3K ft-Ibs torque off btm, BGG down to 55 units 05:00 - 05:15 0.25 DRILL OBSV INTRM1 Monitored well 15 min, well-static 05:15 - 08:45 3.50 DRILL TRIP INTRM1 POOH from 7,090' to 5,050' with no problems, pumped dry job and cont POOH from 5,050' to inside 13 3/8" csg shoe to 2,452' with no problems 08:45 - 09:00 0.25 DRILL OBSV INTRM1 I Monitored well at shoe-static 09:00 - 09:30 0.50 DRILL TRIP INTRM1 I POOH from 2,452' to BHA #4 at 1,152' 09:30 - 13:30 4.00 DRILL PULD INTRM1 ¡POOH from 1,152' to 149', stood back HWDP, jars and NM Flex DC's, LD BAT tool, removed radioactive sources and began downloading MWD/LWD, LD BHA to pipe shed to finish retrieving MWD/LWD data, calc fill on trip out 61.5 bbls actual fill 67.5 bbls 13:30 - 14:00 0.50 DRILL PULD INTRM1 Pulled wear bushing 14:00 -18:15 4.25 WELCT BOPE INTRM1 RU and tested BOP's, tested rams, valves and manifold to 250 psi low and 5,000 psi high, then tested Annular to 250 psi low and 3,500 psi high. NOTE: Test witnessed by John Crisp with AOGCC 18:15 - 18:45 0.50 DRILL PULD INTRM1 Installed wear bushing 18:45 - 22:30 3.75 DRILL PULD INTRM1 MU 12 1/4" BHA #5 and RIH to 1,152', MU bit #4, 8" motor with 1.5 deg bend, stab, FS, DGRlEWRlPWD and DM tool and oriented MWD, MU neutron/ACAL and TM, uploaded MWD, shallow tested tool and ck ok, held PJSM and loaded radioactive sources, RIH with NM flex DC's, jars and HWDP to 1,152' 22:30 - 23:00 0.50 DRILL TRIP INTRM1 RIH from 1,152' to 2,546' 23:00 - 00:00 1.00 RIGMNT RSRV INTRM1 Slip and cut 55' of drlg line, serviced top drive and drawworks 3/25/2005 00:00 - 02:30 2.50 DRILL TRIP INTRM1 RIH from 2,546' and began to see 40K drag at 7,200', PU to 7,185' 02:30 - 04:00 1.50 DRILL REAM INTRM1 Wash and reamed from 7,185' to btm at 7,400', washed down at 515 gpm, 1,800 psi and 50 rpm's 04:00 - 04:45 0.75 DRILL CIRC INTRM1 Circ btms up after washing to btm, max gas at btms up 375 units, circ at 650 gpm, 2,575 psi at 80 rpm's and 3K ft-Ibs torque, BGG down to 45 units, initial ECD 10.5 ppg, final ECD 10.3 ppg 04:45 - 15:00 10.25 DRILL DRLG INTRM1 Drilled 12 1/4" hole per directional plan from 7,400' to 7,670' MD/7,590' TVD (270') ART 7.28 hrs, AST 1.06 hrs, 8-14K wob, 80 rpm's, 154 spm, 650 gpm, off btm pressure 2,575 psi, on btm pressure 2,700 psi, off btm torque 4K ft-Ibs, on btm 3-9K ft-Ibs, rot wt 214K, up wt 217K, dn wt 206K, 10.0 ppg MW, ave ECD 10.2 ppg, Epoch mudloggers ave BGG to 7,640', 40 units, ave BGG below 7,640' was 450 units, max gas 618 / units from 7,613', conn gas ave 30 units over BG, had 20' drlg break, attempted to slide and was unable to hold a tool face 15:00 - 16:00 1.00 DRILL CIRC INTRM1 Circ btms up after 20' drlg break, max gas at btms up 365 units, circ at 650 gpm, 2,575 psi, 80 rpm's with 4K ft-Ibs off btm torque 16:00 - 23:00 7.00 DRILL DRLG INTRM1 Drilled 12 1/4" hole from 7,670' to 8,040' MD/7,903' TVD (370') ART 5.78 hrs, AST-O- hrs, 8-14K wob, 80 rpm's, 154 spm, 650 gpm, off btm pressure 2,675 psi, on btm pressure 2,900 psi, off btm torque 5K ft-Ibs, on btm 4-11 K ft-Ibs, rot wt 216K, up wt 227K, dn wt 207K, 10.15 ppg Printed: 512/2005 2:02:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KOKODA #5 KOKODA #5 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 3/6/2005 Rig Release: 4/25/2005 Rig Number: Spud Date: 3/712005 End: 4/25/2005 Group: 3/25/2005 16:00 - 23:00 7.00 DRILL DRLG INTRM1 MW, ave ECD 10.4 ppg, Epoch mudloggers ave bgg 220 units, max gas 372 units from 7,701', conn gas ave 30 units over BG, attempted to slide again and still was unable to hold a tool face 23:00 - 00:00 1.00 DRILL CIRC INTRM1 Began circ hole clean for wiper trip, pumped hi vis sweep and circ hole at 650 gpm, 2,675 psi, 80 rpm's with 4K ft-Ibs torque, 10.15 ppg MW, ave ECD 10.45 ppg 3/26/2005 00:00 - 01 :30 1.50 DRILL CIRC INTRM1 Fin circ hole clean for wiper trip, circ out hi vis sweep with no increase in cuttings, circ an add. btms up and clean at shakers, circ at 650 gpm, 2,650 psi and 80 rpm's, 10.1+ ppg MW, ECD at 10.4 ppg, Epoch BGG at 115 units 01 :30 - 01 :45 0.25 DRILL OBSV INTRM1 Monitored well 15 min-static 01 :45 - 03:30 1.75 DRILL WIPR INTRM1 Wiped hole 20 stds from 8,040' to 6,166' with no problems 03:30 - 04:30 1.00 DRILL WIPR INTRM1 RIH from 6,166' and worked thru tight spot at 7,655' to 7,670', cont RIH and set down at 7,956' 04:30 - 05:00 0.50 DRILL REAM INTRM1 Washed thru spot at 7,956' with no problems and conI. washing 84' to btm at 8,040' 05:00 - 08:45 3.75 DRILL CIRC INTRM1 Pumped hi vis sweep and circ hole clean for trip out to run 9 5/8" csg, had no increase in cuttings from hi vis sweep, circ a total of 3X btms up and was clean at shakers, circ at 650 gpm, 2,650 psi and 80 rpm's, max gas after wiper trip 545 units, Epoch BGG at 42 units 08:45 - 09:00 0.25 DRILL OBSV INTRM1 Monitored well- static 09:00 - 12:45 3.75 DRILL TRIP INTRM1 POOH from 8,040' (20 stds) to 6,166' with no problems and hole took calc fill, pumped dry job and cant POOH to inside 133/8" csg shoe to 2,540', no problems 12:45 - 13:00 0.25 DRILL OBSV IINTRM1 Monitored well at shoe for 15 min, well-static 13:00 - 13:45 0.75 DRILL TRIP INTRM1 POOH from 2,540' to BHA at 1,152', monitored well at BHA-static 13:45 - 17:30 3.75 DRILL PULD INTRM1 Stood back 9 stds of HWDP, LD 2-jts of HWDP and jars, LD Flex NM Dc's, held PJSM and removed radioactive sources, LD BAT tool and downloaded MWD/LWD, LD remaining BHA and cleared rig floor, calc fill 82 bbls, actual fill 94.75 bbls 17:30 - 18:00 0.50 DRILL PULD INTRM1 Pulled wear bushing 18:00 -19:45 1.75 WELCT EQRP INTRM1 Installed test plug and changed out to set of VBR rams over to 9 5/8" 1.751 CASE csg rams and tested same to 250 psi low and 2,000 psi high 19:45-21:30 RURD INTRM1 RU Doyon's 9 5/8" csg equipment with Franks fill up tool, made dummy run with landing jt and hanger and torqued up same 21 :30 - 21 :45 0.25 CASE SFTY INTRM1 Held PJSM with rig crew and tong operator on running of csg 21 :45 - 00:00 2.25 CASE I RUNC INTRM1 MU 9 5/8" float shoe, 2 jts of 9 5/8", 40#, L-80, BTC csg and fit collar, thread locked conn below FC and circ thru shoe track, RIH with 9 5/8" csg to 1,190', (30 jts of 197 in the hole). 3/27/2005 00:00 - 01 :30 1.50 CASE RUNC INTRM1 RIH with 9 5/8" csg from 1,190' to 2,606' (csg shoe) 63 jts of 197 in hole 01 :30 - 02:00 0.50 CASE CIRC INTRM1 Circ a csg cap at the shoe, staged pump rate up to 6 bpm at 350 psi, st wt up 145K, dn wt 80K 02:00 - 08:30 6.50 CASE RUNC INTRM1 Cont RIH with 9 5/8" csg from 2,606' to 8,000' with no problems, I washed every 20th jt down while RIH 08:30 - 09:15 0.75 CASE RUNC INTRM1 I MU landing jt and hanger, est circ and staged pump rate up to 4 bpm at 1375 psi and began washing down, hanger stopped in BOP stack, I worked hanger down thru stack and landed hanger, landed 9 5/8" csg at i 8,031', ran a total of 197 jts of 95/8",40#, L-80, BTC csg, total I including float equip. and hanger 8004.36', attempted to reciprocate I pipe but would hang up in stack, landed csg without reciprocating, st wt I up before landing hanger 370K, dn wt 235K. 09:15 -10:45 1.50 CEMEN CIRC INTRM1 I Began to circ and condition mud thru fill up tool, staged pump rate up to '4 bpm at 300 psi, circ 450 bbls of mud while conditioning same, did not Printed: 5/212005 2:02:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KOKODA #5 KOKODA #5 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 3/6/2005 Rig Release: 4/25/2005 Rig Number: Spud Date: 3/7/2005 End: 4/25/2005 Group: reciprocate pipe. max gas at btms up 380 units I LD Franks fill up tool and MU Dowells cement head Fin circ and cond mud for cementing, staged pump rate up to 7 bpm, 510 psi, conditioned mud from 10.4 ppg, 62 vis, PV 22, YP 28 to 10.1 + ppg, 48 vis, PV 16, YP 19, did not reciprocate pipe due to hanger hanging up in stack with full returns, held PJSM with Dowell, APC vac truck drivers and rig crew while circ hole 1.75 CEMEN PUMP INTRM1 Turned over to Dowell and pumped 5 bbls ofCW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, pumped add. 45 bbls of CW 100 (50 bbls Total) shut down and dropped btm plug, then pumped 50 bbls of 10.5 ppg Mudpush, ave 4 bpm at 250 psi, began mixing and pumping tail cement, mixed and pumped 190 bbls (920 sxs) of Class G cmt at 15.8 ppg and 1.16 yield with add. ave 6.2 bpm at 1100 psi with full returns, shut down and dropped top plug. 1.50 CEMEN DISP INTRM1 Dowell pumped 20 bbls FW and turned over to rig and rig displaced cmt with 583 bbls of 10.15 ppg mud, ave 7.5 bpm, initial pressure 300 psi, max pressure 1050 psi, slowed to 3 bpm and bumped plugs on calc displacement to 1600 psi with full returns, ck floats and floats held, CIP at 15:26 hrs, Calc TOC @ 6000'. NOTE: Tim Lawlor with BLM waived I witnessing of running and cementing 9 5/8" csg. LD landing it and RD csg equipment Installed 9 5/8" pack-off and tested seals to 5,000 psi for 10 min and ck ok Changed out top set of 9 5/8" csg rams back to 3 1/2" x 6" VBR's, RU and tested same to 250 psi low and 5,000 psi high Installed wear bushing MU 8 1/2" BHA #6 and RIH to 1,138', MU bit #5, 6 3/4" motor with 1.22 deg bend, MWD/LWD/PWD, oriented and uploaded, shallow tested tools, MU BAT tool and held PJSM and loaded radioactive sources, RIH with 3- NM Flex Dc's, HWDP, Jars and ghost reamer to 1,138' RIH with BHA #6 to 1,602' PU 15 its of 5" DP from pipe shed RIH with 8 1/2" BHA #6 from 1,602' to 4,943', PU 108 its of 5" DP from pipe shed while RIH, (123 total its) RU on 13 3/8" x 9 5/8" annulus and performed LOT to 20.2 ppg EMW, 10.1 ppg MW, 1,375 psi at 2,609' TVD Flushed 13 3/8" x 9 5/8" annulus with 300 bbls of water, ave 4 bpm at 430 psi, shut in with 380 psi Slip and cut 45' drlg line and serviced top drive RIH from 4,943' to 7,914' Circ hole for casing test, evened MW in and out at 10.1 ppg, circ at 510 gpm at 2,050 psi RU and tested 9 5/8" csg to 2,500 psi for 30 min I Drilled out plugs, float collar at 7,951', shoe track, float shoe at 8,031' I and cleaned out to btm at 8,040', drilled 20' of new formation to 8,060' MD, 7,920' TVD, ART .30 hrs, drilled out with 5-10 wob, 50 rpm's, 510 gpm at 2,100 psi Circ hole clean for LOT/FIT, evened MW in and out at 10.3 ppg, circ at 510 gpm, 2,100 psi RU and performed FIT to 14.0 ppg EMW, 1,520 psi at 7,920' TVD with 10.3 ppg MW Circ and raised MW from 10.3 ppg to 11.3 ppg, circ at 450 gpm, 1,700 psi at 20 rpm's, rot wt 214K, up wt 225K, dn wt 200K Drilled 8 1/2" hole per directional plan from 8,060' to 8,283' MD/ 8,104' 12:15 - 14:00 14:00 - 15:30 15:30 - 16:45 1.25 CEMEN RURD INTRM1 16:45 -17:15 0.50 I WELCT EQRP INTRM1 17:15 -19:15 2.00 WELCTi EQRP INTRM1 1 119:15 -19:30 0.25 DRILL PULD INTRM1 19:30 - 23:30 4.00 DRILL PULD INTRM1 23:30 - 00:00 0.50 DRILL TRIP INTRM1 3/28/2005 00:00 - 02:30 I 2.50 DRILL TRIP INTRM1 02:30 - 03:15 0.75 DRILL LOT INTRM1 I 03:15 - 04:45 1.501 DRILL OTHR INTRM1 04:45 - 05:45 1.00 RIGMNTIRSRV INTRM1 05:45 - 07:15 1.50 DRILL TRIP INTRM1 07:15 - 08:15 1.00 DRILL CIRC INTRM1 08:15 - 09:30 1.25 CASE DEQT INTRM1 09:30 -11:15 1.75 CEMEN DSHO INTRM1 11:15-12:001 0.75 DRILL CIRC INTRM1 12:00 - 13:00 1.00 DRILL FIT INTRM1 13:00 - 16:00 3.00 DRILL CIRC INTRM2 16:00 - 22:00 6.00 DRILL DRLG INTRM2 i Printed: 5/212005 2:02:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KOKODA #5 KOKODA #5 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 3/6/2005 Rig Release: 4/25/2005 Rig Number: Spud Date: 3/712005 End: 4/25/2005 Group: 3/28/2005 16:00 - 22:00 6.00 DRILL DRLG INTRM2 TVD, (223') ART 2.60 hrs, AST 1.76 hrs, 8-1 OK wob, 90 rpm's, 130 spm, 550 gpm, off btm pressure 2,725 psi, on btm pressure 2,900 psi, off btm torque 5.5K ft-Ibs, on btm torque 7K ft-Ibs, rot wt 202K, up wt 224K, dn wt 196K, 11.5 ppg MW, ave ECD 12.35 ppg, ave BGG 60 I units, max gas 88 units, ave conn gas 3 units over BG 22:00 - 22:45 0.75 DRILL CIRC IINTRM2 I Circ btms up and performed PWD baseline, with 11.5 ppg mud at 550 ,gpm and 90 rpm's clean hole ECD was 12.27 ppg 22:45 - 23:30 0.75 DRILL DRLG INTRM2 I Drilled 8 1/2" hole per directional plan from 8,283' to 8,316' MD/ 8,129' TVD (33') ART -0-, AST .54 hrs 23:30 - 00:00 0.50 RIGMNT RGRP INTRM2 Circ hole at a reduced rate working pipe and changed out swab on #1 mud pump 3/29/2005 00:00 - 12:00 12.00 DRILL DRLG INTRM2 Drill 8 1/2" hole from 8316' to 8770' MD. 8483' TVD. 500 gpm @ 3050 psi 90 rpms 1 0/12k bit wt Up wt - 234k Dn wt - 200k Rot wt - 215k Tq on - 4/9k Tq off - 5/8k ECD - 12.3/12.6 ppg Avg BGG - 60 units Max gas - 361 units Pumped hi vis sweep at 8660' with no increase in cuttings. 12:00 - 00:00 12.00 DRILL DRLG INTRM2 Drilled 8 1/2" hole per directional plan from 8,770' to 9,135' MD/8,761' TVD, (365') ART 4.71 hrs, AST 3.16 hrs, 5-12K wob, 90 rpm's, 130 spm, 550 gpm, off btm pressure 3075 psi, on btm pressure 3250 psi, off btm torque 6-8K ft-Ibs, on btm torque 7K ft-Ibs, rot wt 220K, up wt 240K, dn wt 200K, 11.6 ppg MW, ave ECD 12.5 ppg, ave BGG 60 units, max gas 161 units. 3/30/2005 00:00 - 06:45 6.75 DRILL DRLG INTRM2 Drill 8 1/2" hole from 9135' to 9397' MD. 8961' TVD. 550 gpm @ 3250 psi MW 11.6 ppg 90 rpms 1 0/12k bit wt Up wt - 245k Dn wt - 205k Rot wt - 224k Tq on - 4/1 Ok Tq off - 4/1 Ok ECD - 12.6 Max gas 167 units @ 9271'. Avg 109 units. Conn gas 4 more than background 06:45 - 08:00 1.25 DRILL CIRC INTRM2 Circ 2X bottoms up to clean hole. Set back one std every 30 min. 08:00 - 09:15 1.25 DRILL WIPR INTRM2 POH f/9304' to shoe at 8030'. 25k over pull from 8320' to 8300'. No hole problems. 09: 15 - 09:45 0.50 DRILL WIPR INTRM2 Monitor well. RIH to bridge at 8410'. Unable to work through bridge. 09:45 -10:15 0.50 DRILL WIPR INTRM2 Wash and ream through bridge at 8410' at 5 bpm and 10 rpms. Ream to 8472'. 10:15-11:00 0.751 DRILL WIPR INTRM2 RIH to 9304'. No hole problems. 11 :00 - 12:00 1.00 DRILL CIRC INTRM2 Break circ. Wash and ream from 9304' to 9397'. CBU. Max gas at INTRM2 bottoms up - 460 units. 12:00 - 00:00 I 12.00 DRILL DRLG Drill 8 1/2" hole from 9397' to 9690' MD. 9187' TVD. í I 524 gpm @ 3175 psi MW 11.8ppg I ! 90 rpms 8/17k bit wt Up wt - 250k Dn wt - 207k Rot wt - 227k Torque on - 4/11 k Torque off - 4/1 Ok ECD - 12.7 Max gas 166 units @ 9651'. Avg 102 units. Conn gas 4 over background. Note: Functioned pipe rams on short trip. 3/31/2005 00:00 - 07:30 7.50 DRILL DRLG INTRM2 Drill 8 1/2" hole from 9660' to 9847' MD. 9309' TVD. Printed: 51212005 2:02:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KOKODA #5 KOKODA #5 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 3/6/2005 Rig Release: 4/25/2005 Rig Number: Spud Date: 3/712005 End: 4/25/2005 Group: 3/31/2005 00:00 - 07:30 7.50 DRILL DRLG INTRM2 525 gpm @ 3175 psi MW 11.8 ppg 90 rpms 8/17k bit wt Up wt - 248k Dn wt - 213k Rot wt - 229k Tq on - 5/10k Tq off - 5/9k ECD - 12.7 Max gas 194 units @ 9776'. Avg 104 units. Conn gas 4 more than background 07:30 - 08:00 0.50 DRILL CIRC INTRM2 CBU for drlg break 9815' to 9847'. Max gas - 142 units 08:00 - 12:00 4.00 DRILL DRLG INTRM2 Drill 8 1/2" hole from 9847' to 9928' MD. 9371' TVD. 525 gpm @ 3175 psi MW 11.8 ppg 90 rpms 8/17k bit wt Up wt - 248k Dn wt - 213k Rot wt - 229k Tq on - 5/1 Ok Tq off- 5/9k ECD - 12.7 Max gas 160 units @ 9862'. Avg 11 units. Conn gas 15 more than background 12:00 - 00:00 12.00 DRILL DRLG INTRM2 Drill 8 1/2" hole from 9928' to 10340' MD. 9684' TVD. 550 gpm @ 3400 psi MW 11.8 ppg 90 rpms 8/20 bit wt Up wt - 256k Dn wt - 219k Rot wt 236k Tq on - 7/8k Tq off - 7/5k ECD- 12.8 ppg Max gas 476 units @ 10032'. Avg 182 units. Conn gas 440 more than background Conn @ 10047' : BG gas 160 units, conn gas 35 units over @ 185 units Conn @ 10140' : BG gas 160 units, conn gas 75 units over @ 235 units Conn @ 10232' : BG gas 163 units, conn gas 400 units over @ 563 units Conn @ 10325' : BG gas 100 units, conn gas 440 units over @ 540 units 4/1/2005 00:00 - 02:00 2.00 DRILL DRLG INTRM2 Drill 8 1/2" hole from 10,340' to 10,402' MD. 9730' TVD. ADT - 1.01 hrs ART - .65 hrs AST - .36 hrs 550 gpm @ 3450 psi MW 11.8 ppg 90 rpms 8/18k bit wt Up wt - 260k Dn wt - 220k Rot wt - 236k Tq on - 7/1 Ok Tq off - 6/8k ECD - 12.7 Max gas 111 units @ 10399'. Avg 69 units BG. No connections made. r 02:00 - 02:30 0.50 DRILL CIRC INTRM2 CBU from drilling break at 10,382' to 10,402'. Max gas - 240 units. 02:30 - 03:00 0.50 DRILL DRLG INTRM2 Drill 8 1/2" hole from 10,402' to 10,417' MD. 9742' TVD. ADT - .51 hrs ART - .51 hrs 03:00 - 05:30 2.50 DRILL CIRC INTRM2 Check flow. Circ 2X bottoms up. Large amount splintered shale at shakers. Set back 1 std every 30-45 mins. 05:30 - 08:00 2.50 DRILL CIRC INTRM2 Circ and increase mud wt to 12.0 ppg. Set back 1 std every 45 mins. Large amount of shale at shakers. 08:00 - 09:00 1.00 DRILL WIPR INTRM2 Back reamed from 9957' to 9678'. 09:00 - 09:30 0.50 DRILL WIPR INTRM2 CBU. Shakers cleaned up considerably at bottoms up. 09:30 - 10:15 0.75 DRILL WIPR INTRM2 Blow down top drive. POH from 9678' to 9215'. No hole problems. 10:15-11:30 1.25 DRILL WIPR INTRM2 RIH to 10,328'. Washed through tight spot at 10,224'. 11 :30 - 11 :45 0.25 DRILL WIPR INTRM2 Break circ. Washed and reamed from 10,328' to 10,418'. 11 :45 - 12:30 0.75 DRILL CIRC INTRM2 CBU. Max trip gas - 852 units. 12:30 - 00:00 11.50 DRILL DRLG INTRM2 Drill 8 1/2" hole f/10417' to 10626'. 9903' TVD. ART = 4 hrs. AST= Printed: 51212005 2:02:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KOKODA #5 KOKODA #5 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 3/6/2005 Rig Release: 4/25/2005 Rig Number: Spud Date: 3/712005 End: 4/25/2005 Group: 4/1/2005 12:30 - 00:00 11.50 DRILL DRLG INTRM2 4/2/2005 00:00 - 12:00 12.00 DRILL DRLG INTRM2 12:00 - 13:00 1.00 DRILL DRLG INTRM2 13:00 - 14:30 1.50 DRILL CIRC INTRM2 14:30 - 17:45 3.25 DRILL CIRC INTRM2 17:45 - 00:00 6.25 DRILL CIRC INTRM2 4/3/2005 00:00 - 10:00 10:00 - 11 :00 11 :00 - 12:00 10.00 DRILL 1.00 DRILL 1.00 DRILL CIRC INTRM2 CIRC INTRM2 CIRC INTRM2 12:00 - 00:00 12.00 DRILL DRLG INTRM2 4/4/2005 00:00 - 03:45 3.75 DRILL DRLG INTRM2 2.71 hrs 525 gpm @ 3250 psi MW 12ppg ECD 12.7-12.8ppg 90 rpm's 8/20k bit wt PU wt 265k SO wt 219k Rot wt 239k torq on 8/10k torq off 9k Max gas 244 units @ 10615'. Avg 93 units BG. Connection gas 100-200 over background. Drill81/2" hole from 10,626' to 10,926' MD. 10,141' TVD. ADT - 7.16 hrs ART - 3.91 hrs AST - 3.25 hrs 525 gpm @ 3300 psi MW 12.0 ppg 190 rpms 1 0/17k bit wt Up wt - 275k Dn wt - 219k Rot wt - 244k Tq on - 8/10k Tq off - 8/9k ECD - 12.7/12.9 Max gas 477 units @ 10865'. Avg 120 units BG. Connection gas - 185 units over BG. Drill81/2" hole from 10,926' to 10,968' MD. 10,176' TVD. 525 gpm @ 3300 psi MW 12.0ppg 90 rpm 8-14k wob PU wt 275k Dn wt 219k Rot wt 244k Tq on 8-10k Tq off 8-9k ECD 12.9 ppg I Max gas 310 units @ 10936'. Avg 104 units BG. No connections made. 'I· Loss of circulation while drilling@10968'(10176'TVD),Welltakingfluid w/ pumps off. Fill w/ trip tank while pumping 4bpm. Spot 35 bbl LCM pill IW/20PPb material (7.4 ppb Dynared Med, 7.4 ppb Dynared Fine, 5.2 ppb S-200). Gain full returns when pill reached bit. Lost total of 360 bbls mud during circ and spotting of pill (string volume 184 bbls). Circ and monitor well while building volume in pits. Circ @ 3 bpm w/ 100% returns 400 psi, reduce rate to reduce losses. Pit circ volume holding steady @ 75 bbls. Circ and monitor well while building volume in pits. Circ @ 2 bpm w/ 100% returns 300 psi. Pit circ volume holding steady @ 75 bbls. BG gas 100 units. Circ at 4 bpm w/ no losses. Continue to build mud volume in pits. Stage pumps from 168 gpm to 500 gpm at 2900 psi. ECD - 12.8 Stage rotary from 40 to 90 rpms. Wash from 10,949' to 10,968'. All mud trucks on location. Drill 8 1/2" hole from 10,968' to 11013' MD. 10,212' TVD. ADT = 8.03 ART = 7.38hrs AST = .65hrs 503 gpm w/2850 psi MW 12.1 ppg ECD 12.6ppg 70-90 rpm 17 -30k wt on bit PU wt 285k SO wt 218K Rot wt 238k torq on bottom 10k torq off bottom 9k Mud losses slowed to 7-10 bph avg Max gas 254 units @ 11013'. Ave BG gas 116 units. Conn @ 11973' gas 30 units above BG. **Well is breathing with pumps off Note: Fluid losses total for day 407.3 bbls Total f/ well 767.3 bbls Drill 8 1/2" hole from 11,013' to 11026' MD. 10,223' TVD. ADT = 3.66 hrs ART = 3.66 hrs AST = 0.0 hrs 500 gpm w/3000 psi MW 12.1ppg ECD 12.7 ppg 170-90 rpm 18-30k wt on bit Printed: 5/212005 2:02:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KOKODA #5 KOKODA #5 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 3/6/2005 Rig Release: 4/25/2005 Rig Number: Spud Date: 3/712005 End: 4/25/2005 Group: 4/4/2005 00:00 - 03:45 03:45 - 05:15 05:15 - 05:30 05:30 - 12:00 12:00 - 14:30 14:30 - 16:30 16:30-17:15 17:15 - 17:45 17:45 - 19:30 19:30 - 00:00 4/5/2005 00:00 - 01:15 01 :15 - 06:30 06:30 - 10:45 10:45 - 12:00 12:00 - 22:15 22:15 - 00:00 4/6/2005 00:00 - 00:45 3.75 DRILL DRLG INTRM2 PU wt 255k SO wt 220K Rot wt 244k torq on bottom 10k torq off bottom 9k Mud losses slowed to 12-16 bph avg 1.50 RIGMNT RGRP INTRM2 0.25 RIGMNT RGRP INTRM2 6.50 DRILL DRLG INTRM2 2.50 DRILL DRLG INTRM2 2.00 DRILL CIRC INTRM2 0.75 DRILL OBSV INTRM2 0.50 DRILL WIPR INTRM2 1.75 DRILL CIRC INTRM2 4.50 DRILL WIPR INTRM2 1.25 DRILL WIPR INTRM2 5.25 DRILL WIPR INTRM2 I ICIRC I WIPR I IWIPR i I ICIRC I I I I I I ICIRC I i 4.25 DRILL INTRM2 1.25 DRILL INTRM2 10.25 DRILL INTRM2 1.75 DRILL INTRM2 0.75 DRILL IINTRM2 **Well is breathing with pumps off Back ream 2 stands out of hole. Repair hydraulic fitting on top drive. RIH with 2 stds drill pipe. Drill 8 1/2" hole from 11,026' to 11087' MD. 10,271' TVD. ADT = 4.34 hrs ART = 4.34 hrs AST = 0.0 hrs 500 gpm w/ 3000 psi MW 12.1 ppg ECD 12.8 ppg 70-90 rpm 25-30k wt on bit PU wt 255k SO wt 220K Rot wt 244k torq on bottom 10k torq off bottom 9k Mud losses - 12-20 bph avg. Mud loss f/12 hour tour = 177.5 bbls. Total losses f/ well 944.8 bbls Max gas 365 units @ 11066'. Ave BG gas 120 units. Conn @ 11066' gas 210 units above BG. **Well is breathing with pumps off Drill 8 1/2" hole from 11,087' to 11122' MD. (10,301.34' TVD) ADT= 3.35 hrs all rotating 500 gpm w/ 3000 psi MVV 12.1 ppg ECD 12.8 ppg 90 rpm 20/30k WOB PU wt 295k SO wt 218k Rot wt 246k Tq on 8-15k CBU. Std back 1 std. CBU to clean hole. Monitor well. Flowed back 43 bbls in 45 mins. Flow decreased to a trickle. Attempt to POH. Work through tight spots - 75k over wt. Work bit above loss zone at 10,968'. CBU to check gas influx from flow back and clean hole. Max gas - 350 units (200 units over BG) Back ream out of hole from 10,938' to 9865' at 380 gpm - 1700 psi - 90 rpms Back ream out of hole from 9864' to 9400' at 380 gpm - 1700 psi - 90 rpms Hole packed off, not able to circ, pick up joint f/ pipe shed, working pipe down w/ rotation to 9475', work back up to 9300', found spot that would circ @ 9300'. During no circ and trying to work pipe, max torque of 25k on rotation to keep pipe free. Circ @ .5 bpm, stage up increasing .5 bpm after a while, 2bpm w/425 psi, to final of 500 gpm w/ 2550 psi. Max gas @ BU 190 units. Background around 120 units Back ream out of hole from 9300' to 9215' at 500 gpm - 2550 psi - 90 rpms Note: Total mud losses for 12 hour 84 bbls. Back ream out of hole from 9215' to 8037' at 500 gpm - 2550 psi - 90 rpms Circ hole clean, pump hi-vis sweep, follow by circ @ 550 gpm w/2700 psi. Note: Total mud losses f/12 hour 54.8 bbls. Total losses f/ day 138.8 bbls. Total losses f/ well is 1143.65 bbls. Background gas 30 units Circ sweep out of hole @ 550 gpm w/ 2700 psi. Mostley fines ( LCM ?) Printed: 5/212005 2:02:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KOKODA #5 KOKODA #5 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 3/6/2005 Rig Release: 4/25/2005 Rig Number: Spud Date: 3/712005 End: 4/25/2005 Group: 4/6/2005 00:00 - 00:45 0.75 DRILL CIRC INTRM2 in returns of bottoms up, next BU was clean. 00:45 - 01 :00 0.25 DRILL OBSV INTRM2 Monitor well ...well breathing 01 :00 - 03:30 2.50 DRILL TRIP INTRM2 Pump out of the hole 03:30 - 03:45 0.25 DRILL OBSV INTRM2 Monitor well. slight flow 03:45 - 05:15 1.50 DRILL TRIP INTRM2 Pump out of the hole 05: 15 - 05:30 0.25 DRILL OBSV INTRM2 Monitor well...very slight flow 05:30 - 09:45 4.25 DRILL TRIP INTRM2 Pump out of the hole to 3396' Shut off agitator in pit 5. Confirm correct I fill-up. 1 109:45 _ 10:00 0.25 DRILL OBSV INTRM2 Monitor well. blow down top drive. Line up on trip tank. Hole static 10:00 - 12:00 2.00 DRILL TRIP INTRM2 POOH on elevators. increase speed from 6'/ min to 60'/min over 5 stands. Hole taking proper fill. POOH to BHA @ 1138'. Calc fill = 55.75, Actual fill = 64.25. Total fluid lost over last 12 hrs = 35.3 bbls 12:00 - 12:30 0.50 DRILL TRIP INTRM2 POOH w/ HWDP. LD ghost reamer. Reamer in guage @ 8.5" 12:30 - 14:45 2.25 DRILL PULD INTRM2 Remove sources f/ BHA. UD BHA. Clean rig floor. 14:45 - 15:30 0.75 DRILL PULD INTRM2 PU BHA #7 15:30 - 18:30 3.00 DRILL TRIP INTRM2 Trip in hole w/ BHA #7, filling dp every 10 stands. 18:30 - 19:15 0.75 RIGMNT RSRV INTRM2 I Service top drive. 19:15 - 22:15 3.00 DRILL TRIP INTRM2 ITriP in hole w/ BHA #7, filling dp every 10 stands. 22:15 - 23:15 1.00 RIGMNT RSRV INTRM2 Slip and cut 58', 1 1/4" drilling line. Adjust brakes on drawworks. 23: 15 - 00:00 0.75 DRILL CIRC INTRM2 I Circulate stagging pumps up f/ 2bpm to 9 bpm. BG gas 15-25 units. Max 74 units w/ circ @ shoe Note Total losses f/ today 35.3 bbls. Total mud loss to well to date 1178.95 bbls. 4/7/2005 00:00 - 00:30 0.50 DRILL CIRC INTRM2 Finish circ and condition mud Up wt 185 Dn 186 00:30 - 00:45 0.25 DRILL WIPR INTRM2 RIH from 8030' to 8071' and tag bridge 00:45 - 12:00 11.25 DRILL WIPR INTRM2 Wash and ream from 8071 to 8230' Hole packing off. Max torq 25K Pumped sweep @ 8230' with increase of cuttings over shakers. Continue reaming to 8430 .Hole packing off and torquing up. 12 hr loss 48.3 bbls Midnight to noon: high gas was 210 units @ 8405'. Avg BG gas 100 112:00 - 13:45 units. 1.75 DRILL WIPR INTRM2 Continue reaming to 8487' 113:45 - 14:45 1.00 DRILL WIPR INTRM2 Pump out f/8487' to 8000' (csg shoe @ 8031'). 14:45 - 15:30 0.75 DRILL CIRC INTRM2 Circ bottoms up @ 470 gpm w/1550 psi. 15:30 - 16:30 1.00 DRILL WIPR INTRM2 RIH to bridge @ 8270'. I Wiper trip gas 90 units. 16:30 - 00:00 7.50 I DRILL REAM INTRM2 Reaming f/8270' to 8857'. Max gas 180 units @ 8495'. Avg BG gas 120 units. f/ noon to midnight. 12hr mud losses 2.9 bbls. total losses f/ day 51.2 bbls. Total losses to well 1205.8 bbls. 4/8/2005 00:00 - 01 :30 1.50 DRILL REAM INTRM2 Ream from 8857 to 8963', Pump viscous sweep 01 :30 - 03:30 2.00 DRILL REAM INTRM2 Try pulling then pumping out of the hole. no luck. Back ream 8963 to 8511' 03:30 - 06:30 3.00 DRILL REAM INTRM2 Hole packed off, lost circulation, worked pipe w/ rotation. from 8511' to 8003' slowly regain circulation. 06:30 - 08:00 1.50 DRILL CIRC INTRM2 Pump Hi Vis sweep + 2 BU with no significant increase in cuttings. 08:00 - 12:00 4.00 DRILL REAM INTRM2 RIH on elevators from 8003 to 8323' hole tight. Wash from 8323 to 8375 w/90 spm @ 1330 psi. Could not wash below 8375. Ream from 8375 to 8700' w 50-70 rpm w/100 spm @ 1330 psi String speed 0-5 ftlmin. Midnight to noon: BG gas 150 units. High 230 units @ 8323'. Midnight to noon mud loss 26 bbls. Printed: 5/212005 2:02:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KOKODA #5 KOKODA #5 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 3/6/2005 Rig Release: 4/25/2005 Rig Number: Spud Date: 3/712005 End: 4/25/2005 Group: 4/8/2005 12:00 - 00:00 12.00 DRILL REAM INTRM2 Ream f/8375' to 10416'. At 8979' change rotary to 30 rpm, 91 spm w/ 1340 psi and 44% flow. Increase rotary f/30 to 70 rpm 90-106 spm w/ 1440-1570 psi, string speed 9-15 ftlmin. Tight hole @ 9338'-9345'. Increase rotary to 120 rpm w/116 spm. taking too much weight. Slow pumps to 20 psm and spud through tight spot, then go back to 50-120 rpm w/104 spm @ 1650-1700 psi, 44-46% flow. Noon to midnight: background gas 190 units. Max gas 390 units @ 10235' . Noon to midnight mud losses 28.7 bbls. Total loss f/ day 54.7 bbls. Total loss to well 1260.5 bbls. 4/9/2005 00:00 - 12:00 12.00 DRILL REAM INTRM2 Ream f/10416' to 11,114. Ream w/120 rpm w/104 spm{440 gpm) @ 1650-1700 psi, 44-46% flow. At 10598' increase pump rate to 109 spm(461gpm) w/1750-1800 psi, 46% flow. At 0730 hrs pump 10 bbls LCM pill20#/bbl{ 7.4 ppb dynared med, 7.4 ppb dynared fine, 5.2 ppb I 5-2<)0) down "It p;pe. No 'o..e, whe" ..,m;", !hroo,h 10968'. At 11060' Torqued up and stopped rotateing maintained circulation while working pipe for 30 min. Regained rotation and reamed to 11,114 w/ i 100 rpm, 74 spm, w/950 psi @40% I Midnight-noon gas high= 295 units@10906, Avg=200 units 12 hr mud loss 49 bbls 12:00 - 12:15 0.25 DRILL REAM INTRM2 Ream from 11,114 to TD @ 11,122 12:15 - 14:45 2.50 DRILL CIRC INTRM2 . Circulate and clean up well. Weight up to 12.3+ ppg. over 2 I circulations. lost 56 bbls mud during weight up. Shut down monitor well. Well breathing due to increased ECD. 210 units gas when first on bottom. 150 units gas at BU, average 130 units while circulating. Take SPR @ 11122 MD, 10300 TVD. #1 = 35 stks @ 420 psi, 45 stks @ 470, #2 35 stks@360, 45 stks @ 450 psi. 14:45 - 00:00 9.25 DRILL TRIP INTRM2 POOH pumping 26 spm (2.5 bpm) @ 280 psi. @40 rpm @ 7'Imin.. At 10972 increase pump to 71 spm @ 860 psi and 30 rpm.. At 10787' spot 80 bbl LCM pill. Continue out of hole to 8720' pumping 4.7 bbl/min @ 600 psi 30-90 rpm. Noon-midnight max gas 380 units @ 9000', Avg. = 140 units 12 hr mud loss 71 bbls. well total for 24 hrs 120.1, well total 1 ,323 bbls 4/10/2005 00:00 - 00:30 0.50 DRILL TRIP INTRM2 Circ BU from 8720'. Circ @ 47 spm (4 3/4 bpm) w/550-600 psi. 00:30 - 01 :45 1.25 DRILL OBSV INTRM2 Monitor well for breathing. Flowed back 5 bbls w/ flow continualy decreasing. 01 :45 - 04:30 2.75 DRILL TRIP INTRM2 Pump out of hole w/o rotation from 8720'- 8003' . Pump 47 spm, (43/4 bpm) w/550 psi till @ 8280', then slow to 18 spm while leaving a 30 bbl LCM pill in hole, while pulling f/8280' to 8003'. 04:30 - 05:00 0.50 DRILL TRIP INTRM2 POOH 5 stds on elevators from 8003 - 7539' 2.25 bbl actual fill 3.5 bbl calc. 05:00 - 05:30 0.50 DRILL OBSV INTRM2 Monitor well (static) 05:30 - 06:45 1.25 DRILL CIRC INTRM2 Circ BU aboove LCM pill. Circ @ 47 spm w/500 psi. 06:45 - 07:00 0.25 DRILL OBSV INTRM2 Monitor well - very slight breathing 07:00 - 09:00 2.00 DRILL TRIP INTRM2 POOH 10 stds on elevators from 7539 - 6611' eratic hole fill. 09:00 - 12:00 3.00 DRILL TRIP INTRM2 Pump out of hole f/6611' to 4846' at 30 stks (3bbl/min) w/320# at 20% flow. w/ correct fill. Note: Max gas f/ midnight to noon was 178 units while pumping @ 8720'. Avg 100 units. Mud losses f/12 hrs f/ midnight to noon =19.6 bbls. 12:00 - 12:45 0.75 DRILL TRIP INTRM2 Pump out of hole f/ 4846' to 4289' at 30 stks (3bbl/min) w/ 300# at 20% flow. w/ correct fill. 12:45 -13:15 0.50 DRILL TRIP INTRM2 Monitor well. Static. Pull on elevators f/4289' to 3826', proper fill. Printed: 51212005 2:02:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KOKODA #5 KOKODA #5 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 3/6/2005 Rig Release: 4/25/2005 Rig Number: Spud Date: 3/712005 End: 4/25/2005 Group: 4/10/2005 13:15 - 13:30 0.25 DRILL OBSV INTRM2 Monitor well (static) 13:30 - 14:00 0.50 DRILL CIRC INTRM2 Pump dry job, blow down top drive. 14:00 - 16:00 2.00 DRILL TRIP INTRM2 POOH. Correct fill. Calculated fill f/ entire trip out = 96.35 bbls, actual 111.85 bbls. 16:00 - 16:45 0.75 DRILL PULD INTRM2 UD BHA #7. Clean rig floor. 16:45 - 19:00 2.251 WELCT OTHR INTRM2 Change out top pipe rams f/3 1/2"x6" to 4 1/2" x 7" variable rams. RU and test rams to 250 psi low and 5000 psi high. RID test equipment. 19:00 - 20:15 1.25 RIGMNT RSRV INTRM2 Change out 4 1/2" IF saver sub on top drive. 20:15 - 20:45 0.50 CASE RURD INTRM2 Prepare Baker Oil Tool circ head. Install 6.77' 5" pup above safety valve and a 14.77' 5" pup below. 20:45 - 21 :45 1.00 CASE RURD INTRM2 RU to run T' 26ppf L-80 BTC-M csg w/ PES I torque rings installed in collars. 21 :45 - 22:00 0.251 CASE SFTY INTRM2 PJSM on running 7" liner, with Baker Oil Tool, PESI, rig crew, casing crew, rig crew, and company rep. 22:00 - 00:00 2.00 CASE PULR INTRM2 Run 7" 26ppf L-80 BTC-M csg. Rays Oil Tools 7" eccentric shoe, 2 jts, Weatherford model 402 FC, 1 jt, insert landing collar in pin end of next jt (it #4), follow wIT' csg. 20 jts in hole @ midnight. Note: Max gas f/ noon to midnight 52 units while pumping out @ 4289'. Avg 40 units. Mud losses f/ noon to midnight 15.5 bbls. Total losses f/ day 35.1 bbls. Total mud losses to well 1358.1 bbls. 4/11/2005 00:00 - 02:00 2.00 CASE RUNL INTRM2 Hold PJSM. RU and run 75 jts of 7" 26#. L-80 casing w. 8 centalizers on bottom 8 jts to 3258' 02:00 - 03:30 1.50 CASE RUNL INTRM2 RD casing equipment P/U liner hanger and ZXP liner packer and prep to run. 03:30 - 04:30 1.00 CASE RUNL INTRM2 Circ 1 liner volume 04:30 - 12:00 7.50 CASE RUNL INTRM2 Continue running liner on drill pipe fill w/ hose every 5 stands and pump 20 bbls every 10 stds to 7991' Midnight to noon max gas 52 units @ 3300'. Avg 25 units. 12:00 -15:30 3.50 I CASE CIRC INTRM2 Circulate surface to surface. Stage up from 2 bpm @ 250 psi to 4.5 bpm @ 625 psi. loose 5 bbl over entire circ.. 15:30 - 15:45 0.25 CASE CIRC INTRM2 I torq & Drag pumps off PU 190, SO 180, Rot wt 183 10-40 rpm w/ 12.0-2.5 K Pump on @ 2 bpm Rot wt. 177 10-40 rpm torq 2.0-2.5K. 10 Irpm P/U 176, SO 177..20 rpm P/U 176, S/O 178. 15:45 - 00:00 8.25 CASE OTHR INTRM2 RIH on elevators to 8334' could not work thru. Brk circulation @ 2bpb w/375 pis and work pipe w/20K down, increase pump to 3 bpm w/425 psi and 20K down to 8364' increase pump to 4 bpm w/ 550 psi. unable to get below 8390. PU and rotate @ 10 rpm w/ 2K ft-Ibs & 4bpm @ 525 psi to 8440'.. Increase pumps to 4.5 bpm w/610psi. rot wt 184. work to 8466. can't get below 8466. stop rotating work pipe w 4 bpm @ 500 psi and 40K down. PU and rotate pipe 15 rpm w/ 4.5 bpm w 500 psi work pipe to 8490. Increase rpm to 20 w 25K ft-Ibs. Work pipe to 8514'. hole packed off. Work pipe unable to rotate of circulate. Work pipe from 150K to 275K. regained circulation and stage up to 5 bpm w/ 500psi Rotate @ 15 rpm w/ 25K torq work pipe to 8525' reduce pumps to 2 bpm w/ 600 psi. hole packing off. stop rotation. pull pipe to 300K. Hole packed off. working pipe to 310K Worked pipe free established circ @ 5bpm w/625psi at 8473'. Mud lost noon to midnight 13 bbls. mud lost f/ dau 17.2 bbls. Total mud lost to well 1375.3 bbls. Max gas noon to midnight 210 units @ 8400'. Avg 25 units. 4/12/2005 00:00 - 00:45 0.75 CASE RUNL INTRM2 Worked pipe from 8473'- 8535' w/ 30 rpm @ 2500ft-lb torq, w/5 bpm @ 625 psi. pipe torqued to 15k, lost 58 K weight & 300 psi pump Printed: 5/212005 2:02:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KOKODA #5 KOKODA #5 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 3/6/2005 Rig Release: 4/25/2005 Rig Number: Spud Date: 3/712005 End: 4/25/2005 Group: 02:00 - 03:45 03:45 - 04:00 04:00 - 07:00 07:00 - 09:30 09:30 - 15:45 15:45 - 16:15 16:15 - 19:45 19:45 - 20:30 20:30 - 21 :30 21 :30 - 22:00 22:00 - 00:00 4/13/2005 00:00 - 07:15 07:15 - 08:30 i 108:30 - 09:30 09:30 - 14:00 pressure. Flow remained the same @ 38%. wt loss is equal to liner weight. 1.25 CASE RUNL INTRM2 Wash and rotate from 8535'-8851' at 5 bpm and 325 psi, rotate at 10 rpm and 500 ft-Ibs torque, rot wt dn 132K. At 8851' pressure increased to 500 psi. shut down pump and rotation. pushed liner to 8871' with 10K down wt. Maybe inside of liner seal bore or on top of liner. Running tool appears to have released from liner, Est TOL @ 5,621' PU to 5,621' and Circ btms up, circ at 60 spm, 255 gpm, at 500 psi. max gas 245 units ave bgg 140 units I monitored well-static I POOH to liner running tool, calc fill, 44.25 bbls, actual fill 49.25 bbls Made service breaks on running tool and broke out rotating dog sub, LD running toolrecovered full running tool and safety release was still intact with liner wiper plug on btm of tool, wiper plug had a small piece of rubber missing RU and tested BOP's, tested rams, valves and manifold to 250 psi low and 5,000 psi high, tested Annular to 250 psi low and 3,500 psi, high, NOTE: Chuck Scheve with AOGCC waived witnessing of test, gained 10 gals of mud while testing BOP's Held PJSM then MU new Baker liner running tool RIH with liner running tool to Est TOL at 5,621', est circ at 1 bpm at 175 psi, st wt up 132K, dn wt 136K Latched onto TOL at 5,621' with 7" shoe at 8,871', PU to 220K and was able to move liner up hole, attempted to est circ at 8,871' with no success, PU liner to 8,797' and was able to est circ and rotation Circ a liner capacity at 8,797', staged pump rate up to 3 bpm at 500 psi, rotated liner at 7 rpm's with 4K ft-Ibbs torque RIH with 7" liner on DP slow from 8,797' to 8,871' and set down at 8,871', RIH with liner pumping 3 bpm at 500 psi with no rotation Washed liner down from 8,871' to 8,883', washed down at 15 rpm's and 3 bpm at 400 psi with 2-4K st wt down, attempted to RIH with liner with pump only and would not go down without rotating, ave BGG 125 units, max gas at btms up 236 units, Lost 5 bbls of mud last 24 Hrs, Total mud lost to hole 1,380.3 bbls 7.25 CASE RUNL INTRM2 Washed 7"liner down from 8,883' to 9,060', washed pipe down at 3 bpm at 300 psi and 20 rpm's with 3-5K ft-Ibs torque, attempted to RIH without rotation at 8,895' and 8,920' and would not go. Rotated and pumped down to 8,960' then washed down without rotation from 8,960' to 9,035' at 3 bpm and 375 psi. took weight and liner stopped, cont to I wash liner down with rotation from 9,035' to 9,060' when pipe stopped I and torqued up, rotated at 15 rpm with 3,500 ft-Ibs torque at 3 bpm and 1375 psi. 1.25 CASE RUNL INTRM2 Worked pipe at 9,060' with 350K up wt, stood back 1 stand and PU a single of DP, worked pipe up with 400K up wt and dn to 110K and worked pipe free. Circ liner at 8,982' at 4 bpm at 375 psi. (approx. 75 psi less than when last circ at 4 bpm-possible float washed out) st wt up 205K, dn wt 180K, rotated at 10 rpm's with 3,500 ft-Ibs torque while working pipe at 8,982'. 1.00 CASE CIRC INTRM2 Circulated and rotated at 3 bpm at 300 psi, 10 rpm's at 3-5K torq, worked liner from 8,982' down to 9,040' when hole packed off and was unable to circulate or rotate. 4.50 CASE RUNL INTRM2 Worked pipe up with 400+K st wt and slowly pulled liner out of hole from 9,040' to 8,950', stood back stand, cont to work pipe at 8,950' and 1.75 CASE RUNL INTRM2 0.25 CASE CIRC INTRM2 3.00 CASE RUNL INTRM2 2.50 CASE RUNL INTRM2 i 6.25 WELCT~ BOPE INTRM2 I 0.50 DRILL PULD INTRM2 3.50 DRILL TRIP INTRM2 0.75, CASE RUNL INTRM2 1.00 CASE CIRC INTRM2 0.50 CASE RUNL INTRM2 2.00 CASE RUNL INTRM2 Printed: 5/2/2005 2:02:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KOKODA #5 KOKODA #5 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 3/6/2005 Rig Release: 4/25/2005 Rig Number: Spud Date: 3/712005 End: 4/25/2005 Group: 4/13/2005 09:30 - 14:00 4.50 CASE RUNL INTRM2 was able to rotate liner at 10 rpm. est. circ at 2 bpm and pipe packed off and torqued up. Worked pipe up to 8,704' and after 3 attempts to circulate was unable to circulate no more than 10 bbls without packing off. Pulled out to 8,625' and est circ, Circ at 3 bpm at 300 psi., ave BGG 100 units, max gas 178 units 14:00 - 15:00 1.00 CASE RUNL INTRM2 Pumped out of hole with 7" liner from 8,625' to 7991 to inside 9 5/8" csg shoe at 8,031', . pumped out at 2 bpm at 250 psi 15:00 - 16:45 1.75 CASE CIRC INTRM2 Circ btms up at 7,991' then pumped a hi vis sweep and circ out of hole, had no increase in cuttings back from sweep, staged pump rate up to 8 bpm at 850 psi, rotated at 15 rpm's, Max gas at btms up was 175 units, BGG ave 50 units, st up wt 186K, dn wt 183K 16:45 - 17:00 0.25 CASE OTHR INTRM2 Monitored 15 min, well-static 17:00 - 00:00 7.00 CASE RUNL INTRM2 Pumped out of hole with 7" liner from 7,991' to 3,629', pumped out due I to swabbing from hanger/packer assembly, pumped out at 2 bpm at 100 psi, calc fill 37 bbls, actual fill 40 bbls, mud lost to hole last 24 hrs I 13.8 bbls, total mud lost to hole 1,394.1 bbls 4/14/2005 00:00 - 00:15 0.25 CASE RUNL INTRM2 Pumped out of hole with 7" liner from 3,629' to 3,347', pumped out due to swabbing from hanger/packer assembly, pumped out at 2 bpm at 100 psi, pumped out to stand above liner hanger assembly 00:15 - 00:30 0.25 CASE OTHR INTRM2 Monitored well at 3,347', well-static 00:30 - 01 :15 0.75 CASE OTHR INTRM2 Pumped dry job and stood back std of 5" DP, LD Baker liner hanger/packer assembly, hanger assembly looked ok 01:15 - 01:45 0.50 CASE OTHR INTRM2 RU Doyon's liner handling equipment 01 :45 - 02:00 0.25 CASE SFTY INTRM2 Held PJSM on LD 7" liner 102:00 - 07:15 5.25 CASE OTHR INTRM2 POOH and LD 75 jts, (3,218') of 7" 26#, L-80 BTC-M liner, recovered 9 ridgid centralizers and stop rings, 2-stop rings were dented and left 1 Ray Oil Tools 7" x 8-3/8" x4" aluminum centralizer that was on float shoe jt in the hole, no problems LD liner and hole took calc fill 07:15 - 08:00 0.75 CASE RURD INTRM2 RD Doyon's liner handling equipment and cleared rig floor, serviced top I 'drive 08:00-09:15 I 1.25 DRILL PULD INTRM2 MU 8 1/2"clean out BHA #8 and RIH to 981', MU 8 1/2" PDC bit with I near bit stab, flex dc's, HWDP, jars and ghost reamer while RIH to 981' 09:15 - 13:30 4.25 DRILL TRIP INTRM2 RIH from 981' to 8,000' (95/8" Shoe @ 8,031') 13:30 - 14:30 1.00 DRILL CIRC INTRM2 Circ btms up at 8,000', staged pump rate from 5 bpm at 550 psi up to 9.5 bpm at 1,200 psi, max gas at btms up 120 units, rot wt 197K, up wt 197K, dn wt 190K 14:30 - 00:00 9.50 DRILL REAM INTRM2 RIH from 8,000' and began taking weight at 8,098', reamed 8 1/2" hole from 8,098' to 8,960' (862'), reamed at 70-120 rpm's, 120 spm, 510 gpm with 1,800 psi, with pumps on rotating wt 200K, up wt 191 K, dn wt 199K, worked thru tight spots at 8,350',8,430',8,471',8,500' and 8,750', ave BGG 75 units, max gas 138 units from 8,450', no mud loss to hole last 24 hrs, total losses to hole 1,394.1 bbls 4/15/2005 00:00 -14:15 14.25 DRILL REAM INTRM2 I Cont to ream 8 1/2" hole from 8,960' to 9,655 (695') when progress slowed and began torquing up and packing off, reamed at 90-100 rpm's, 120 spm, 510 gpm with 1,900 psi, torque ranged from 5-11K ft-Ibs, rot wt 210K, up wt 225K, dn wt 185K, worked thru tight spots at 9,030' to 9,080',9,300',9,521' 9,615' and 9,644', ave BGG 100 units, max gas 198 units from 9,518' and 168 units from 9,633", no mud loss I to hole while reaming 14:15 -14:30 0.25 DRILL OBSV INTRM2 I Monitored well at 9,655', well-static 14:30 - 16:15 1.751 DRILL ¡TRIP INTRM2 . Pumped out of hole from 9,655' to 8,010' (csg shoe @ 8,031'), pumped I i out 375 gpm at 1,100 psi, ave 50K drag over st wt while pumping out to shoe, attempted to backream out but would pack-off and torque up to Printed: 51212005 2:02:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KOKODA #5 KOKODA #5 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 3/6/2005 Rig Release: 4/25/2005 Rig Number: Spud Date: 3/712005 End: 4/25/2005 Group: 4/15/2005 14:30 -16:15 1.75 DRILL TRIP INTRM2 16:15 - 17:45 1.50 DRILL CIRC INTRM2 17:45 - 18:00 0.25 DRILL OBSV INTRM2 18:00 - 21 :30 3.50 DRILL TRIP IINTRM2 21 :30 - 00:00 2.50 DRILL PULD INTRM2 4/16/2005 00:00 - 01:15 I 01 :15 - 04:15 04: 15 - 05:30 05:30 - 06:00 06:00 - 00:00 4/17/2005 00:00 - 12:45 1.25 DRILL PULD INTRM2 I 3.00 DRILL TRIP INTRM2 1.25 RIGMNT RSRV INTRM2 0.50 DRILL OTHR INTRM2 18.00 DRILL REAM INTRM2 12.75 DRILL REAM INTRM2 12:45 - 14:30 1.75 DRILL REAM INTRM2 14:30 - 15:00 0.50 DRILL CIRC INTRM2 15:00 - 00:00 9.00 DRILL DRLG INTRM2 I 16K ft-Ibs, while pumping out of hole attempted to run back in hole with no pump and was not able to go down hole Pumped hi vis sweep at 8,010' and circ out of hole, had no increase in cuttings back from sweep, circ at 510 gpm at 1,700 psi, st wt up 197K, dn wt 194K, max gas at btms up 145 units, ave gas 100 units Monitored well at shoe-static POOH wet 10 stds and hole took calc fill, pumped dry job and POOH to BHA to 981', monitored well at HWDP, well-static POOH and stood back HWDP, LD ghost reamer, stood back reaming HWDP and jars, found 2 jts of HWDP bent, LD 3 jts of HWDP, near bit stab and bit, found ghost reamer in gauge but one of the blades worn approx 2" on lower end of hardfacing of the blade, calc fill on trip out 68 bbls, actual fill 70.5 bbls, lost 46 bbls mud to hole last 24 hrs, total mud lost to hole 1 ,440 bbls MU reaming BHA #9 and RIH to 979', MU RR 8 1/2" Hycalog PDC bit on Security's near bit reamer dressed to open hole to 9 3/8" & RIH with string stabilizer, HWDP and jars, PU 3 jts of HWDP while RIH to 979' RIH with BHA #9 from 979' to 7,940' Slip and cut 65' of drlg line and serviced top drive RIH from 7,940' to 8,060', est circ at 510 gpm at 1,675 psi, 100 rpm's with 3K ft-Ibs torque, rot wt 189K, up wt and dn wt 185K, increased pump rate to 580 gpm at 2,050 psi and sheared pins in reamer and opened tool to 9 3/8", saw no change in pressure or torque Reamed and opened hole from 8 1/2" to 9 3/8" from 8,060' to 9,127' (1,067'), opened hole at 2-5K wOb, 110 rpm's, 120 spm, 510 gpm at 1,825 psi, ave 5.5K ft-Ibs torque, rot wt 208K, up wt 228K, dn wt 188K, 12.3 ppg MW, ave BGG 100 units, max gas 150 units from 8,525' and 153 units from 9,123' While reaming thru hard spots would torque up to 15K ft-Ibs and try to packoff, reamed thru hard spots from 8,338' to 8,350' (took 1/2 hr), from 18,520' to 8,550' (took 41/2 hrs) and from 8,933' to 8,936' (took 1/2 hr) While opening hole with out problems would ave 2-3' /min string speed Reamed and opened 81/2" hole to 9 3/8" from 9,127' to 9,658' (531') took 71/2 hrs to open hole, opened hole at 2-5K wOb, 100-110 rpm's, 120 spm, 1,900 psi, ave 7K ft-Ibs torque, rot wt 216K, up wt 250K, dn wt 180K, ave bgg 150 units, max gas 251 units at 9,650', pumped 35 bbl hi vis sweep at 9,605' and had 10-20% increase in cuttings, worked thru I tight spots due to packing off and torquing up from 9,580' to 9,590' ! (took 1 hr) and from 9,600' to 9,658' (took 41/4 hrs, reamed thru 2X) Reamed and opened 8 1/2" hole to 9 3/8" from 9,658' to 9,718' (60') and packed off 4X's with a hard spot at 9,668' and a tight spot at 9,692' Circ and worked pipe at 9,718', slowed pump rate to 168 gpm at 650 psi and staged pump rate up to 525 gpm at 1,900 psi Reamed and opened 8 1/2" hole to 9 3/8" from 9,718' to 10,444' MD/ 9,762' TVD, (726') opened hole with 2-5K wob, 130 rpm's, 127 spm, i 540 gpm at 2,150 psi, ave 8500 ft-Ibs torque, rot wt 225K, up wt 265K, dn wt 175K, 12.3 ppg mw, ave BGG 190 units, max gas 300 units from 10,200', had a hard spot at 10,067', while attempting to get down wt's on conn's at times would need to pump to get std to go down, NOTE: After 00:00 hrs pumped 50 bbl hi vis sweep at 10,444' and initially with sweep back we had a 5-10% increase in cuttings then after approx 200 bbls had an add. 100% increase in cuttings back from behind the sweep, ave cuttings size have been 1-4 mm, cuttings back during Printed: 51212005 2:02:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KOKODA #5 KOKODA #5 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 3/6/2005 Rig Release: 4/25/2005 Rig Number: Spud Date: 3/712005 End: 4/25/2005 Group: 4/17/2005 15:00 - 00:00 9.00 DRILL DRLG INTRM2 sweep were 5-12 mm and mostly rounded on the edges 4/18/2005 00:00 - 01 :00 1.00 DRILL REAM INTRM2 Reamed and opened 8 1/2" hole from 10,444' to 10,495' (51'), opened hole at 2-5K wob, 130 rpm's, 540 gpm at 2,150 psi, ave 8500 ft-Ibs torque, rot wt 225K, up wt 265K, dn wt 175K pumped hi vis sweep at 10,444', ave BGG 180 units, max gas 208 units from 10,450' 01 :00 - 01 :30 0.50 DRILL CIRC ; INTRM2 Fin circ sweep out of hole, initially with sweep back we had a 5-10% increase in cuttings then after approx 200 bbls (2,000 stks) had an add. 100% increase in cuttings back from behind the sweep, aye cuttings size have been 1-4 mm, cuttings back during sweep were 5-12 mm and mostly rounded on the edges, circ sweep out at 540 gpm at 2,150 psi and 130 rpms 01 :30 - 09:00 7.50 DRILL REAM INTRM2 I Reamed and opened 8 1/2" hole from 10,495' to 10,819' (324'), opened hole at 2-5K wOb, 130 rpm's, 127 spm, 540 gpm at 2,200 psi, 9K ft-Ibs torque, rot wt 228K, up wt 272K, dn wt 175K, pumped hi vis sweep at 10,629' and after sweep was out of hole 200 bbls had a 50% increase in cuttings back from sweep, while opening hole at 10,740 began to see partial losses (approx 10-20%) began adding LCM at 21.5 ppb and circ down hole 09:00 - 09:30 0.50 DRILL CIRC INTRM2 Circ hole at a reduced rate and monitored for losses, circ at 90 spm, 380 gpm at 1,375 psi, circ improved to 95% with LCM sweep around, as of 09:30 hrs had lost a total of 69 bbls 09:30 - 15:30 6.00 DRILL REAM INTRM2 Reamed and opened hole from 10,816' to 11,120' MD/1 0,300' TVD (304') opened hole at 2-9K wob, 130 rpm's, 120 spm, 510 gpm at 2,150 psi with 9K ft-Ibs torque, rot wt 232K, up wt 265K, dn wt 150K, opened hole with approx 95% returns, ave BGG 175 units, max gas 199 units from 10,950'. 15:30 - 20:15 4.75 DRILL CIRC INTRM2 Circ high vis sweep at 11,120' and circ out of hole, had 100% increase in cuttings back from sweep, cuttings were 250 bbls 2,500 stks, behind calc, then pumped 60 bbls of 21.5 ppb LCM pill followed by a weighted hi vis sweep at 2# over MW, with wt'd sweep out saw no increase in cuttings, then circ and raised MW from 12.3 ppg to 12.5 ppg, circ hole at 120 spm, 510 gpm at 2,150 psi, 140 rpm's with 9K ft-Ibs torque 20:15 - 20:45 0.50 DRILL OBSV INTRM2 Observed well, breathing slightly, performed exhale test, initial rate .4 I bpm and after 20 min rate down to .2 bpm 20:45 - 23:00 2.25 DRILL TRIP INTRM2 Began POOH to run liner, began pumping out to lay LCM pill on btm, had to rotate also to pull out, pumped 60 bbl, 24 ppb LCM pill and spotted 35 bbls of pill from 11,083' to 10,550', cont to pump and rotate out of hole from 10,550' at an ave 25-80 rpm's and 30 spm, 126 gpm at 475 psi with 10-15K torque, while POOH at 10,240' DP torqued up and hole packed off 23:00 - 00:00 1.00 DRILL OTHR INTRM2 Began working pipe at 10,240' was able to get pipe to rotate and worked pipe down to 10,270', unable to circ due to packing off and while working pipe have no jar movement, would pressure up on DP with no i circ max pressure put on DP 1,000 psi, worked pipe up to 325K and down to 125K, would attempt to work pipe up and after 4-5' would torque up and stall dp, mud lost to hole from 09:30 to 24:00 hrs was 97 . bbls, mud lost to hole last 24 hrs 166 bbls and total mud lost to hole I 11,606 bbls 4/19/2005 00:00 - 02:30 ' 2.50 DRILL OTHR INTRM2 Worked and rotated packed off pipe down with rotation only from 10,270' to 10,358', attempted to circ while working down with no circ or )ar movement, rotated pipe at 110-140 rpms and 215K rot wt, max up ¡wt 325K, dn wt 125K, while working down pipe torqued up and stalled i out Printed: 5/212005 2:02:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KOKODA #5 KOKODA #5 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 3/6/2005 Rig Release: 4/25/2005 Rig Number: Spud Date: 3/7/2005 End: 4/25/2005 Group: 4/19/2005 02:30 - 03:30 1.00 DRILL OTHR INTRM2 Pulled 390K st wt and worked pipe with no rotation up from 10,358' to 10,345', stood back 1 std of DP 03:30 - 04:30 1.00 DRILL OTHR INTRM2 PU 1 jt of DP and worked pipe down to 10,360' slacking off 50-75K wt down and was able to re-establish rotation at 50 rpm's and 9K ft-Ibs torque 04:30 - 12:00 7.50 DRILL OTHR INTRM2 Began working pipe up with rotation only applying pressure in attempts to circ hole, was able to rotate pipe with 80-90 rpm's with 13K ft-Ibs torque, worked pipe up slowly at .5 to 1 '/min, if we attempted to go faster or rotate faster would stall out DP, was not able to circ or see any jar movement, worked pipe up from 10,360' to 10,198' with 220K rot wt when we lost 35K st. wt to 185K 12:00 - 14:15 2.25 FISH CIRC IINTRM2 Est circ and staged pumps up slowly due to packing off, initial circ rate of 42 gpm at 410 psi and increased rate to 510 gpm at 1,375 psi, rotated pipe at 100 rpm's and 3.5K ft-Ibs torque with 185K rot wt 14:15 - 15:15 1.00 FISH CIRC INTRM2 Circ hole while working pipe from 10,204' to 10,161', circ 2X btms up at 530 gpm at 1,400 psi, 100 rpm's and 3.5K ft-Ibs torque, circ out LCM and shale 15:15 - 17:15 2.00 FISH CIRC INTRM2 Pumped 35 bbl hi vis sweep from 10,204' and circ out, saw no increase in cuttings, circ a total of 2X btms up, circ at 530 gpm at 1,400 psi, 100 rpm's and 3.5K ft-Ibs torque, stood back 1 std POOH to 10,161' 17:15 - 20:15 3.00 FISH CIRC INTRM2 Pumped and add. 31 bbl hi vis sweep at 10,161' and circ hole till shakers cleaned up, saw no increase in cuttings from sweep, (circ out shale) circ at 130 spm, 550 gpm at 1,475 psi with 140 rpm's, 4K ft-Ibs torque and 179K rot wt, 12.5 ppg MW with an ave BGG of 100 units, circ a total of 2,300 bbls (2300 stks) approx 5X btms up 20:15 - 21:15 1.00 FISH FISH INTRM2 Est circ at 168 gpm at 400 psi and 20 rpm's, rot wt 190K, up wt 192K and dn wt 177K, slowly washed down to 10,204' and began to slack off st wt and had an increase in pressure and torque, also lost returns while attempting to screw into fish, PU and had an add. 30K st wt and while PU weight fell off and still had no circ or rotation, worked pipe and regained rotation and circ. decision was made to POOH 21:15 - 00:00 2.75 FISH TRIP INTRM2 POOH and monitored well at shoe, well-static, pumped dry job and cont. POOH with a total of 50 stds of 5" DP, no mud loss last 24 hrs 4/20/2005 00:00 - 01:15 1.25 FISH TRIP INTRM2 Fin POOH with 5" DP after twisting off while working pipe from packing off, POOH with 46 stds and 1 single, found pipe to have parted on pin end of top jt of 3rd std above HWDP, fish left in hole 8 jts of 5" DP and BHA #9, total length 1,227', est TOF at 8,979' with bit at 10,204' 01:15 - 01:45 0.50 WELCT OTHR INTRM2 Pulled wear bushing 01 :45 - 07:00 5.25 WELCT BOPE INTRM2 RU and tested BOP's, tested valves, manifold and rams to 250 psi low and 5,000 psi high, tested annular to 250 psi and 3,500 psi, tested both rams with 5" DP and VBR's with 7" for upcoming liner run, Note: John Crisp with AOGCC waived witnessing of test. 07:00 - 07:30 0.50 WELCT INTRM2 Installed wear bushing 07:30 - 09:30 2.00 FISH INTRM2 MU fishing BHA #10 and RIH to 407', MU Baker 83/8" cut lip guide with 6 3/8" overshot, bumper sub, oil jars, 12-65/8" DC's, accelerator jars and pump out sub 09:30 - 12:15 2.75 FISH [TRIP INTRM2 RIH from 407' to 8,015' 12:15 - 13:15 1.00 RIGMNT RGRP INTRM2 Repaired loose wire on top drive, was unable to rotate pipe at shoe 13:15 -13:30 0.25 FISH CIRC INTRM2 Est circ at 8,015', circ at 210 gpm, 500 psi, rotated at 50 rpm's with 3K ft-Ibs torque, rot wt 190K, up wt 190K, dn wt 185K 13:30 - 15:45 2.25 FISH CIRC INTRM2 Washed down with fishing assembly from 8,015' to 8,380' and started taking wt at 8,380', began to wash and rotate down from 8,380' to 8,943' (est TOF at 8,979'), washed down at 210 gpm at 500 psi with 50 Printed: 5/212005 2:02:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KOKODA #5 KOKODA #5 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 3/6/2005 Rig Release: 4/25/2005 Rig Number: Spud Date: 3/712005 End: 4/25/2005 Group: 4/20/2005 13:30 - 15:45 2.25 FISH CIRC INTRM2 rpm's and 4-14K ft-Ibs torque 15:45 - 17:00 1.25 FISH CIRC INTRM2 Pumped 30 bbl high vis sweep at 8,943' and worked pipe up to 8,850' while circ out sweep, had a slight increase in cuttings back from sweep, circ hole at 550 gpm at 1,700 psi with 50 rpm's and 5-14K ft-Ibs torque, rot wt 207K, up wt 225K, dn wt -0- with pumps off, max gas 190 units from 8,380', ave BGG 100 units 117:00 - 19:30 2.50 FISH FISH INTRM2 Washed down and tagged TOF at 8,983' (est TOF at 8,979'), attempted to work over fish with varied RPM's and pump rates with no success, appears to be going along side of fish or could be on fill, would try to go deeper and would torque up and stall DP, decision was made to POOH 19:30 - 21:15 . 1.75 FISH TRIP INTRM2 Monitored well-static, attempted to POOH on elevators and had excess drag, pumped and rotated out of hole from 8,983' to 8,012', had an increase in torque and drag from 8,555' to 8,544' and worked thru, no other problems POOH to shoe, pumped at 3 bpm at 400 psi and rotated at 40 rpm's 21:15-22:00 0.75 FISH CIRC INTRM2 Circ btms up inside csg shoe at 8,012', circ at 550 gpm, 1,600 psi with 50 rpm's and 3K ft-Ibs torque, no increase in cuttings at btms up, monitored well-static 22:00 - 00:00 2.00 FISH TRIP INTRM2 POOH wet 10 stds from 8,012' to 7,090' and hole took calc fill, pumped dry job and cont POOH to 3,841', no mud loss last 24 hrs 4/21/2005 00:00 - 00: 15 0.25 FISH TRIP INTRM2 POOH with fishing BHA #10 from 3,841' to 2,263' 00:15 - 01:30 1.25 RIGMNT RGRP INTRM2 Repaired hydraulic leak on top drive 01 :30 - 02:30 1.00. FISH TRIP INTRM2 POOH from 2,263' to BHA at 407' 02:30 - 03:00 0.50 FISH PULD INTRM2 POOH and stood back 4 stds of DC's and LD ace jars, inspected guide shoe and found cutlip guide flattened and curled in on btm and had no signs of working on fish 03:00 - 04:45 1.75 FISH PULD INTRM2 MU fishing BHA #11 and RIH to 411', MU Baker 81/2" x 6 3/8" burnover shoe, XO bushing, jars and 12- 6 5/8" DC's ACC jars and pump out sub 04:45 - 07: 15 2.50 FISH TRIP INTRM2 RIH from 411' to 8,023' 07:15 - 17:30 10.25 FISH WASH INTRM2 Est circ at 8,023' at 255 gpm at 750 psi, 50 rpm's, 3K ft-Ibs torque, rot wt 190K, up wt 190K, dn wt 184K, washed down from 8,023' to 8,375' then washed and reamed from 8,375' and hit tight spot at 8,536', worked thru tight spot and cont washing down, washed down to 9,036' at 465 gpm, 1,300 psi, 80 rpm's with 4-14K ft-Ibs torque, while washing down at 9,036' pipe torqued up and packed off loosing circ, max gas 135 units from 8,536', ave BGG 100 units with 12.5 ppg MW 17:30 - 19:15 1.75 FISH OTHR INTRM2 ¡Worked packed off pipe at 9,036', worked pipe from 9,036' up to 9,026' attempting to eire, pulled max 325K up wt and 1 OOK down wt, while attempting to circ hole regained rotation and while working pipe at 9,026' regained circ 19:15 - 21:30 2.25 FISH CIRC INTRM2 I Est circ at 100 gpm at 400 psi and staged pump rate up to 510 gpm, 1,500 psi, while circ hole and slowly working pipe up to 9,017' pipe packed off, worked pipe down to 9,033' and re-est. eire, staged pump rate up to 510 gpm at 1,500 psi and 110 rpm's with 5K ft-Ibs torque, i max gas 155 units, ave BGG 90 units 21 :30 - 00:00 2.50 FISH CIRC INTRM2 Began slowly backreaming out of hole from 9,033' to 8,749', backreamed out at an ave of 1 to 2'/min 1st 2 stds then increased to 4-5'/min, pumped out at 110 rpm's, 5-6K ft-Ibs torque, 510 gpm at 1,500 2.00 I FISH ! psi, 190K rot wt, 12.5 ppg MW, no mud loss last 24 hrs 4/22/2005 00:00 - 02:00 CIRC I INTRM2 I Cont to backream out of hole from 8,749' to 8,023', backreamed out at I 110 rpm's, 4-5K torque, circ at 510 gpm at 1,450 psi ! 02:00 - 03:00 1.00 FISH CIRC INTRM2 Circ hole clean at 8,023', circ at 530 gpm, 1,450 psi, 50 rpm's with 3K Printed: 5/212005 2:02:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KOKODA #5 KOKODA #5 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 3/6/2005 Rig Release: 4/25/2005 Rig Number: Spud Date: 3/712005 End: 4/25/2005 Group: ft-Ibs torque, rot wt 190K, monitored well-static POOH 5 stds wet and hole was taking calc fill, pumped dry job and cant POOH to BHA at 411' POOH and LD fishing BHA #11, jars, 12-6 5/8 DC's and burnover shoe, shoe was worn down 5" with cutright on btm and 6 3/8" ID gone Pulled wear bushing and installed test plug, Changed out upper set of 4 1/2" x 7" VBR's over to 3 1/2" x 6" VBR's, tested rams to 250 psi low and 5,000 psi high, pulled test plug and installed wear bushing RU and PU 30 jts of 31/2",9.3# L-80 tbg stinger and RIH to 941' Slip and cut 65' of drlg line and serviced top drive RIH with 31/2" cement stinger on 5" DP from 941' to 7,996' Est circ at 7,996' at 170 gpm at 500 psi, st wt up 165K, dn wt 164K, washed down from 7,996' and worked thru bridge at 8,406' and cont to wash down to 8,424', st wt up 175K, dn wt 171 K Began circ btms up at 8,424' and while working pipe at 8,392' was unable to go back down, cont to circ btms up at 8,392', circ at 340 gpm at 875 psi, with 12.6 ppg MW in and out, max gas 113 units, ave BGG 80 units 1.75 ABAND CIRC ABANDN Spotted 20 bbl hi vis pill at 8,392' and POOH to 8,331' and circ btms up, saw no sign of pill on btms up, circ at 340 gpm at 875 psi with 165K st wt, held PJSM with Dowell and ASCR vac truck drivers on setting of cement plug 1.00 CEMEN PLUG ABANDN Dowell pumped 5 bbls fresh water and pressure tested lines to 3,000 psi, pumped 10 more bbls fresh water and followed with 46 bbls, 169 sxs of class G cement at 15.8 ppg and 1.53 yield, ave 4 bpm at 750 psi, then pumped 1.8 bbls water behind cement, turned over to the rig and rig pumped 131 bbls of 12.6 ppg mud to balance plug, initial rate 6 bpm at 700 psi and slowed to 4 bpm at 375 psi and max pressure before shutting down was 625 psi, CIP at 22:00 hrs with btm of plug at 8,331' and est TOC at 7,831' (Note: cement volume calc on 300' of 93/8" hole plus 20% excess and 200' inside 9 5/8" csg) POOH slow 11 stds from 8,331' to 7,315' Pumped down a DP wiper dart and began circ hole clean at 7,315', circ at 250 gpm at 600 psi Fin circ btms up at 7,315' after pumping DP wiper dart, increased rate from 250 gpm to 340 gpm at 750 psi, had slight increase in PH with no cmt at btms up, st wt 147K Held PJSM with Dowell on cementing 133/8" x 9 5/8" Annulus and with rig crew on LD 5" DP Cemented 13 3/8" x 9 5/8" annulus to 500' with 30 bbls, 180 sxs of AS 1 at 15.8 ppg and .93 yield, ave 2 bpm at 340 psi, CIP at 01 :20 hrs, shut in with 200 psi, rig began POOH LD excess DP POOH LD 89 jts of 5" DP while W.O.C., POOH to 4,550' RIH with 30 stds DP from derrick , Removed excess DP from pipe shed and cleaned rig floor, waited on cement a total of 8 hrs RIH looking for TOC from 7,346' to 8,082' and had not seen any cement, washed down to 8,210' at 1 bpm at 300 psi and no sign of cement Circ btms up at 8,210', at btms up did not see any cement, only an increase in PH to 11.4, initial circ rate 250 gpm at 500 psi and increased to 336 gpm at 900 psi with 166K st wt RIH washing down at 1 bpm at 300 psi from 8,210' and tagged TOC at 4/22/2005 02:00 - 03:00 1.00 FISH CIRC INTRM2 03:00 - 06:15 3.25 FISH TRIP INTRM2 06: 15 - 08:30 2.25 FISH PULD INTRM2 08:30 - 10:30 2.00 WELCT INTRM2 10:30 - 13:00 2.50 ABAND PULD ABANDN 13:00 - 14:30 1.50 RIGMNT RSRV ABANDN 14:30 - 17:00 2.50 ABAND TRIP ABANDN 17:00 - 17:30 0.50 ABAND CIRC ABANDN 17:30 - 19:15 1.75 ABAND CIRC ABANDN 19:15-21:00 21 :00 - 22:00 22:00 - 23:15 1.25 ABAND TRIP ABANDN 23: 15 - 00:00 0.75 ABAND CIRC ABANDN 4/23/2005 00:00 - 00:30 0.50 ABAND CIRC ABANDN I 00:30 - 00:45 0.25 CEMElSFTY ABANDN 00:45 - 01 :30 0.75 CEMEN PUMP ABANDN 01 :30 - 03:45 2.25 ABAND PULD I ABANDN 03:45 - 04:45 1.00 ABANDfRIP ABANDN 04:45 - 06:00 1.25 ABAND OTHR ABANDN 06:00 - 07:30 1.50 CEMEN TRIP ABANDN I I 107:30 - 08:30 1.00 CEME1C'RC ABANDN 08:30 - 09:00 0.50 CEMEN TRIP ABANDN I Printed: 5/212005 2:02:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KOKODA #5 KOKODA #5 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 3/6/2005 Rig Release: 4/25/2005 Rig Number: Spud Date: 3/712005 End: 4/25/2005 Group: 4/23/2005 08:30 - 09:00 0.50 CEMEN TRIP ABANDN 8,326', calc TOC was at 7,831'. NOTE: John Spaulding with AOGCC and Tim Lawlor with BLM on location to witness tag 09:00 - 10:00 1.00 CEMEN CIRC ABANDN Pumped and spotted 46 bbl hi vis pill at 8,326', circ at 336 gpm at 950 psi 10:00-11:15 1.25 CEMEN CIRC ABANDN POOH to 8,177' and circ btms up, at btms up had approx 20 bbls of hi vis pill back at surface, circ at 336 gpm, 950 psi with 12.5 ppg MW in and out, held PJSM on setting cement plug 11:15-12:30 1.25 CEMEN PLUG ABANDN I Dowell pumped 5 bbls fresh water and pressure tested lines to 3,000 I psi, pumped 10 more bbls fresh water and followed with 57 bbls, 210 sxs of class G cement at 15.8 ppg and 1.53 yield, ave 4 bpm at 700 psi, then pumped 1.8 bbls water behind cement, turned over to the rig and rig pumped 127 bbls of 12.5 ppg mud to balance plug, displaced at an ave of 5 bpm, initial circ pressure 400 psi, final pressure 780 psi, CIP at 12:22 hrs with btm of plug at 8,177' and cal TOC at 7,494' (Note: cement volume calc on 150' of 9 3/8" hole plus 50% excess and 450' inside 9 5/8" csg) 12:30 - 13:30 1.00 CEMEN TRIP ABANDN POOH 12 stds from 8,177' to 7,063', pulled at 20'/min 13:30 - 16:30 3.00 CEMEN~CIRC ABANDN Dropped DP wiper dart and circ 2X btms up, on initial btms up saw no cement, circ at 168 gpm at 525 psi with 150K st wt 16:30 - 18:00 1.50 ABANDfU'D ABANDN POOH and LD an additional 24 jts of 5" DP while WOC, POOH to 6,322' 18:00 - 22:00 4.00 ABAND OTHR ABANDN While WOC, began cleaning pollution pans under rig floor and drawworks, cont to clean mud pits and cellar area 22:00 - 22:30 0.50 CEMEN TRIP ABANDN RIH from 6,322' to 7,067' with 3 1/2" stinger on 5" DP 22:30 - 00:00 1.50 CEMEN~TRIP ABANDN Began washing down to find TOC, washed down from 7,067' to 7,988' with no sign of cement, circ at 1 bpm at 300 psi and 150K st wt, NOTE: John Spaulding with AOGCC and Tim Lawlor with BLM on location to witness tag 4/24/2005 00:00 - 01 :00 1.00 CEMEN TRIP ABANDN Cont to wash down looking for TOC, washed down from 7,988' and tagged TOC at 8,190', calc TOC was at 7,494' 01:00-02:151 1.25 CEMEN CIRC ABANDN Circ btms up at 8,190', circ at 255 gpm, 800 psi, no cement at btms up, stwt up 164K, dn wt 161K 02:15 - 02:30 0.25 CEMEN TRIP ABANDN POOH 3 stds from 8,190' to 7,996' 02:30 - 06:00 3.50 CEMEN CIRC ABANDN Circ and condo mud at 7,996' while waiting on additional cement to arrive, circ at 80 spm, 340 gpm at 900 psi, st wt 157K, circ and cond 12.5 ppg mud from 140 vis due to high PH down to 100 vis 06:00 - 06:30 0.50 CEMEN TRIP ABANDN RIH washing down from 7,996' to 8,186', washed at 64 gpm at 500 psi 06:30 - 07:00 0.50 CEMEN CIRC ABANDN ! Circ hole at 8,186' at 168 bpm at 500 psi while Dowell offloaded cement 07:00 - 07:15 0.25 CEMEN SFTY IABANDN Held PJSM with rig crew, Dowell and ACS rep on setting plug #3 07:15-08:15 I 1.00 CEMEN PLUG ' ABANDN Dowell pumped 5 bbls fresh water and pressure tested lines to 3,000 psi, pumped 10 more bbls fresh water and followed with 103 bbls, 500 sxs of class G "Alpine Intermediate" cement at 15.8 ppg and 1.17 yield, ave 5.5 bpm, initial pressure 800 psi, final pressure 200 psi, then pumped 1.8 bbls water behind cement, turned over to the rig and rig I pumped 118 bbls of 12.5 ppg mud to balance plug, displaced at an ave i of 6 bpm, initial circ pressure 300 psi, final pressure 975 psi, CIP at I 108: 15 hrs with btm of plug at 8,186' and cal TOC at 7,714' (Note: cement volume calc on 159' of open hole being 375 cubic ft plus 20% excess and 317' inside 9 5/8" csg) 08:15 - 09:15 1.00 CEMEN1TR'P ABANDN POOH 11 stds from 8,186' to 7,160', (30'/min) 09:15 - 14:00 4.75 CEMEN CIRC ABANDN Circ and cond mud at 7,160' while WOC, at 1 st btms up did not see any cement back at surface, circ and cond mud at 6 bpm at 550 psi, WOC i6 hrs I I I Printed: 51212005 2:02:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KOKODA #5 KOKODA #5 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 3/6/2005 Rig Release: 4/25/2005 Rig Number: Spud Date: 3/712005 End: 4/25/2005 Group: 14:15-15:15 ABANDN 15:15 - 19:30 ABANDN 19:30 - 20:45 ABANDN 20:45 - 22:00 ABANDN 22:00 - 22:30 ABANDN 22:30 - 23:00 ABANDN 23:00 - 23:30 ABANDN 23:30 - 00:00 ABANDN Washed down at 2 bpm at 320 psi from 7,160' and tagged TOC at 7,311', set 15K wt down on plug, tag witnessed by John Spaulding W/AOGCC and Tim Lawlor W/BLM, Circ btms up at 7,311' at 8 bpm, 800 psi, at btms up saw small chunks of cmt back at btms up POOH LD 219 jts of 5" DP, POOH from 7,311' to 3 1/2" stinger at 941' RU mousehole and LD 30 jts of 5" DP from derrick RU 3 1/2" handling tools and POOH LD 20 jts 3 1/2", 9.3# tbg stinger, POOH to 311' Displaced hole over from 12.5 ppg mud to water POOH with 3 1/2" stinger Pulled wear bushing RIH with 3 1/2" stinger to 311', preparing to set plug at surface NOTE: At approx 09:45 a ASRC vac truck driver fell out of the back end of his truck and hurt his leg, he was sent to KUP medic and later was sent to town for further evaluation RU pump in sub on 3 1/2" stinger and held PJSM with crew and Dowell on setting plug at surface Dowell set 311' surface plug, pumped 5 bbls water and followed with 30.5 bbls, 195 sxs of AS 1 cement at 15.8 ppg, .93 yield and circ till good 15.8 ppg cement was at surface, circ out 4 bbls of good cement, pumped cement at 1.75 bpm at 90 psi, CIP at 1 :07 hrs, Tim Lawlor with BLM witnessed placement of the plug RD pump in sub and blew down cement line , POOH from 311' and LD 10 jts of 3 1/2" stinger RD Doyon's 31/2" tbg handling equipment ND BOPE I Cont to clean mud pits, rock washer and cellar area ¡Disconnected service loops and lines and blow down rig, staged pipe shed Tioga air heater on pad and fin cleaning mud pits, transfered approx 3,120 gals diesel fuel from rig to 1 R for freeze protection, Note @ 17:00 Hrs tagged top of cement in 9 5/8" at 12' below wellhead RELEASED RIG @ 12:00 hrs 4/25/05 4/25/2005 00:00 - 00:30 0.50 CEMEN RURD ABANDN 00:30 - 01:15 0.75 CEMEN PLUG ABANDN 01: 15 - 01 :30 0.25 CEMEN~RURD ABANDN 01 :30 - 02:00 0.50 CEMEN TRIP ABANDN 02:00 - 02:30 0.50 CEMEl RURD ABANDN 02:30 - 04:00 1.50 WELCT NUND ABANDN 04:00 - 07:00 3.00 MOVE DMOB ABANDN 07:00 - 12:00 5.00 MOVE DMOB ABANDN Printed: 5/212005 2:02:27 PM . . KOKODA 5 P & A SUMMARY APRIL 25, 2005 4/22/05 Spotted 20 bbl hi vis pill at 8,392' and picked up to 8,331' and circ btms up with no sign of pill on btms up. Pumped plug #1 from 8,331' to calculated top of cement at 7,831' pumped 46 bbls, 169 sxs of class "G" with silica at 15.8 ppg and 1.53 yield, CIP at 22:00 hrs. PU to 7,315' and circ btms up with no sign of cement at btms up. Placement of plug was witnessed by Tim Lawlor with BLM (Note: cement volume calc on 300' of 9 3/8" hole plus 20% excess and 200' inside 9 5/8" csg) 4/23/05 While WOC, cemented off 13 3/8" x 9 5/8" annulus. Cemented annulus to 500'. Est injection rate at 1 bpm, pressure increased to 925 psi then broke over and ave. 480 psi at 1 bpm, at 1.5 bpm ave. 490 psi and at 2 bpm ave. 490 psi. Pumped a total of 30 bbls then shut down. Mixed and pumped 30 bbls, 180 sxs of AS 1 cmt at 15.8 ppg and .93 yield to cement annulus down to 500' with CIP at 01:20 hrs. Shut in well with 200 psi. Placement of plug was witnessed by Tim Lawlor with BLM 4/23/05 WOC a total of 6 hrs, then RIH and tagged TOC at 8,326', calc TOC was at 7,831' tag was witnessed by Tim Lawlor with BLM and John Spaulding with AOGCC. Spotted 46 bbl hi vis pill at 8,326' and POOH to 8,177' and circ btms up and saw approx 20 bbls of hi vis pill. Pumped plug #2 from 8,177' with a calc TOC at 7,494'. Cemented with 57 bbls, 210 sxs of class G cement at 15.8 ppg and 1.53 yield, CIP at 12:22 hrs. (Note: cement volume calc on 150' of 9 3/8" hole plus 50% excess and 450' inside 9 5/8" csg) POOH to 7,160' and circ btms up with no signs of cmt at btms up. Placement of plug was witnessed by Tim Lawlor with BLM and John Spaulding with AOGCC. WOC 10 hrs RIH and tagged TOC at 8,190', calc TOC was at 7,494' circ btms up with no sign of cmt 4/24/05 Pumped plug #3 from 8,186' to a calc. TOC at 7,714', cemented with 103 bbls, 500 sxs of class G "Alpine Intermediate" cement at 15.8 ppg and 1.17 yield, CIP at 08:15 hrs. (Note: cement volume calc on 159' of open hole being 375 cubic ft plus 20% excess and 317' inside 9 5/8" csg) Placement of plug was witnessed by Tim Lawlor with BLM and John Spaulding with AOGCC. WOC 6 hrs RIH and tagged TOC at 7,311', calc TOC was at 7,714', set 15K weight down on plug while pumping at 2 bpm and tag was witnessed and approved by Tim Lawlor with BLM and John Spaulding with AOGCC. Circ btms up at 7,311' and had small chunks of cement back at btms up POOH LD 5" DP leaving 12.5 ppg mud in hole, no losses were seen while setting cement plugs 4/25/05 Pumped plug #4 from 311' to surface, set surface plug with 30.5 bbls, 195 sxs of AS 1 cement at 15.8 ppg, .93 yield and circ till good 15.8 ppg cement was at surface, circ out 4 bbls of good cement, CIP at 1 :07 hrs. Tim Lawlor with BLM witnessed placement of plug At 19:00 hrs RIH with tape measure and tagged TOC in 9 5/8" csg at 12' below ground level . . Kokoda 5 Surface P&A Summary 04/29/05 On 4/28/05 Peak excavated around the existing casings on Kokoda 5 to a depth 5 feet below ground level. Tim Lawlor (BLM) witnessed the P&A operations on 4/29/05. Chuck Sheve (AOGCC) waived witnessing the P&A operations via telephone on 4/26/05. On 4/29/05 The following operations were performed: · The Drilling Safety Specialist monitored the 20" x 13 3/8", 13 3/8" x 9 5/8" annuli and the 9 5/8" casing for combustible hydrocarbons. There were no detectable combustible hydrocarbons present. · Peeled 20" conductor off 13 3/8" casing from just below 20" landing ring to 40 inches below ground level. Chiseled cement off 13 3/8" casing. · Cut off 13 3/8" and 9 5/8" casing 41 inches below ground level. · Removed cut off s and well head equipment from excavation. · Dropped plumb bob down 13 3/8" and 9 5/8" annulus it stopped at 62 feet. The tape measure was pulled out dry. Measured cement in 95/8" casing at 6 feet below ground level. · With BLM approval the 13 3/8" x 9 5/8" annulus was cemented from the surface / using Schlumberger Cementers. Mixed and pumped 13.5 bbls. AS 1 at 15.8 ppg to fill annulus to the surface. Cement volume indicates the top of annulus plug # 1 was 230 feet below ground level. Filled 95/8" casing with 'l2 bbl. AS I at 15.8 ppg. Cement in place at 1410 MS. 4/29/05. · Welded P&A identification marker plate to 20" casing stub. The plate has a 1/8" / hole drilled in it as required by the BLM. · Filled excavation with native soils from the excavation and the spoils from / conductor drilling operations. Attachments: · Eight Photos Robert L. Morrison Jr. 4/30/05 © ConocoPhìllips Alaska, Inc. This photo is copyright by ConocoPhìllipsAlaska, Inc. and (jr published without the express consent © ConocoPhillips Alaska, Inc. This photo is copyright by CQnoGoPhillîps Ala"ka, Inc. and cannot be released or pubIîshed without the expres" consent of ConocoPhîllips Alaska., Inc. © ConocoPhillips Alaska, Inc. 111is photo is copyright by ConocoPhiUips Alaska, Inc. and cannot be released or published without the express consent of ConocoPhillips, Alaska, ]11C. © ConocoPhillips Alaska, Inc. 111is photo is copyright by ConocoPhillips Alaska, Inc. and cannot be released or pu blished without the express consent of ConocoPhillips Alaska, Inc. © ConocoPhjJIips Alaska, Inc. ~n1is photo is copyright by ConocoPhilIips Alaska, Inc. and cannot be released or published without the express consent of ConocoPhillips Alaska, Inc. ConocriP'hillips Alaska, Inc. TRANSMITTAL TO: AOGCC 333 W 7TH AVE Anchorage, AK 99501 OPERATOR: CP AI SAMPLE TYPE: DRIES SAMPLES SENT: KOKODA 5 ¿ Dries 108-11122 SENT BY: Mike McCracken ,-,,' Bayview Geological Facility 619 East Ship Creek Ave., Suite 102 Anchorage, AK 99510 phone 907.263.4859 DATE: 06-06-05 AIRBllL: 5325452 CPBV 05-06-06-13 CHARGE CODE#: 10045962 WELL: KOKODA 5 NUMBER OF BOXES: 1 Bundle (9 boxes) ;1 '<f $CANNEt> JUN O· 6 2007 UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAil A SIGNED COPY OF THIS FORM TO: RECEIVED BY: ;Ud/J ConocoPhillips Alaska, Inc. 619 E. Ship Creek Ave Anchorage, AK. 99510 Attn: Dan Przywojski DATE: b J~ ~ } ~~<.I .... 1 \'9 4> . . ¿:;þ'¿~d57 FRANK H. MURKOWSKI, GOVERNOR A"fA~1iA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul Mazzolini Drilling T earn Leader ConocoPhillips, Alaska Inc. PO Box 100360 Anchorage AK 99510 Re: Kokoda #5 305-098 Dear Mr. Mazzolini: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is censidered timely if it is received by 4:30 PM on the 23 y following the date of this letter, or the next working day if the 23rd day falls 0 a ho ·day or weekend. A person may not appeal a Commission decision t u er" r Cou unless rehearing has been requested. DA TED this ~y or;:;k 2005 Encl. 1. Type of Request: Abandon 0 Suspend 0 Operational shutdown 0 Perforate 0 Aít{V¡a~./ f f") 0 Annular Dispos. 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimul~aSkâ Oil & Gi§~~ieò,Qission other 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 AfJOhul'8þspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 204-259 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-279-20012-00 7. KB Elevation (ft): 9. Well Name and Number: 28' RKB, 150' GL Kokoda #5 8. Property Designation: 10. Field/Pools(s): ALK M081737 & M081840 I ADL L300841 NPRA Exploration 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured) Junk (measured): 11122' 10301 ' 9036' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 108' 108' Surface 2581' 13-3/8" 2609' 2609' Intermediate 8003' 9-5/8" 8031' 7895' Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None None None None Packers and SSSV Type: Packers and SSSV MD (ft): None None 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/22/2005 Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: ~~r Date: 4/22/2005 WAG 0 GINJD WINJ 0 WDSPL 0 Commission Representative: T m Maunder 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Chambers @ 265-1319 Printed Name Paul Mazzolini Title Drilling Team Leader Signature ¿J ¡J,. t:L£- Phone 263-4603 Date 1; Z-z/ð 5· 17 )}-IZ.« t::..1I7fh .ð$/Z'5 RJÆh#~1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrit~BOP Test Location Clearance ~ ~-:o,5 -{)ý ~ 0 Mechanical Integrity Test 0 Other: ~ð~ ¡'- ~~\\"t..c;.S +Ca..~ ~c.0~C~ ITL,j ~ '\ RBDMSBFLIIAYO~1D05 Subse t orm qUi d: APPro.....,:"' it BY ORDER OF Date:~11 ~ COMMISSIONER THE COMMISSION ,~ , \ I G t f\! i\ L I , . . ~Z3f- STATE OF ALASKA ¥.3 /S' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPRMGEfVED 20 MC 25 280 -4 I,}:} Form 10-403 Revised 12/2003 INSTRUCTIONS ON REVERSE Submit in Duplicate . . Kokoda 5 - P&A Procedure Confidential 04/22/05 1. Kokoda 5 Wellbore Status: Drilled 16" Surface Hole. 13-3/8" casing was run to 2,609' MD/TVD and cemented back to surface. Drilled 12-1/4" Intermediate Hole. 9-518" casing was run and cemented to 8,031' MD 17,895' TVD (Est. Top Cement at 6,000' MD). Drilled 8-1/2" Intermediate Hole to 11,122' MD 110,301' TVD. Unable to get 7" Liner to bottom. Numerous attempts were made to clean out well bore. Drill pipe connection parted and 1,227' of fish was left in well bore. Two fishing runs were attempted unsuccessfully. Top of fish was never located. Unable to get below 9,036' MD during fishing attempts (fish appears to have moved down hole). The decision has been made to P&A the well. These procedures cover the proposed P&A plan. 2. Notify BLM/AOGCC in advance of all well P&A operations. Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. 3. Mobilize and rig up D/S for well P&A operation. RIH with 3-1/2" stinger and 5" DP. 4. Spot balanced cement plug # 1from 8,331' MD to 7,831' MD (200' above the 9-5/8" shoe v at 8,031' MD / 7,895' TVD). Total interval is approximately 500' in length. Note: BLM/AOGCC require this olun to be tanned before continuinQ wI P&A .!QGc..c.. ~'õ ./ 5. RU D/S to pump down the 13-3/8" x 9-518" annulus. Pump 100 bbls of water to flusti- annulus and verify injectivity (note rate and pressures). Bullhead 180 sx (30 bbls) of Arctic Set 1 cement into the annulus. 6. Spot a 300' balanced Arctic Set 1 cement plug # 2 from 300' to surface. Note: To prevent plug from moving down hole, spot cement on top of wiper plug. / 7. RDMO. 8. Cut off wellhead and all casing strings at 3 feet below ground level. Verify cement is at surface in all strings. Send casing head with stub to Materials for repair I redress. 9. Weld 1/4" thick cover plate (at least 18" in diameter) over all casing strings with the following information bead welded into the top. Drill 1/8" weep hole in cover plate (per BLM requirements). · ConocoPhillips Alaska, Inc. · Kokoda # 5 · PTD # 204-259 · API # 50-279-20012-00 · SHL: 3143' FNL, 1709' FEL, Sec. 5, T11N, R5W 10. Remove cellar. Back fill cellar with gravel as needed. Clear ice pad location and demobilize all materials and equipment. RECEIVED APR 2 2 Z005 MAC 04/22/05 Alaska Oil & Gas Cons. Commi*gióíì Anchorage If- . Conductor (80'): 20",9400#, B Set @ +/- 108' MD / TVD Surface Casing: 13-3/8".6800#. L-80, BTC Set @ +/- 2609' MD / TVD Intermediate Casing #1: 9-5/8".4000#, L-80. BTC Set @ +/- 8031' MD /7895' TVD Fish: Estimated Top @ +9036' Total Length 1227' Deeoest Point Durina Fishina was 9036'. Did Not Encounter Too of Fish. TD (Estimated): @ +/- 11,122' MO /10.301' TVD Kokoda 5 - P&A Schematic v1.0 Prepared by Mark Chambers 04/21/05 koda #5 12.50 PPG G% KCL Kill Weiaht Mud 12.50 PPG G% KCL Kill Weiaht Mud illips 9-518" Casing (.0758 bbl/ft): 300' Cement Plug Set From Surface to 300' MO 140 Sacks (23 bbl) Arctic Set 1 Slurry Weight Slurry Yield Thickening Time 15.7 ppg 0.93 cu-ft/sk 2.50 hrs 13-3/8" x 9-5/8" Annulus (.0597 bbl/ft): 500' Cement Plua Set From Surface to 500' MD 180 Sacks (30 bbl) Arctic Set 1 Slurry Weight Slurry Yield Thickening Time 15,7 ppg .93 cu-ftIsk 2,50 hrs Marker Plate Information: y." Plate Thickness Operator Name: ConocoPhillips Alaska, Inc, Well Name: Kokoda #5 Permit to Drill Number: 204-259 API Number 50-279-20012-00 SHL: 3143' FNL, 1709' FEL, See 5, T11N, R5W Note: BLM requires a weep hole in this plate ~-~-~-~~,.~..._- 8-1/2" Open Hole (Opened to 9-3/8"): 500' Cement Plua Set From 8 331' MD to 7.831' MD (Top Cement Planned @ 200' MD Above 9-5/8" Casing Shoe) Plan to Set Cement Plug in 1 Stage 169 Sacks (46 bbl) Class G + 35% 066 (Silica) + Additives Slurry Weight Slurry Yield Thickening Time 15.8 ppg 1.53 cu-ftIsk 4,00 hrs Cement Volume Based on 9-3/8" Open Hole +20% Excess Actual Cement Volumes Will Be Recalculated When Final TO is Determined Verbal Approval Kokoda #5 e . Ma« This message is to confirm that you have "verbal" approval to abandon Kokoda #5. I will copy the Inspectors with the procedure. Please make sure the Company Man contacts them regarding the tag and cutoff. It is likely that an AOGCC Inspector will witness 1 or both of these activities regardless if the BLM Inspector is there. Tom Maunder, PE AOGCC D~o ~<>-~LO~j 1 of I 12/22/2005 12:45 PM e e daLi-~~ Kokoda 5 - Well Status Report >..J \ 04/14/05 Kokoda #5 Accepted rig at 2200 hrs 3/6/05. Spudded well at 2045 hrs 3/7/05. Drilled 16" surface hole to 1,061' MD / TVD. POOH waiting on weather from 2115 hrs 3/8/05. OOH waiting on weather from 0515 hrs 3/9/05 to 1845 hrs 3/11/05. RIH and drilled 16" surface hole from 1,061' MD / TVD to 2,615' MD / TVD. Ran 13-3/8",68 PPF, L-80, BTC casing to 2,609' MD / TVD. Performed stab-in cement job. Pumped lead until cement observed at surface before switching to tail. Cement job went as planned with full returns throughout. Completed BOPE testing, drilled shoe track and 20' of new hole to 2,635' MD / TVD. Performed FIT to 16.1 ppg EMW. Drilled 12-1/4" hole to 3,667' MD / TVD. POOH for MWD failure. Continued drilling 12-1/4" hole to 8,040' MD / 7,903' TVD. Performed wiper trip and POOH to run 9-5/8" casing. Ran and cemented 9-5/8",40 PPF, L-80, BTC casing to 8,030' MD. Pumped 190 bbls (920 sks) of Class "G" + additives with full returns during cement job, did not reciprocate pipe, bumped plug on strokes. Estimated TOC @ 6,000' MD/TVD. RIH with 8-1/2" BHA, tested casing to 2,500 psi for 30 minutes - OK. Drilled shoe track and 20' of new hole to 8,060' MD / 7,920' TVD. Performed FIT to 14.0 ppg EMW. Directionally drilled 8-1/2" hole to 9,397' MD / 8,961' TVD. Performed short trip to 9-5/8" casing shoe @ 8,030' MD. Directionally drilled 8-1/2" hole to 10,417' MD / 9,742' TVD. Performed short trip to 9,215' MD. Directionally drilled 8-1/2" hole to 10968' MD /10176' TVD. Lost circulation while drilling ahead @ 10,968' MD /10,176' TVD. Pumped35bbl LCM pill and re-established circulation. Circulated at a reduced rate and monitored well while building volume in the pits. Directionally drilled 8-1/2" hole to casing point @ 11,122; MD /10,301' TVD. Attempted to POOH. Worked through numerous tight spots. Back reamed OOH from 10,938' MD to 9,400' MD. Hole packed off. Unable to circulate. Re-established circulation and continued back reaming OOH to 9-5/8" casing shoe @ 8,030' MD. Circulate hole clean. POOH. Lay down Ghost Reamer and directional BHA. PU rotary assembly, RIH and tag bridge @ 8,071' MD. Wash and ream from 8,071' MD to 8,487' MD (hole packing off). Pump OOH from 8,497' MD to 8,000' MD. Circulate hole clean. RIH and tag bridge @ 8,270' MD. Wash and ream from 8,270' MD to 8,963' MD. Back ream OOH to 8,003' MD (hole packing off). Circulate hole clean. RIH on elevators to 8,323' MD. Wash and ream from 8,323' MD to 11,112' MD. Pump out of hole to 10,787' MD and spot 80 bbl LCM pill. Continue POOH to run 7" Liner. RIH with 7", 26 PPF, L-80, BTC liner to 8,535' MD. Liner running tool released prematurely (lost 58K weight / 300 psi pump). Chased liner to 8,871' MD. POOH. Test BOP's while waiting on tools. MU new liner running tool. Rill and latch onto top of liner. PU and establish circulation. Attempt to continue Rill with liner. Unable to work liner below 9,060' MD. POOH and LD 7" liner. Currently operation: Performing cleanout run w/ rotary assembly. . . ~Dc/~l53 Kokoda - Well Status Report 04/08105 Kokoda #1 Spudded well 2/16105. Drilled 12-1/4" surface hole to 2510' MD/TVD. Ran & cemented 9-5/8",40 PPF, L-80, BTC casing to 2505' MD/TVD. Reciprocated pipe and had full returns throughout job. Did not see any 10.7 ppg lead cement to surface. Performed two top jobs from 88' (tagged-up with I" stinger) with the second job getting cement back to surface. Completed testing ofthe BOPE, drilled shoe track and 20' of new hole to 2530' MD/TVD. Performed FIT to 15.9 ppg EMW. Drilled 8-1/2" hole to 6678' and POOH for rotary BHA. Drilled to core point at 6837' POOH. Core from 6837' to 6873' (36'). POOH LD core (recovered 34' of core). Drilled 8-1/2" hole to TD at 8045' MD/TVD. Tested BOPes. Ran e-line logs requiring a wiper trip between logging runs. P&A'd well per approvals and released rig at 0400 hrs 3/6105. Kokoda #5 Accepted rig at 2200 hrs 3/6105. Spudded well at 2045 hrs 3/7/05. Drilled 16" surface hole to 1,061' MD I TVD. POOH waiting on weather from 2115 hrs 3/8/05. OOH waiting on weather from 0515 hrs 3/9105 to 1845 hrs 3/11/05. RIH and drilled 16" surface hole from 1,061' MD I TVD to 2,615' MD I TVD. Ran 13-3/8", 68 PPF, L-80, BTC casing to 2,609' MD I TVD. Performed stab-in cement job. Pumped lead until cement observed at surface before switching to tail. Cement job went as planned with full returns throughout. Completed BOPE testing, drilled shoe track and 20' of new hole to 2,635' MD I TVD. Performed FIT to 16.1 ppg EMW. Drilled 12-1/4" hole to 3,667' MD I TVD. POOH for MWD failure. Continued drilling 12-1/4" hole to 8,040' MD I 7,903' TVD. Performed wiper trip and POOH to run 9-5/8" casing. Ran and cemented 9-5/8",40 PPF, L-80, BTC casing to 8,030' MD. Pumped 190 bbls (920 sks) of Class "G" + additives with full returns during cement job, did not reciprocate pipe, bumped plug on strokes. Estimated TOC @ 6,000' MD/TVD. RIH with 8-1/2" BHA, tested casing to 2,500 psi for 30 minutes - OK. Drilled shoe track and 20' of new hole to 8,060' MD I 7,920' TVD. Performed FIT to 14.0 ppg EMW. Directionally drilled 8-1/2" hole to 9,397' MD I 8,961' TVD. Performed short trip to 9-5/8" casing shoe @ 8,030' MD. Directionally drilled 8-1/2" hole to 10,417' MD I 9,742' TVD. Performed short trip to 9,215' MD. Directionally drilled 8-1/2" hole to 10968' MD 110176' TVD. Lost circulation while drilling ahead @ 10,968' MD 110,176' TVD. Pumped 35 bbl LCM pill and re-established circulation. Circulated at a reduced rate and monitored well while building volume in the pits. Directionally drilled 8-1/2" hole to casing point @ 11,122' MD 110,301' TVD. Attempted to POOH. Worked through numerous tight spots. Back reamed OOH from 10,938' MD to 9,400' MD. Hole packed off. Unable to circulate. Re-established circulation and continued back reaming OOH to 9-5/8" casing shoe @ 8,030' MD. Circulate hole clean. POOH. Lay down Ghost Reamer and directional BHA. PU rotary assembly, RIH and tag bridge @ 8,071' MD. Wash and ream from 8,071' MD to 8,487' MD (hole packing oft). Pump OOH from 8,497' MD to 8,000' MD. Circulate hole clean. RIH and tag bridge @ 8,270' MD. Wash and ream from 8,270' MD to 8,857' MD (report time 4/8/05). e e Kokoda - Well Status Report 04/01105 df) L\_ if- S-1 Kokoda #1 Spudded well 2/16/05. Drilled 12-1/4" surface hole to 2510' MD/TVD. Ran & cemented 9-5/8",40 PPF, L-80, BTC casing to 2505' MD/TVD. Reciprocated pipe and had full returns throughout job. Did not see any 10.7 ppg lead cement to surface. Performed two top jobs from 88' (tagged-up with 1" stinger) with the second job getting cement back to surface. Completed testing ofthe BOPE, drilled shoe track and 20' of new hole to 2530' MD/TVD. Performed FIT to 15.9 ppg EMW. Drilled 8-1/2" hole to 6678' and POOH for rotary BHA. Drilled to core point at 6837' POOH. Core from 6837' to 6873' (36'). POOH LD core (recovered 34' of core). Drilled 8-112" hole to TD at 8045' MD/TVD. Tested BOPes. Ran e-line logs requiring a wiper trip between logging runs. P&A'd well per approvals and released rig at 0400 hrs 3/6/05. Kokoda #5 Accepted rig at 2200 hrs 3/6/05. Spudded well at 2045 hrs 3/7/05. Drilled 16" surface hole to 1061' MD/TVD. POOH waiting on weather from 2115 hrs 3/8/05. OOH waiting on weather from 0515 hrs 3/9/05 to 1845 hrs 3/11105. RIH and drilled 16" surface hole from 1061' MD/TVD to 2615' MD/TVD. Ran 13-3/8",68 PPF, L-80, BTC casing to 2609' MD/TVD. Performed stab-in cement job. Pumped lead until cement observed at surface before switching to tail. Cement job went as planned with full returns throughout. Completed BOPE testing, drilled shoe track and 20' of new hole to 2635' MD/TVD. Performed FIT to 16.1 ppg EMW. Drilled 12-114" hole to 3667' MD/TVD. POOH for MWD failure. Continued drilling 12-114" hole to 8040' MD I 7903' TVD. Performed wiper trip and POOH to run 9-5/8" casing. Ran and cemented 9-5/8", 40 PPF, L-80, BTC casing to 8030' MD. Pumped 190 bbls (920 sks) of Class "G" + additives with full returns during cement job, did not reciprocate pipe, bumped plug on strokes. Estimated TOC @ 6000' MD/TVD. RIH with 8-1/2" BHA, tested casing to 2500 psi for 30 minutes - OK. Drilled shoe track and 20' of new hole to 8060' MD I 7920' TVD. Performed FIT to 14.0 ppg EMW. Directionally drilled 8-112" hole to 9397' MD 18961' TVD. Performed short trip to 9-5/8" casing shoe @ 8030' MD. Directionally drilled 8- 112" hole to 10340' MD I 9684' TVD (Report time 03/31/05). Current status: Drilling 8-1/2" hole at 10,500' MD. · e Kokoda Well Status As of 3/30/05 Kokoda #1 Spudded well 2/16/05. Drilled 12-1/4" surface hole to 2510' MD/TVD. Ran & cemented 9-5/8",40 PPF, L-80, BTC casing to 2505' MD/TVD. Reciprocated pipe and had full returns throughout job. Did not see any 10.7 ppg lead cement to surface. Perfonned two top jobs from 88' (tagged-up with 1" stinger) with the second job getting cement back to surface. Completed testing of the BOPE, drilled shoe track and 20' of new hole to 2530' MD/TVD. Perfonned FIT to 15.9 ppg EMW. Drilled 8-1/2" hole to 6678' and POOH for rotary BHA. Drilled to core point at 6837' POOH. Core from 6837' to 6873' (36'). POOH LD core (recovered 34' of core). Drilled 8-1/2" hole to TD at 8045' MD/TVD. Tested BOPes. Ran e-line logs requiring a wiper trip between logging runs. P&A'd well per approvals and released rig at 0400 hrs 3/6/05. Kokoda #5 ~6 '-\. - ~S-~ Accepted rig at 2200 hrs 3/6/05. Spudded well at 2045 hrs 317/05. Drilled 16" surface hole to 1061' MD/TVD. POOH waiting on weather from 2115 hrs 3/8/05. OOH waiting on weather from 0515 hrs 3/9/05 to 1845 hrs 3/11/05. RIH and drilled 16" surface hole from 1061' MD/TVD to 2615' MD/TVD. Ran 13-3/8",68 PPF, L-80, BTC casing to 2609' MD/TVD. Perfonned stab-in cement job. Pumped lead until cement observed at surface before switching to tail. Cement job went as planned with full returns throughout. Completed BOPE testing, drilled shoe track and 20' of new hole to 2635' MD/TVD. Perfonned FIT to 16.1 ppg EMW. Drilled 12-1/4" hole to 3667' MD/TVD. POOH for MWD failure. Continued drilling 12-1/4" hole to 8040' MD/ 7903' TVD. Made wiper trip and POOH to run 9-5/8" csg. Ran & cemented 9-5/8" 40 ppf, L-80 BTC casing to 8031' MD. Pumped 190 bbls (920 sks) of Class "G" with additives with full returns during cement job, did not reciprocate pipe, bumped plug on strokes. Estimated TOC @ 6000' MD/TVD. RIH with 8-1/2" BHA, tested casing to 2500 psi for 30 minutes- OK. Drilled to 8060' MD17920' TVD, perfonned FIT to 14.0 ppg EMW. Current status: Directionally drilling 8-1/2" hole at 9400' MD/ 8962' TVD, preparing to make a wiper trip. e . Kokoda Well Status As of3/18/05 Kokoda #1 dO~ - if ç 3> Spudded well 2/16/05. Drilled 12-114" surface hole to 2510' MD/TVD. Ran & cemented 9-5/8",40 PPF, L-80, BTC casing to 2505' MD/TVD. Reciprocated pipe and had full returns throughout job. Did not see any 10.7 ppg lead cement to surface. Performed two top jobs from 88' (tagged-up with 1" stinger) with the second job getting cement back to surface. Completed testing ofthe BOPE, drilled shoe track and 20' of new hole to 2530' MD/TVD. Performed FIT to 15.9 ppg EMW. Drilled 8-1/2" hole to 6678' and POOH for rotary BHA. Drilled to core point at 6837' POOH. Core from 6837' to 6873' (36'). POOH LD core (recovered 34' of core). Drilled 8-1/2" hole to TD at 8045' MD/TVD. Tested BOPes. Ran e-line logs requiring a wiper trip between logging runs. P&A'd well per approvals and released rig at 0400 hrs 3/6/05. Kokoda #5 d-() L\ -C7-~ Accepted rig at 2200 hrs 3/6/05. Spudded well at 2045 hrs 3/7/05. Drilled 16" surface hole to 1061' MD/TVD. POOH waiting on weather from 2115 hrs 3/8/05. OOH waiting on weather from 0515 hrs 3/9/05 to 1845 hrs 3/11/05. RIH and drilled 16" surface hole from 1061' MD/TVD to 2615' MD/TVD. Ran 13-3/8",68 PPF, L-80, BTC casing to 2609' MD/TVD. Performed stab-in cement job. Pumped lead until cement observed at surface before switching to tail. Cement job went as planned with full returns throughout. Completed BOPE testing, drilled shoe track and 20' of new hole to 2635' MD/TVD. Performed FIT to 16.1 ppg EMW. Drilled 12-114" hole to 3667' MD/TVD. POOH for MWD failure. Current status: Rill to continue drilling 12-114" hole. e e Kokoda Well Status As of3/1 0/05 ¿(OLl.. - (t 5,\ Kokoda #1 Spudded well 2/16/05. Drilled 12-114" surface hole to 2510' MD/TVD. Ran & cemented 9-5/8" 40 ppfL-80 BTC casing to 2505'. Reciprocated pipe and had full returns throughout job. Did not see any 10.7 ppg lead cement to surface. Perfonned two top jobs from 88' (tagged-up with 1" stinger) with the second job getting cement back to surface. Completed testing ofthe BOPE stack, drilled shoe track and 20' of new hole to 2530' MD/TVD. Perforemd FIT to 15.9 ppg EMW. Drilled 8-112" hole to 6678' and POOH for rotaryBHA. Drilled to core point at 6837' POOH. Core from 6837' to 6873' (36'). POOH LD core (recovered 34' of core). Drilled 8-112" hole to TD at 8045' MD/TVD. Tested BOPes. Ran e-line logs requiring a wiper trip between logging runs. P&A'd well per approvals and released rig at 0400 hrs 3/6/05. Kokoda #5 Accepted rig at 2200 hrs 3/6/05. Spudded well at 2045 hrs 3/7/05. Drilled 16" surface hole to 1061' MD/TVD. POOH waiting on weather from 2115 hrs 3/8/05 to present. Current status: Waiting on weather- phase 3 conditions! Re: Kokoda #5 Hole Problems Paul, Your note confirms our conversation. At the present time, working with the hole is the best course of action. You have not reported any pressure problems. The difficulties are mechanical. I agree with your proposal to delay the BOP test in favor of going back into the hole. Please keep us advised of your activities. Tom Maunder, PE AOGCC Mazzolini, Paul wrote: Tom, As I stated in our phone conversation Doyon 141 has been fighting its way out of the hole on a conditioning trip prior to running our 7" liner since 6 pm on 4/4. We have reached a TD of 11,122' MD that gets us below the troublesome Kingak and Miluvich shale intervals. While tripping out we encountered very tight hole conditions just 2 stands off bottom and began backreaming our way out of the hole. On about 6 different occasions we became packed off and had to easily work pipe out of these areas to regain circulation. As of 5 pm on 4/5 we have now gotten an uphole reamer into the 9 5/8" casing shoe at 8031" MD. Our present plan is to come all the way out of the hole, lay down the full suite of LWD tools and mud motor and pickup a rotary assembly to go directly back in the hole and clean out to TD. We would then come out when hole conditions dictate and pick up the liner and run to bottom and cement. Our initial trip out of the hole is to minimize risk of losing an expensive BHA with nuclear tools. CPA is requesting approval from AOGCC to continue the waiver on the 7 day BOPE test until the clean out trip and the 7" liner has been run and cemented in place in order to give us the best chance to successfully get the liner in place. Please contact me at 263-4603 with any questions. Regards, Paul I of 1 4/6/2005 8:29 AM RE: Kokoda #5 BOPE Extension Request . - Subject: RE: Kokoda #5 BOPE Extension Request From: "Brassfield, Tom J" <TOM.J.Brassfield@conocophillips.com> Date: Wed, 30 Mar 2005 12:29:31 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us> (;2·0 ~ - ~~ Tom, thanks! Tom -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, March 30, 2005 11:47 AM To: Brassfield, Tom J Cc: AOGCC North Slope Office Subject: Re: Kokoda #5 BOPE Extension Request Tom, Your proposal is acceptable, however if you need to make a trip prior to running the liner a BOP test is necessary. Good luck with the operations. Tom Maunder, PE AOGCC Brassfield, Tom J wrote: Tom, we would like to request an extension to the 7 day BOPE Test requirement for our Kokoda #5 well. The next BOPE test would be due by midnight tomorrow or 3/31/05. We are currently making a wiper trip from 9400' MD to the 9-5/8" shoe at 8031' MD. Our predicted TD for this section of hole is 11,220' or approximately 150' TVD below the Sag River. At our current ROP's we would anticipate hole TD sometime Friday and running the 7' liner Saturday/Sunday, performing the BOPE test before PU the next BHA. We have approximately 500' of Kingak shale remaining to drill. Thanks, Tom 1 of 1 3/30/2005 12:33 PM Re: [Fwd: Kokoda #5 BOPE Extension RequI Subject: Re: [Fwd: Kokoda #5 BOPE Extension Request] From: James Regg <jimJegg@admin.state.ak.us> Date: Wed, 30 Mar 2005 11:18:01 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us> - êX)~-dS~ consistent with what we've allowed others to do Thomas Maunder wrote: Jim, I would agree with their request, provided there is no other trip necessary. Having casing set deep is in their favor and they reported a 14.0 shoe test on drillout and 141 is a reliable rig. Kingak can be troublesome as Kerr-McGee is finding out, but the CPAI hole hasn't been abused with cement like KM What are your thoughts?? Tom -------- Original Message -------- Kokoda #5 BOPE Extension Request Wed, 30 Mar 2005 09:59:46 -0900 Brassfield, Tom J <TOM.J.Brassfield@conocophillips.com> tom maunder@admin.state.ak.us ....mm......._............................__..........................................nm............................._........m........................_ Doyon 141 Company Man <n1334@conocophillips.com> Subject: Date: From: To: CC: Tom, we would like to request an extension to the 7 day BOPE Test requirement for our Kokoda #5 well. The next BOPE test would be due by midnight tomorrow or 3/31/05. We are currently making a wiper trip from 9400' MD to the 9-5/8" shoe at 8031' MD. Our predicted TD for this section of hole is 11,220' or approximately 150' TVD below the Sag River. At our current ROP's we would anticipate hole TD sometime Friday and running the 7' liner Saturday/Sunday, performing the BOPE test before PU the next BHA. We have approximately 500' of Kingak shale remaining to drill. Thanks, Tom 1 of 1 3/30/2005 11 :47 AM MEMORANDUM. TO: Jim Regg ~¡fq ::,/ZA Ii>§' P.I. Supervisor I ( FROM: John Crisp Petroleum Inspector stat. Alaska Alaska Oil and Gas Conservation Commission DATE: March 7,2005 SUBJECT: Diverter Function Test Doyon 141 ConocolPhillips Kokoda #5 2042590 Exploratory CONFIDENTIAL Operator Rep.: Don Lutrick Op. phone: 263-3010 Op. E-Mail: Contractor Rep.: Pat Krupa Rig phone: 263-3020 Rig E-Mail: MISC. INSPECTIONS: ACCUMULATOR SYSTEM: P/F Location Gen.: ok Well Sign: ok Systems Pressure: 3000 psig P Housekeeping: good (Gen.) Drlg. Rig: ok Pressure After Closure: 1900 psig P Reserve Pit: na Flare Pit: na 200 psi Recharge Time: 24 min:sec P FullRecharge Time: 3:00 min:sec 27 Nitrogen Bottles: 5 @ 2425 avg. Dsi MUD SYSTEM INSPECTION: DIVERTER SYSTEM INSPECTION: Light Alarm Diverter Size: 21 1/4 in. Trip Tank: ok ok N Divert Valve(s) Full Opening: yes Mud Pits: ok ok Valve(s) Auto & Simultaneous: yes Flow Monitor: ok ok Vent Line(s) Size: 16 in. Vent Line(s) Length: 110 ft. GAS DETECTORS: Line(s) Bifurcated: na Light Alarm Line(s) Down Wind: yes Methane ok ok Line(s) Anchored: yes H2S: ok ok Turns Targeted I Long Radius: na .------ N I wind direction I Rig w/ full opening S Divefter valve I CAMP I Test's Details I traveled to Conoco/Phillips Exploratory well Kokoda #5 to witness the Diverter Function test on Doyon 141. Rig was ready to proceed with function as soon as I arrived on location. Diverter system is in compliance with all AOGCC regulations. Rig is in great shape & all hands were a pleasure to work with. BLM Inspector Tim Lawlor also witnessed the test. Total Test Time: 12 hrs. £E Number of failures: Q Attatchments: Q Div Doyon 141 03-07-05jc.xls . . Page: 1 [AGl]Since it was a Nabors employee who spun the chart, it may be appropriate to write to both Nabors & BP. Page: I [AG2]Do we inform BP of who the informant is? Is that proper? Page: I ribr31 Should we iust refer to this as daily drilling report? Page: 4 [AG4]Is this true? Page: 4 ribr51 AOGCC inspector granted test extension to Nabors 9ES on 12/16/04 to allow time to condition hole and set storm choke for HOPE test Page: 4 [AG6]Here describe what we did to conclude no leaky valves were ignored ... . . ~1T 1TŒ (ID~ ~~~~æL% . AItASIiA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOW5KI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul Mazzolini Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchoraga, Alaska 99510-0360 Re: Kokoda #5 ConocoPhillips Alaska, Inc. Permit No: 204-259 Surface Location: 3143' FNL, 1709' FEL, SEC. 5, TIIN, R5W, UM Bottomhole Location: 5189' FNL, 1147' FEL, SEC. 32, TI2N, R5W, UM Dear Mr. Mazzolini: Enclosed is the approved application for permit to drill the above referenced exploration well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, subsequent LOT data following setting production casing, and any CQLs must be submitted to the Commission on form 10-403AD prior to the approval of disposal operations. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. In your application, you indicate that testing will likely not be possible due to time constraints. However if testing does become·part of the plan, a Sundry Application (Form 403) detailing the planned activities should be submitted for approval. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may .;. # . . result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3 ager). DATED this ~y of January, 2005 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. . . ConocÓPhillips Box 100360 Alaska 99510-0360 ':\leD ->,r:','.\ -/ ~c~\ ....". . ~ ,., ...... i' 1~\0l~ , .. \) ~),"I ~ (' ~m~\$~\ß~' ~\.i;\'~ December 29, 2004 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 r..\~$\LÞ Re: Application for Permit to Drill: Surface Location: Kokoda #5 (Exploratory Test) 3143' FNL, 1709' FEL, Sec 5, T11N-R5W X=598,367, Y=5,972,762 ASP5 NAD27 3114' FNL, 1704' FEL, Sec 5, T11N-R5W 125' FNL, 1184' FEL, Sec 5, T11N-R5W 5189' FNL, 1147' FEL, Sec 32, T12N-R5W Target Location Brookian (Torok) Target Location Ivishak: Bottom Hole Location: Dear Commissioner: ./ ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory test well from the referenced location in the National Petroleum Reserve - Alaska. The well is designed to penetrate, evaluate and test the production potential of two objective sands. As indicated in the attachments, the drilling program will entail drilling 16" surface hole to approx. 2500'. Then drill a 12-1/4" wellbore to the Brookian (Torok) shallow target at 6858' MD. A conventional core will be cut in the Brookian target. The cored interval will be reamed out to 12-1/4" and the intermediate 12-1/4" hole section will continue to 7996', Then a 8-1/2" hole will be drilled directionally to 11,926' Gust above the lower target, the Ivishak). The well will be finished with a 6-1/8" hole to 12,265' MD through the Ivishak target interval. All hole intervals will be logged with a LWD logging suite. E-line logs will be run at the end of the 8-1/2" hole section through the Brookian target and at the end of the 6- 1/8" hole section through the Ivishak target to determine if the well will be cased (with 4-1/2" liner) for possible future testing. It is anticipated that there will not be time to conduct a well test this year due to end of season constraints. The proposed casing program will utilize 13-3/8" surface casing, 9-5/8" intermediate casing, a 7" intermediate liner and 4-1/2" production liner (if completed), and 4-1/2" tubing. There is a possibility that CPAI could request authorization for the disposal of drilling waste via the annulus by filing with the AOGCC a 10-403 supplement with additional information as required under 20 AAC 25.080. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: . . 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottom hole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Diagrams and descriptions of the BOP and diverter equipment to be used (Doyon 141) as required by 20 AAC 25.035 (a) (1) and (b) have been submitted previously. 5) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well. 6) The drilling fluid program as required by 20 MC 25.033 are attached in this APD package. 7) Seismic refraction or reflection analysis for Kokoda #5 as required by 20 MC 25.061(a) has been previously submitted with the Kokoda #1 APD. 8) ConocoPhillips does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment will be functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 9) Complete logging, and mud logging operations are planned and descriptions are attached. The following are ConocoPhillip's designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 MC 25.070) Sharon Allsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs (20 AAC 25.071) Greg Wilson, Geologist 263-4748 The anticipated spud date for this well is March 1. 2005. If you have any questions or require further information, please contact Tom Brassfield at (907) 265-6377 or Paul Mazzolini at (907) 263-4603 Sincerely, J~I Tom Brassfield Senior Drilling Engi eer cc: CONFIDENTIAL - Kokoda #S Well File Paul Mazzolini ATO-1570 Bill Smalstig ATO-1308 . . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 RECEIVED DEC 3 0 2004 Ale 1a. Type of Work: Drill0 RedrilU 1b. Current Well Class: Exploratory ~ ~M¡W)~¡ ~ Mu~iPle ;Zone 0 Re-entry D Stratigraphic Test D Service D s Cons. Com_qgne D 2. Operator Name: 5. Bond: ~ Blanket U Single Wel W INHIf8I& and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 Kokoda #5 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 12265' - TVD: 11128' ., NPRA Exploration 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 3143' FNL, 1709' FEL, Sec. 5, T11N, R5W, UM .,; ALK AA081737 Top of Productive Horizon (BrookianfTorok): A/lOBI¿Y!D"l' ~S 3114' FNL, 1704' FEL, Sec. 5, T11N, R5W, UM /~ ~ ,t? Top of Productive Horizon (Ivishak): 8. Land Use Permit: 13. Approximate Spud Date: 125' FNL, 1184' FEL, Sec. 5, T11 N, R5W, UM ADL L300841 March 1, 2005 Total Depth: 9. Acres in Property: 14. Distance to 5189' FNL, 1147' FEL, Sec. 32, T12N, R5W, UM , 5756 Nearest Property: 28425' @ surf 4b. Location of Well (State Base Plane Coordinates): NAD 27 10. KB Elevation 15. Distance to Nearest Well Within Surface: x- 598367 y- 5972762 Zone- 5 (Height above Gl): 28' RKB & GL 150' Pool: Caribou#26-22-1 ,10.5 miles 16. Deviated wells: 17. Anticipated Pressure (see 20 AAC 25.035) " Kickoff depth: 6523 - ft. Maximum Hole Angle: 40° Max. Downhole Pressure: 5960 psig / Max. Surface Pressure: 4986 psig 18. Casing Program Setting Depth Quantity of Cement Size Specifications Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 36" 20" 94# B PEB 80' Surface Surf. 108' 108' 300 sxAS I 16" 13-3/8" 68# L-80 BTC 2472' Surf. Surf. 2500' 2500' 440 sx AS III Lite, 230 sx Class G 12-1/4" 9-518" 40# L-80 BTC 7968' Surf. Surf. 7996' 7858' 900 sx Class G + additives 8-1/2" 7" 26# L-80 BTC-M 4344' 7846' 7743' 11926' 10868' 740 sx Class G + additives 6-1/8" 4-1/2" 12.6# L-80 IBT-M 489' 11776' 10753' 12265' 11128' 90 sx Class G + additives 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (It): Total Depth TVD (It): Plugs (measured) Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (It): Perforation Depth TVD (ft): 20. Attachments: Filing Fee 0 BOP Sketch D Drilling program[,;j Time v. Depth Plot 0 Shallow Hazard Analysis 0 Property Plat D Diverter SketchD Seabed Report D Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tom Brassfie/d 265-6377 Printed Name Paul Mazzolini Title Drilling Team Leader Signatutll1-l~ A /'I!A't".!2.J- )ÛÁ. t?-t;L~: Phone Date )¿/;,1'i ..,. -Dr"kR / Commission Use Only Permit to Drill / API Number: Permit Approv;al /, See cover letter Number: d04-ð-5'<; 50- ø "\~ - ~aG \;)~()Ù Date: I !I)' "E for other requirements Conditions 01 approval: Samples required grves D No Mud log required .3Ves D No .ñogen sulfide measures ~ves D No Directional survey required ~ Yes D No Other: 50rs; ~~~I \o\c;. \Sa\' ~~\ \~~ ~Ck\ '=- '\ ()Ö-'t ~ " -r~(i')¡ 7./27:' ';:'*"""':æ0 Ir>-t "'-~~~ LIe 0 ~ <> \,p \,"-<1 \, '" r-, 0~~ (~ U APPROVED BY Approved b~'--'7 ¿¡ r t THE COMMISSION Date: Form 1 0- b,{~ ~2004. '-- I ¿bmit in duplicate ORIGINAL · Conoco Phillips A,asl,nc. Drill and Case Plan for Kokoda #5 General Procedure: 1. MIRU Doyon 141 over pre-installed 20" conductor casing with welded landing ring on conductor. 2. Install diverter & function test same. Notify regulatory agencies 48 hours prior to test. 3. Spud well and drill 16" hole to the surface casing point at 2500' MD/2500' TVD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 13-3/8" 68# L80 BTC casing string to surface. · Employ lightweight permafrost cement lead slurry and Dowell LiteCrete high compressive, lightweight tail slurry to assure cement returns to the surface in a one-stage job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify all regulatory agencies 48 hours prior to test 7. Make up 12-1/4" bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 8. Drill float equipment and approximately 20' of new hole · Perform LOT (or FIT if gradient reaches 16 ppg equivalent) · Record results and fax to town 9. Directionally drill 12-1/4" hole (KOP for starting to build angle at 6523' MD) to top of Brookian (Torok) target at 6860' MD/6860' MD. 10. Conventionally core Brookian interval with 8-1/2" core bit. ./ 11. RIH with 12-1/4" bit, ream out cored interval and continue drilling to intermediate casing TD at approx. ±7996' MD/±7858' TVD. Run MWD / LWD logging tools in drill string as required for ./ directional monitoring and formation data gathering. · Condition hole and mud for e-line logs. 12. Log 12-1/4" wellbore as necessary. ,/ 13. Make clean out trip in 12-1/4" hole prior to running casing. 14. Run 9-5/8" 40# L-80 BTC intermediate casing to ±7996' MD/±7858' TVD. Cement casing to bring cement to appx 5868' (±1000' above Brookian target interval). 15. Make up 8-1/2" bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town / 16. Drill float equipment and approximately 20' of new hole · Perform LOT (or FIT if gradient reaches 16 ppg equivalent) · Record results and fax to town ý 17. Drill 8-1/2" hole (holding angle of 40 deg) to appx 11,926' MD/10,868' TVD (just above top of Ivishak target interval). Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 18. Run 7" 26# L-80 BTC mod drilling liner to appx 11,926' MD/10,868' TVD. Cement liner to bring cement above liner top at appx 7846' MD. 19. MU 6-1/8" bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town ORIGINAL · Conoco Phillips Alasllnc. 20. Drill float equipment and approximately 20' of new hole · Perform LOT (or FIT if gradient reaches 16 ppg equivalent) · Record results and fax to town 21. Drill 6-1/8" hole while holding 40 deg hole angle to TD of appx 12,265' MD/11,128' lVD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 22. Log 6-1/8" wellbore as necessary:" 23. Make clean out trip in 6-1/8" hole prior to running liner (success case). Submit and execute P&A plan (failure case). 24. (success case) Run 4-1/2" 12.6# L-80 1BT mod production liner to TD at appx 12,265' MD/11,128' lVD. Cement liner to bring cement above liner top at appx 11, 776' MD. 25. Make a cleanout run with bit and scrapers · Displace to filtered seawater or brine- depending on formation pressure. · Pressure test well to 3000 psi for 30 minutes (perform low pressure test on liner lap). · Record results and fax to town 26. Run and land 4-1/2" tubing per schematic. 27. Nipple down BOP's. Install production tree and pressure test same to 5000 psi. 28. Secure well, release rig. 29. There will probably not be enough time to test Kokoda #5 in 2005 due to end of the winter season. Testing will have to occur in the future. 30. Upon completion of rig work (P&A or running completion), thoroughly clean location and block off further ice road access to location. ORIGINAL · Conoco Phillips Alasl,nC. DRilLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRilLING AREA RISKS Kokoda #5 Drillin9 Fluid Properties: Spud to surf csg Intermediate Hole Drilling Liner Production Hole pt @ 2500' MD 2500' to 7996' MD 7996' to 11,926' MD 11,926' to 12,265' MD Density 10.0 - 10.2 ppg 9.8 - 10.0 ppg 10.0 - 12.0 ppg 10.0 - 10.5 ppg PV 16 - 26 6 - 20 6-20 6-20 YP 30 - 40 25 - 35 20-35 20-35 Funnel Vis 75 - 90 75 - 90 45-90 45-90 Initial Gel 10 - 20 10 - 20 10-20 10-20 10 Min Gel 15 - 40 14 - 20 14-20 14-20 API Filtrate 7 - 15 <6 <6 <6 pH 9.5 - 10 9.0 - 10 9.0-10.0 9.0-10.0 % Solids ± 10% < 11% <11% <11% Drilline: Fluid System: Equipment list for Doyon 141 should be on file with AOGCC. Drilling fluid practices will be in accordance with the regulations stated in 20 MC 25.033. Maximum Anticipated Surface Pressure and Casin9 Design: The following information is used for calculation of the maximum anticipated surface pressures for the planned well: Casing Size 20" 13-3/8" 9-5/8" 7" Casing Settin De th 108' MD 1 108' 1VD 2500' MD 1 2500' 1VD 7996' MD 1 7858' 1VD 11926' MD/10868' 1VD Pore Pressure Pore Gradient Pressure 8.33 47 8.33 1082 9.7 3964 10.3 @ 5820 10868' 1VD 11.8 @ 6075 4986 psi 9900' 1VD 10.3 5960 4736 si 4-1/2" 12265' MD/11128' 1VD 18.6 Expected Maximum Mud Weights: 16" surface hole to 2500' MD 1 2500' 1VD: 10.2 ppg, elevated pore pressures of up to 10.0 ppg may be i/ present just below the permafrost at -575' 55. (See Seismic Pore Pressure Analysis attached.) 12-1/4" Intermediate hole to 7996' MD 1 7858' 1VD: 10.0 ppg The pore pressure is predicted to increase below -7000' 55 (7178' MD(TVD) from normal pressure gradient to up to 9.7 ppg at TD of 7996' MD/7858' 1VD. 01 ur~iG1NAL · Conoco Phillips AlasllnC. 8-1/2" Drilling Liner Intermediate hole to 11926' MD/10868' ND: 12.0 ppg. The pore pressure is predicted to increase below the 9-5/8" shoe to a maximum of 11.8 ppg at 9900' ND/ 10,662' MD. The pore pressure is expected to decrease from 9900' ND to 10.3 ppg at the bottom of the 8-1/2" interval at 11926' MD/l0868' ND. This large predicted pore pressure increase may not be a true pore pressure but may be due to lithology effects. 6-1/8" Production hole to TD of 12,265' MD/ll,128'ND: 10.5 ppg. The pore pressure is predicted to be 10.3 ppg below the 7" liner shoe at 11926' MD/l0868' ND and expected to decrease slightly to 10.2 ppg at TD of 12,265' MD/ll,128' ND. Procedure for Calculating Maximum Anticipated Surface Pressure: MASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) MASP = [(FG x 0.052) - 0.11] x D Where: MASP = Maximum Anticipated Surface Pressure FG = Fracture Gradient at the casing seat in Ib/gal 0.052 = Conversion factor from Ib/gal to psi/ft 0.11 = Gas Gradient in psi/ft (above 10,OOO'ND) D = True vertical depth to casing seat in ft from RKB OR 2) MASP = FPP - (0.11 x D) Where: FPP = Formation Pore Pressure at the next casing seat MASP Calculations 1. Drilling below 20" Conductor Casing MASP = [(FG x 0.052) - 0.11] x D = [(11.0 x 0.052) - 0.11] x 108' = 50 psi OR MASP = FPP - (0.11 x D) = 1082 - (0.11 x 2500') = 807 psi 2. Drilling below 13-3/8" Surface Casing MASP = [(FG x 0.052) - 0.11] x D MASP = [(13.8 x 0.052) - 0.11] x 2500' MASP = 1519 psi OR MASP = FPP - (0.11 x D) = 3964 - (0.11 x 7858') = 3100 psi 3. Drilling below 9-5/8" Intermediate Casing MASP = [(FG x 0.052) - 0.11] x D MASP = [(17.3 x 0.052) - 0.11] x 7858' MASP = 6204 psi ORIGINAL · Conoco Phillips Alas' Inc. OR MASP = FPP - (0.11 x D) = 6075 - (0.11 x 9900') = 4986 psi 4. Drilling below 7" Drilling Liner MASP = [(FG x 0.052) - 0.11] x D MASP = [(18.6 x 0.052) - 0.11] x 10868' MASP = 9316 psi OR MASP = FPP - (0.11 x D) = 5960 - (0.11 x 11,128') = 4736 psi Casing Design Performance Properties Size 20" 13-3/8" 9-5/8" 7" Grade B L-80 L-80 L-80 L-80 Connection PEB BTC BTC BTC-M IBT-M Tensile Strength Joint Body 4-1/2" 1545 M 979 M 667 M 288 M 1556 M 916 M 519 M 288 M Casing Setting Depth Rational: 20" @ 108' MD RKB Conductor casing to provide sufficient anchor and fracture gradient for diverter system. 13-3/8" @ 2500' MD RKB Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling 12-1/4" hole through first target and on to intermediate casing point. 9-5/8" @ 7996' MD RKB Intermediate casing is set to case off the upper target Brookian zone and to penetrate the LCU marker. 7" @ 11,926' MD RKB Drilling liner is set to case off potentially troublesome Shublik shales before drilling into the lower target, Ivishak. 4-1/2" @ 12,265' MD TD Production liner is set at TD in a successful Ivishak case for potential future testing. Well Proximity Risks: None Drilling Area Risks: Shallow Hazards: See attached explanation Drilling Risks: Drilling risks in the Kokoda #5 area are surface interval clays, intermediate interval sloughing shales, and lost circulation/breathing potential through the reservoir. Surface clay problems will be counteracted ORIGINAL · Conoeo Phillips Alas' Ine. with fluid chemistry and rheology. Shale stability will be controlled while drilling with fluid chemistry, rheology, hydraulics and fluid density. Lost circulation will be addressed with lost circulation material (LCM) and managed flowrates. See attached Pre-Drill Seismic Pore Pressure Prediction which includes offset well mud weight versus depth graphs and predicted formation pressure gradient for Kokoda #5. Annular Pumping Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The Kokoda #5 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. CPAI may request approval to inject or dispose of fluids in the Kokoda #5 13-3/8" x 9-5/8" annulus at a later date. This request would be made after sufficient data is available to meet the requirements of AOGCC's 20 AAC 25.080. Geology: Anticipated geologic markers, depth uncertainty, fluid properties, and pore pressures are as follows: FORMATION DEPTH (55) UNCERTAINTY POSSIBLE FLUID EST. PORE RKB = 178' TYPE PRESSURE, ÐSi Permafrost 575' 100' 326 Nanushuk 1130' 250' 567 Torok 3210' 200' 1468 Torok Objective (Brookian) 6680' 150' Probable Oil and/or 2970 Gas HRZ 7460' 150' 3614 LCU 7680' 150' 3923 UJU 8225' 4370 J2 9575' 5731 Shublik 10150' 6070 Ivishak Objective 10690' Probable Oil and/or 5821 Gas TD 10950' 150' 5960 Formation Evaluation: Anticipated logging, coring and testing for this well is as follows: I. Logging 16" Surface Interval (0 - Surface Casing setting depth) LWD: GR/Res / Wireline: None 12-1/4" Intermediate Hole (13-3/8" surface casing shoe to 9-518" setting depth) LWD: GR/Res/Density/Neutron/PWD .' Wireline: Dipole Sonic/Formation Imaging (FMI contingent on Brookian core success) ORIG1NAL · Conoco Phillips Alasllnc. 8-1/2" Drilling Liner Hole (9-5/8" casing shoe to 7" setting depth) LWD: GRjRes/Density/Neutron/PWD i/ Wireline: None 6-1/8" Production Hole (7" Shoe to TD) LWD: GR/Res/Density/Neutron/PWD .' Wireline: Dipole Sonic, MDT sampling tooljCMR nuclear magnetic resonance (success case only), Rotary coring tool (success case only) II. Coring 120' conventional core in the Brookian target interval near the bottom of the 12-1/4" hole interval. The core will be cut with an 8-1/2" core bit. II. Mudlogging 0/ Mudlogging service should be in operation from the base of the conductor casing to TD. Service most likely will include ROP on 5' intervals, lithology, total gas, sample collection, gas analysis of cuttings, gas chromatography, and H2S detection if Thirty to sixty-foot (30'-60') wet and dry samples will be collected from surface to surface casing ,r setting depth. Thirty-foot (30') wet and dry samples will be collected from surface casing setting depth to well ./ TD and ten-foot (10') wet and dry samples, or continuous, collected across any hydrocarbon intervals. III. Flow Testing There will probably not be time to perform a well test during this 2005 ice road season. If a test is deemed to be needed, the well will be cased and tubing run to allow for a future well test. ORIGINAL · Conoco Phillips Alas. Inc. Kokoda #5 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) 16" Hole /13-3/8" Casing Interval Risk Level Miti ation Strate Low -/ Monitor well at base of permafrost, increased mud weight, managed fluid rheologies, decreased circulating times, controlled drilling rates, low mud tem eratures Medium Maintain planned mud parameters, Increase mud weight, use weighted swee s, reduce fluid viscosi control ROP. Medium Oiverter drills, increased mud weight. -/ Predicted pore pressure may be as high as 10.0 ·ust below ermafrost at -575' SS. Medium Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries, port collar, controlled runnin seeds. Event Gas Hydrates Clay Balling Abnormal Pressure in Surface Formations Lost Circulation 12-1/4" Hole Event Lost circulation Risk Level Low Hole swabbing on trips Low Directional Control Low Sloughing Shale, Tight Hole Medium Abnormal Reservoir Pressure Medium Hydrogen Sulfide gas Low / Miti ation Strate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECO) monitoring, mud rheology, Pre- lanned LCM ills, lost circulation material. Reduced trip speeds, mud properties, proper hole filling, real time equivalent circulating density (ECO) monitoring, wei hted swee s. BHA design, on-sight geologic review and advisement of otential slum blocks. Increased mud density and fluid composition according to plan, controlled tri seeds swee s, ECO monitorin . Well control drills, increased mud weight, , pore pressure is predicted to increase from normal gradient above -7000' ss to 9.7 ppg at TO of -7680 ss. H2S drills, detection systems, alarms, standard well control practices, mud scaven ers ORIGINAL · Conoco Phillips Alasllnc. 8-1/2" Hole Event Lost circulation Hole swabbing on trips Directional Control Sloughing Shale, Tight Hole Abnormal Reservoir Pressure Hydrogen Sulfide gas 6-1/8" Hole Event Lost circulation Hole swabbing on trips Directional Control Sloughing Shale, Tight Hole Risk Level Low Low Low High Medium Low Risk Level Low Low Low Low v" Miti ation Strate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, Pre- lanned LCM ills, lost circulation material. Reduced trip speeds, mud properties, proper hole filling, real time equivalent circulating density (ECD) monitoring, wei hted swee s. BHA design, on-sight geologic review and advisement of otential slum blocks. Potentially troublesome Shublik shales. Increased mud density and fluid composition according to plan, controlled tri seeds, swee s, ECD monitorin . Well control drills, increased mud weight, pore pressure is predicted to increase from 9.7 ppg at -7680' ss (9-5/8" shoe) to 11.8 ppg at -9722' 55. This high pore pressure prediction might be due to lithological effects instead of a true ore ressure. H2S drills, detection systems, alarms, standard well control practices, mud scaven ers Miti ation Strate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, Pre- lanned LCM ills lost circulation material. Reduced trip speeds, mud properties, proper hole filling, real time equivalent circulating density (ECD) monitoring, wei hted swee s. BHA design, on-sight geologic review and advisement of otential slum blocks. Increased mud density and fluid composition according to plan, controlled trip speeds, sweeps, ECD monitoring. ORiG\NAL · Conoco Phillips Alas' Inc. Abnormal Reservoir Medium Well control drills, increased mud weight, Pressure pore pressure is predicted to be 10.3 ppg in the Ivishak formation at -10690' 55 and .-" not expected to increase as rathole is drilled to TD of -10950' 55. Hydrogen Sulfide gas Low ,I HzS drills, detection systems, alarms, standard well control practices, mud scavenqers ORIGINAL ~ . . ConocoPhillips Alaska Inc. Exploration Wells ASP Zone 5 (Kokoda) Kokoda Kokoda #5 Kokoda #5 ConocóPhillips Plan: Kokoda #5 (wp04) Standard Planning Report 22 December, 2004 ORIGINAL Iii Calculation Method: Error System: Scan Method: Error Surface: Warning Method: Minimum Curvature ISCWSA Elliptical Conic Rules Based Trav. Cylinder North Minimum Curvature Calculation Method: ISCWSA Trav. Cylinder North Elliptical Conic o o l!) .,... ~ .r. 15.. (!) o ¡¡¡ () :e ~ (!) :;¡ ... I- . eonocÓPhillips . SPERRY_SUN HES Planning Report EDM 2003.11 Single User Db ConocoPhíllips Alaska Inc. NAD 83 Exploration Wells ASP Zone 5 (Kokoda) okoda okoda #5 Kokoda #5 Kokoda #5 (wp04) Map System: Geo Datum: Map Zone: US State Plane 1983 North American Datum 1983 Alaska Zone 5 System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor 0.000 ft Northing: Easting: Slot Radius: 5,972,477.000ft 1.738,386.000ft Latitude: Longitude: Grid Convergence: Site Position: From: Position Uncertainty: Map Kokoda #5 Well Position +N/-5 +EI-W Position Uncertainty 0.000 ft 0.000 ft 0.000 ft Northing: Easting: Wellhead Elevation: 5,972,477.000 ft 1,738,386.000 ft ft Latitude: Longitude: Ground Level: 28.000 0.000 9.691 28.000 0.000 0.000 0.00 0.00 0.00 0.00 6,000.000 0.000 9.691 6.000.000 0.000 0.000 0.00 0.00 0.00 9.69 6.523.129 0.000 9.691 6,523.129 0.000 0.000 0.00 0.00 0.00 0.00 7.856.463 40.000 9.691 7,750.763 440.446 75.215 3.00 3.00 0.00 9.69 11.925.726 40.000 9.691 10.868.000 3,018.793 515.522 0.00 0.00 0.00 0.00 Kokoda #5 (Ivishak) T 12,265.132 40.000 9.691 11,128.000 3,233.845 552.247 0.00 0.00 0.00 0.00 12/22/2004 8:20:47AM Page 2 of 6 COMPASS 2003.11 Build 48 ORIGINAL . ~illips . SPERRY_SUN HES Planning Report EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. NAD 83 Exploration Wells ASP Zone 5 (Kokoda) Kokoda Kokoda #5 28.000 0.000 9.691 28.000 0.000 0.000 0.000 0.00 0.00 0.00 SIiL.· 3143ft f'NL &.1709ft FEL. See&- T11 N-R5VV 100.000 0.000 9.691 100.000 0.000 0.000 0.000 0.00 0.00 0.00 199.999 0.000 9.691 199.999 0.000 0.000 0.000 0.00 0.00 0.00 300.000 0.000 9.691 300.000 0.000 0.000 0.000 0.00 0.00 0.00 400.000 0.000 9.691 400.000 0.000 0.000 0.000 0.00 0.00 0.00 500.000 0.000 9.691 500.000 0.000 0.000 0.000 0.00 0.00 0.00 600.000 0.000 9.691 600.000 0.000 0.000 0.000 0.00 0.00 0.00 700.000 0.000 9.691 700.000 0.000 0.000 0.000 0.00 0.00 0.00 753.000 0.000 9.691 753.000 0.000 0.000 0.000 0.00 0.00 0.00 sase Permafrost 800.000 0.000 9.691 800.000 0.000 0.000 0.000 0.00 0.00 0.00 900.000 0.000 9.691 900.000 0.000 0.000 0.000 0.00 0.00 0.00 1,000.000 0.000 9.691 1,000.000 0.000 0.000 0.000 0.00 0.00 0.00 1,100.000 0.000 9.691 1,100.000 0.000 0.000 0.000 0.00 0.00 0.00 1.200.000 0.000 9.691 1.200.000 0.000 0.000 0.000 0.00 0.00 0.00 1,300.000 0.000 9.691 1,300.000 0.000 0.000 0.000 0.00 0.00 0.00 1,308.000 0.000 9.691 1.308.000 0.000 0.000 0.000 0.00 0.00 0.00 Nanushuk 1,400.000 0.000 9.691 1,400.000 0.000 0.000 0.000 0.00 0.00 0.00 1.500.000 0.000 9.691 1,500.000 0.000 0.000 0.000 0.00 0.00 0.00 1.600.000 0.000 9.691 1,600.000 0.000 0.000 0.000 0.00 0.00 0.00 1,700.000 0.000 9.691 1.700.000 0.000 0.000 0.000 0.00 0.00 0.00 1,800.000 0.000 9.691 1,800.000 0.000 0.000 0.000 0.00 0.00 0.00 1,900.000 0.000 9.691 1.900.000 0.000 0.000 0.000 0.00 0.00 0.00 2,000.000 0.000 9.691 2.000.000 0.000 0.000 0.000 0.00 0.00 0.00 2.100.000 0.000 9.691 2,100.000 0.000 0.000 0.000 0.00 0.00 0.00 2,200.000 0.000 9.691 2.200.000 0.000 0.000 0.000 0.00 0.00 0.00 2,300.000 0.000 9.691 2,300.000 0.000 0.000 0.000 0.00 0.00 0.00 2,400.000 0.000 9.691 2,400.000 0.000 0.000 0.000 0.00 0.00 0.00 2,500.000 0.000 9.691 2,500.000 0.000 0.000 0.000 0.00 0.00 0.00 2,600.000 0.000 9.691 2.600.000 0.000 0.000 0.000 0.00 0.00 0.00 2,700.000 0.000 9.691 2,700.000 0.000 0.000 0.000 0.00 0.00 0.00 2,800.000 0.000 9.691 2,800.000 0.000 0.000 0.000 0.00 0.00 0.00 2.900.000 0.000 9.691 2,900.000 0.000 0.000 0.000 0.00 0.00 0.00 3.000.000 0.000 9.691 3,000.000 0.000 0.000 0.000 0.00 0.00 0.00 3,100.000 0.000 9.691 3,100.000 0.000 0.000 0.000 0.00 0.00 0.00 3,200.000 0.000 9.691 3.200.000 0.000 0.000 0.000 0.00 0.00 0.00 3,300.000 0.000 9.691 3.300.000 0.000 0.000 0.000 0.00 0.00 0.00 3,388.000 0.000 9.691 3,388.000 0.000 0.000 0.000 0.00 0.00 0.00 Torok 3,400.000 0.000 9.691 3,400.000 0.000 0.000 0.000 0.00 0.00 0.00 3,500.000 0.000 9.691 3,500.000 0.000 0.000 0.000 0.00 0.00 0.00 3,600.000 0.000 9.691 3.600.000 0.000 0.000 0.000 0.00 0.00 0.00 3,700.000 0.000 9.691 3.700.000 0.000 0.000 0.000 0.00 0.00 0.00 3,800.000 0.000 9.691 3,800.000 0.000 0.000 0.000 0.00 0.00 0.00 3,900.000 0.000 9.691 3.900.000 0.000 0.000 0.000 0.00 0.00 0.00 4.000.000 0.000 9.691 4,000.000 0.000 0.000 0.000 0.00 0.00 0.00 4,100.000 0.000 9.691 4,100.000 0.000 0.000 0.000 0.00 0.00 0.00 4,200.000 0.000 9.691 4,200.000 0.000 0.000 0.000 0.00 0.00 0.00 4,300.000 0.000 9.691 4.300.000 0.000 0.000 0.000 0.00 0.00 0.00 4,400.000 0.000 9.691 4,400.000 0.000 0.000 0.000 0.00 0.00 0.00 4,500.000 0.000 9.691 4,500.000 0.000 0.000 0.000 0.00 0.00 0.00 12/22/2004 8:20:47AM Page 3 of 6 COMPASS 2003.11 Build 48 ORIGINAL . ConocÓÁ,illips . SPERRY_SUN HES Planning Report EDM 2003.11 Single User Db onocoPhillips Alaska Inc. NAD 83 loration Wells ASP Zone 5 (Kokoda) okada okada #5 okoda #5 4,600.000 0.000 9.691 4.600.000 0.000 0.000 0.000 0.00 0.00 0.00 4,700.000 0.000 9.691 4,700.000 0.000 0.000 0.000 0.00 0.00 0.00 4,800.000 0.000 9.691 4,800.000 0.000 0.000 0.000 0.00 0.00 0.00 4,900.000 0.000 9.691 4,900.000 0.000 0.000 0.000 0.00 0.00 0.00 5,000.000 0.000 9.691 5,000.000 0.000 0.000 0.000 0.00 0.00 0.00 5,100.000 0.000 9.691 5,100.000 0.000 0.000 0.000 0.00 0.00 0.00 5,200.000 0.000 9.691 5.200.000 0.000 0.000 0.000 0.00 0.00 0.00 5,300.000 0.000 9.691 5,300.000 0.000 0.000 0.000 0.00 0.00 0.00 5,400.000 0.000 9.691 5,400.000 0.000 0.000 0.000 0.00 0.00 0.00 5.500.000 0.000 9.691 5.500.000 0.000 0.000 0.000 0.00 0.00 0.00 5,600.000 0.000 9.691 5.600.000 0.000 0.000 0.000 0.00 0.00 0.00 5.700.000 0.000 9.691 5.700.000 0.000 0.000 0.000 0.00 0.00 0.00 5,800.000 0.000 9.691 5.800.000 0.000 0.000 0.000 0.00 0.00 0.00 5,900.000 0.000 9.691 5,900.000 0.000 0.000 0.000 0.00 0.00 0.00 6.000.000 0.000 9.691 6,000.000 0.000 0.000 0.000 0.00 0.00 0.00 6,100.000 0.000 9.691 6,100.000 0.000 0.000 0.000 0.00 0.00 0.00 6.200.000 0.000 9.691 6,200.000 0.000 0.000 0.000 0.00 0.00 0.00 6,300.000 0.000 9.691 6,300.000 0.000 0.000 0.000 0.00 0.00 0.00 6,400.000 0.000 9.691 6,400.000 0.000 0.000 0.000 0.00 0.00 0.00 6,500.000 0.000 9.691 6,500.000 0.000 0.000 0.000 0.00 0.00 0.00 6,523.129 0.000 9.691 6,523.129 0.000 0.000 0.000 0.00 0.00 0.00 Begini)ir@ 3.( O DLS: 6523.15Oft MD,6523.150ft TVD 6,600.000 2.305 9.691 6,599.979 1.525 0.260 1.547 3.00 3.00 0.00 6,700.000 5.305 9.691 6,699.747 8.067 1.378 8.184 3.00 3.00 0.00 6,800.000 8.305 9.691 6,799.031 19.748 3.372 20.034 3.00 3.00 0.00 6,859.740 10.098 9.691 6,858.000 29.165 4.980 29.587 3.00 3.00 0.00 Target (To 'Ok) : 6860ft MD, 685t¡,OOOft TVD,(31~ft FNL, 1709ft PEL, Sec5-T11N·R5W - Torok ObjectNø -l<okOda~ Tgt1 6,900.000 11.305 9.691 6,897.559 36.534 6.239 37.063 3.00 3.00 0.00 7,000.000 14.305 9.691 6.995.060 58.381 9.970 59.226 3.00 3.00 0.00 7,100.000 17.305 9.691 7,091.268 85.227 14.554 86.461 3.00 3.00 0.00 7,200.000 20.305 9.691 7,185.919 117.000 19.980 118.694 3.00 3.00 0.00 7.300.000 23.305 9.691 7.278.753 153.613 26.233 155.837 3.00 3.00 0.00 7,400.000 26.305 9.691 7,369.516 194.964 33.294 197.787 3.00 3.00 0.00 7.500.000 29.305 9.691 7,457.959 240.942 41.146 244.430 3.00 3.00 0.00 7,600.000 32.305 9.691 7,543.840 291.418 49.766 295.637 3.00 3.00 0.00 7,700.000 35.305 9.691 7.626.923 346.257 59.131 351.269 3.00 3.00 0.00 7,713.608 35.714 9.691 7,638.000 354.048 60.461 359.174 3.01 3.01 0.00 HRZ 7.800.000 38.305 9.691 7.706.980 405.306 69.214 411.173 3.00 3.00 0.00 7.856.463 40.000 9.691 7,750.763 440.446 75.215 446.822 3.00 3.00 0.00 End Dir;St$rt $ail@40.000:7856.46OftMD, 7750.761ft TVD 7,900.000 40.000 9.691 7,784.115 468.032 79.926 474.807 0.00 0.00 0.00 7,996.450 40.000 9.691 7,858.000 529.144 90.362 536.805 0.00 0.00 0.00 LCU 8,000.000 40.000 9.691 7,860.719 531.393 90.747 539.086 0.00 0.00 0.00 8,100.000 40.000 9.691 7,937.324 594.755 101.567 603.365 0.00 0.00 0.00 8,200.000 40.000 9.691 8,013.928 658.117 112.387 667.644 0.00 0.00 0.00 8,300.000 40.000 9.691 8,090.533 721.478 123.207 731.923 0.00 0.00 0.00 8,400.000 40.000 9.691 8,167.137 784.840 134.028 796.201 0.00 0.00 0.00 8,500.000 40.000 9.691 8,243.741 848.201 144.848 860.480 0.00 0.00 0.00 8,600.000 40.000 9.691 8,320.346 911.563 155.668 924.759 0.00 0.00 0.00 8,700.000 40.000 9.691 8,396.950 974.924 166.489 989.038 0.00 0.00 0.00 8.707.897 40.000 9.691 8,403.000 979.928 167.343 994.114 0.00 0.00 0.00 12/22/2004 8:20:47AM Page 4 of 6 COMPASS 2003. 11 Build 48 ORIGINAL . eonocó'Phillips SPERRY_SUN HES Planning Report . DM 2003.11 Single User Db ConocoPhillips Alaska Inc. NAD 83 Exploration Wells ASP Zone 5 (Kokoda) Kokoda Kokoda #5 koda #5 koda #5 (wp04) U;./U 8,800.000 8,900.000 9,000.000 9.100.000 9,200.000 9,300.000 9,400.000 9,500.000 9,600.000 9,700.000 9,800.000 9,900.000 10,000.000 10,100.000 10,200.000 10,300.000 10,400.000 10,470.197 ;,/2 10.500.000 40.000 9.691 9.775.830 2,115.431 361.254 2,146.055 0.00 0.00 0.00 10.600.000 40.000 9.691 9.852.435 2,178.793 372.074 2,210.334 0.00 0.00 0.00 10.700.000 40.000 9.691 9,929.039 2,242.154 382.895 2,274.613 0.00 0.00 0.00 10,800.000 40.000 9.691 10.005.644 2,305.516 393.715 2,338.892 0.00 0.00 0.00 10,900.000 40.000 9.691 10.082.248 2,368.877 404.535 2,403.170 0.00 0.00 0.00 11,000.000 40.000 9.691 10,158.853 2,432.239 415.356 2,467.449 0.00 0.00 0.00 11.100.000 40.000 9.691 10,235.457 2,495.600 426.176 2,531.728 0.00 0.00 0.00 11,200.000 40.000 9.691 10,312.061 2.558.962 436.996 2,596.007 0.00 0.00 0.00 11,220.806 40.000 9.691 10.328.000 2,572.145 439.248 2,609.381 0.00 0.00 0.00 Shublik 11,300.000 40.000 9.691 10.388.666 2,622.323 447.816 2.660.285 0.00 0.00 0.00 11,400.000 40.000 9.691 10,465.270 2,685.685 458.637 2,724.564 0.00 0.00 0.00 11,500.000 40.000 9.691 10,541.875 2,749.046 469.457 2,788.843 0.00 0.00 0.00 11,600.000 40.000 9.691 10,618.479 2.812.408 480.277 2,853.122 0.00 0.00 0.00 11,700.000 40.000 9.691 10,695.084 2,875.769 491.098 2,917.400 0.00 0.00 0.00 11,800.000 40.000 9.691 10.771.688 2,939.131 501.918 2,981.679 0.00 0.00 0.00 11,900.000 40.000 9.691 10,848.293 3,002.492 512.738 3,045.958 0.00 0.00 0.00 11,925.726 40.000 9.691 10,868.000 3,018.793 515.522 3,062.494 0.00 0.00 0.00 Targ!!t(lvishak) : 11 26ftMD, 10868ft WO, (125ftFNL. 1184ft FEL, sees- T11 N-RM . Iyishak Objecijye - (okøda tIS (l~isMk) TSt2 12,000.000 40.000 9.691 10,924.897 3,065.854 523.559 3,110.237 0.00 0.00 0.00 12,100.000 40.000 9.691 11,001.501 3.129.215 534.379 3,174.515 0.00 0.00 0.00 12.200.000 40.000 9.691 11,078.106 3,192.577 545.199 3,238.794 0.00 0.00 0.00 12,265.132 ' 40.000 9.691 11.128.000 3,233.845 552.247 3.280.660 0.00 0.00 0.00 TOIBH!-):12265ftMO,11127.997ft WO, (5189ft FNL, 1147ft FEL,Sec32-T12N-RSW 40.000 40.000 40.000 40.000 40.000 40.000 40.000 40.000 40.000 40.000 40.000 40.000 40.000 40.000 40.000 40.000 40.000 40.000 9.691 9.691 9.691 9.691 9.691 9.691 9.691 9.691 9.691 9.691 9.691 9.691 9.691 9.691 9.691 9.691 9.691 9.691 8,473.555 8,550.159 8,626.764 8,703.368 8,779.973 8,856.577 8,933.181 9.009.786 9,086.390 9,162.995 9,239.599 9.316.204 9,392.808 9,469.413 9,546.017 9,622.621 9,699.226 9,753.000 1,038.286 1.101.647 1,165.009 1,228.370 1,291.732 1,355.093 1.418.455 1,481.816 1,545.178 1,608.539 1,671.901 1,735.262 1,798.624 1,861.985 1.925.347 1.988.708 2,052.070 2,096.548 177.309 188.129 198.950 209.770 220.590 231.410 242.231 253.051 263.871 274.692 285.512 296.332 307.153 317.973 328.793 339.613 350.434 358.029 1.053.316 1.117.595 1,181.874 1,246.153 1,310.431 1,374.710 1,438.989 1,503.268 1,567.546 1,631.825 1.696.104 1,760.383 1,824.661 1.888.940 1.953.219 2.017.498 2,081.777 2,126.898 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 12/22/2004 8:20:47AM Page 50f6 ORiGINAL COMPASS 2003.11 Build 48 . eonocÓPhillips . SPERRY_SUN HES Planning Report OM 2003.11 Single User Ob ConocoPhillips Alaska Inc. NAO 83 Exploration Wells ASP Zone 5 (Kokoda) Kokoda Kokoda #5 Kokoda #5 Tgt1 0.00 0.00 6.858.000 0.000 0.000 5,972,477.000 1,738,386.000 - plan misses by 29.587ft at 6859.740ft MO (6858.000 TVO, 29.165 N, 4.980 E) - Point 70020' 04.804" N 153012' 18.587" W Kokoda #5 (Ivishak) T~ - plan hits target - Point 0.00 0.0010,868.000 3,018.793 515.522 5,975,502.000 1,738,862.000 70020' 34.495" N 1530 12' 03.526" W 753.000 753.000 Base Permafrost 0.00 1.308.000 1,308.000 Nanushuk 0.00 3,388.000 3.388.000 Torok 0.00 6,859.740 6.858.000 Torok Objective 0.00 7,713.608 7,638.000 HRZ 0.00 7.996.450 7,858.000 LCU 0.00 8,707.897 8,403.000 UJU 0.00 10.470.197 9,753.000 J2 0.00 11.220.806 10,328.000 Shublik 0.00 11.925.726 10,868.000 Ivishak Objective 0.00 28.010 6.523.150 6,859.740 7,856.460 11,925.720 12,265.130 28.010 6,523.150 6.858.000 7,750.761 10,867.995 11,127.998 0.000 0.000 29.165 440.444 3.018.789 3.233.844 0.000 0.000 4.980 75.215 515.521 552.246 SHL - 3143ft FNL & H09ft FEL. Sec5-T11N-R5W Begin Oir @ 3.00 OLS: 6523.150ft MO,6523.150ft TVO Target (Torok): 6860ft MO, 6858.00Oft TVO, (3143ft FNL, 1709ft FEL, Sec5-T1 End Oir, Start Sail @ 40.000: 7856.460ft MO, 7750. 761ft TVO Target (Ivishak) : 11926ftMO.10868ftTVO, (125ftFNL, 1184ftFEL, Sec5-T11~ TO (BHL) : 12265ft MO, 11127.997ft TVO, (5189ft FNL, 1147ft FEL, Sec32-T12 12/22/2004 8:20:47AM Page 6 of 6 COMPASS 2003.11 Build 48 ORIGlf~AL . . o ConocoPhillips Alaska Inc. NAD 83 Exploration Wells ASP Zone 5 (Kokoda) Kokoda Kokoda #5 Kokoda #5 Plan: Kokoda #5 (wp04) Sperry-Sun Combo Report 22 December, 2004 Local Coordinate Origin: Viewing Datum: TVDs to System: North Reference: Unit System: Centered on Well Kokoda #5 Kokoda @ 178.000ft (178 ft above MSL) N True API - US Survey Feet HALLIBURTON ORIGINl\ . . ConocoPhillips Alaska Inc. NAD 83 HALLIBURTON Exploration Wells ASP Zone 5 (Kokoda) Plan Report for Kokoda #5 . Kokoda #5 - Kokoda #5 (wp04) Measured Sub-System Vertical Local Coordinates Map Coordinates Dogleg Vertical Depth Inclination Azimuth Depth Depth +NI-S +E/-W Northing Easting Rate Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) (ft) 28.000 0.000 9.691 -150.000 28.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 SHL -3143f:tFNL & 1709ft FEL, Sec5-T11N-R5W 100.000 0.000 9.691 -78.000 100.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 199.999 0.000 9.691 21.999 199.999 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 300.000 0.000 9.691 122.000 300.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 400.000 0.000 9.691 222.000 400.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 500.000 0.000 9.691 322.000 500.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 600.000 0.000 9.691 422.000 600.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 700.000 0.000 9.691 522.000 700.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 753.000 0.000 9.691 575.000 753.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 Base Permafróst 800.000 0.000 9.691 622.000 800.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 900.000 0.000 9.691 722.000 900.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 1 ,000.000 0.000 9.691 822.000 1,000.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 1 ,100.000 0.000 9.691 922.000 1,100.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 1 ,200.000 0.000 9.691 1,022.000 1,200.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 1 ,300.000 0.000 9.691 1,122.000 1,300.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 1,308.000 0.000 9.691 1,130.000 1,308.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 Nanushuk 1,400.000 0.000 9.691 1,222.000 1,400.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 1,500.000 0.000 9.691 1,322.000 1,500.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 1,600.000 0.000 9.691 1 ,422.000 1,600.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 1,700.000 0.000 9.691 1,522.000 1,700.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 1,800.000 0.000 9.691 1,622.000 1,800.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 1,900.000 0.000 9.691 1,722.000 1,900.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 2,000.000 0.000 9.691 1,822.000 2,000.000 0.000 0.000 5,972,477.000 1 ,738,386.000 0.00 0.000 2,100.000 0.000 9.691 1,922.000 2,100.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 2,200.000 0.000 9.691 2,022.000 2,200.000 0.000 0.000 5,972,477.000 1 ,738,386.000 0.00 0.000 2,300.000 0.000 9.691 2,122.000 2,300.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 2,400.000 0.000 9.691 2,222.000 2,400.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 2,500.000 0.000 9.691 2,322.000 2,500.000 0.000 0.000 5,972,477.000 1 ,738,386.000 0.00 0.000 2,600.000 0.000 9.691 2,422.000 2,600.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 2,700.000 0.000 9.691 2,522.000 2,700.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 2,800.000 0.000 9.691 2,622.000 2,800.000 0.000 0.000 5,972,477.000 1 ,738,386.000 0.00 0.000 2,900.000 0.000 9.691 2,722.000 2,900.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 3,000.000 0.000 9.691 2,822.000 3,000.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 3,100.000 0.000 9.691 2,922.000 3,100.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 3,200.000 0.000 9.691 3,022.000 3,200.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 3,300.000 0.000 9.691 3,122.000 3,300.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 3,388.000 0.000 9.691 3,210.000 3,388.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 Torc>k 3,400.000 0.000 9.691 3,222.000 3,400.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 3,500.000 0.000 9.691 3,322.000 3,500.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 3,600.000 0.000 9.691 3,422.000 3,600.000 0.000 0.000 5,972,477.000 1 ,738,386.000 0.00 0.000 3,700.000 0.000 9.691 3,522.000 3,700.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 3,800.000 0.000 9.691 3,622.000 3,800.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 3,900.000 0.000 9.691 3,722.000 3,900.000 0.000 0.000 5,972,477.000 1 ,738,386.000 0.00 0.000 4,000.000 0.000 9.691 3,822.000 4,000.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 4,100.000 0.000 9.691 3,922.000 4,100.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 4,200.000 0.000 9.691 4,022.000 4,200.000 0.000 0.000 5,972,477.000 1 ,738,386.000 0.00 0.000 4,300.000 0.000 9.691 4,122.000 4,300.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 4,400.000 0.000 9.691 4,222.000 4,400.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 4,500.000 0.000 9.691 4,322.000 4,500.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 4,600.000 0.000 9.691 4,422.000 4,600.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 4,700.000 0.000 9.691 4,522.000 4,700.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 4,800.000 0.000 9.691 4,622.000 4,800.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 4,900.000 0.000 9.691 4,722.000 4,900.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 5,000.000 0.000 9.691 4,822.000 5,000.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 5,100.000 0.000 9.691 4,922.000 5,100.000 0.000 0.000 5,972,477.000 1,738,386.000 0.00 0.000 22 December, 2004 - 8:21 Page 2 of 5 COMPASS ORIGINAL · HALLIBURTON · ConocoPhillips Alaska Inc. NAD 83 Exploration Wells ASP Zone 5 (Kokoda) Plan Report for Kokoda #5 - Kokoda #5 - Kokoda #5 (wp04) Measured Depth Inclination (ft) (0) 40.000 40.000 40.000 40.000 40.000 40.000 40.000 40.000 40.000 40.000 40.000 40.000 40.000 40.000 40.000 40.000 40.000 40.000 40.000 40.000 Sub-8ystem Azimuth Depth (0) (ft) 9.691 9.691 9.691 9.691 9.691 9.691 9.691 9.691 9.691 9.691 9.691 9.691 9.691 9.691 9.691 9.691 9.691 9.691 9.691 9.691 22 December, 2004 - 8:21 7,682.719 7,759.324 7,835.928 7,912.533 7,989.137 8,065.741 8,142.346 8,218.950 8,225.000 8,295.555 8,372.159 8,448.764 8,525.368 8,601.973 8,678.577 8,755.181 8,831.786 8,908.390 8,984.995 9,061.599 Vertical Depth (ft) 7,860.719 7,937.324 8,013.928 8,090.533 8,167.137 8,243.741 8,320.346 8,396.950 8,403.000 8,473.555 8,550.159 8,626.764 8,703.368 8,779.973 8,856.577 8,933.181 9,009.786 9,086.390 9,162.995 9,239.599 Local Coordinates +NI-8 +E/-W (ft) (ft) 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 531.393 594.755 658.117 721.478 784.840 848.201 911.563 974.924 979.928 1,038.286 1,101.647 1,165.009 1 ,228.370 1,291.732 1,355.093 1 ,418.455 1,481.816 1,545.178 1 ,608.539 1,671.901 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.260 1.378 3.372 4.980 6.239 9.970 14.554 19.980 26.233 33.294 41.146 49.766 59.131 60.461 69.214 75.215 79.926 90.362 90.747 101 .567 112.387 123.207 134.028 144.848 155.668 166.489 167.343 177.309 188.129 198.950 209.770 220.590 231.410 242.231 253.051 263.871 274.692 285.512 Page 3 of 5 OR1G\N.AL Map Coordinates Northing Easting (ft) (ft) 5,972,477.000 5,972,477.000 5,972,477.000 5,972,477.000 5,972,477.000 5,972,477.000 5,972,477.000 5,972,477.000 5,972,477.000 5,972,477.000 5,972,477.000 5,972,477.000 5,972,477.000 5,972,477.000 5,972,477.000 5,972,478.528 5,972,485.084 5,972,496.788 5,972,506.225 5,972,513.609 5,972,535.501 5,972,562.403 5,972,594.241 5,972,630.929 5,972,672.365 5,972,718.437 5,972,769.018 5,972,823.969 5,972,831.776 5,972,883.139 5,972,918.352 5,972,945.994 5,973,007.232 5,973,009.486 5,973,072.978 5,973,136.470 5,973,199.962 5,973,263.453 5,973,326.945 5,973,390.437 5,973,453.929 5,973,458.943 5,973,517.420 5,973,580.912 5,973,644.404 5,973,707.896 5,973,771 .388 5,973,834.879 5,973,898.371 5,973,961 .863 5,974,025.355 5,974,088.847 5,974,152.338 1,738,386.000 1,738,386.000 1,738,386.000 1,738,386.000 1 ,738,386.000 1,738,386.000 1,738,386.000 1,738,386.000 1,738,386.000 1,738,386.000 1,738,386.000 1,738,386.000 1,738,386.000 1,738,386.000 1,738,386.000 1 ,738,386.240 1,738,387.272 1,738,389.114 1 ,738,390.599 1,738,391.761 1,738,395.205 1,738,399.439 1,738,404.449 1,738,410.222 1,738,416.742 1,738,423.991 1,738,431.951 1,738,440.597 1,738,441.826 1,738,449.908 1,738,455.449 1,738,459.799 1,738,469.435 1,738,469.790 1,738,479.780 1,738,489.771 1,738,499.762 1,738,509.753 1,738,519.743 1,738,529.734 1,738,539.725 1,738,540.514 1,738,549.716 1,738,559.707 1,738,569.697 1,738,579.688 1,738,589.679 1,738,599.670 1,738,609.660 1,738,619.651 1,738,629.642 1,738,639.633 1,738,649.623 Dogleg Rate (0/100ft) Vertical Section (ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 5,200.000 0.000 9.691 5,022.000 5,200.000 5,300.000 0.000 9.691 5,122.000 5,300.000 5,400.000 0.000 9.691 5,222.000 5,400.000 5,500.000 0.000 9.691 5,322.000 5,500.000 5,600.000 0.000 9.691 5,422.000 5,600.000 5,700.000 0.000 9.691 5,522.000 5,700.000 5,800.000 0.000 9.691 5,622.000 5,800.000 5,900.000 0.000 9.691 5,722.000 5,900.000 6,000.000 0.000 9.691 5,822.000 6,000.000 6,100.000 0.000 9.691 5,922.000 6,100.000 6,200.000 0.000 9.691 6,022.000 6,200.000 6,300.000 0.000 9.691 6,122.000 6,300.000 6,400.000 0.000 9.691 6,222.000 6,400.000 6,500.000 0.000 9.691 6,322.000 6,500.000 6,523.129 0.000 9.691 6,345.129 6,523.129 BeginJDir@3.Qq DLS: 6523;150ft MD,6523.150ft TVD 6,600.000 2.305 9.691 6,421.979 6,599.979 1.525 6,700.000 5.305 9.691 6,521.747 6,699.747 8.067 6,800.000 8.305 9.691 6,621.031 6,799.031 19.748 6,859.740 10.098 9.691 6,680.000 6,858.000 29.165 rarg~ (TorCill<) :. 61f60ft MD, 6858.00Oft TVD, (3143ft FNL,1709ft FEL, Sec5 6,900.000 11.305 9.691 6,719.559 6,897.559 36.534 7,000.000 14.305 9.691 6,817.060 6,995.060 58.381 7,100.000 17.305 9.691 6,913.268 7,091.268 85.227 7,200.000 20.305 9.691 7,007.919 7,185.919 117.000 7,300.000 23.305 9.691 7,100.753 7,278.753 153.613 7,400.000 26.305 9.691 7,191.516 7,369.516 194.964 7,500.000 29.305 9.691 7,279.959 7,457.959 240.942 7,600.000 32.305 9.691 7,365.840 7,543.840 291.418 7,700.000 35.305 9.691 7,448.923 7,626.923 346.257 7,713.608 35.714 9.691 7,460.000 7,638.000 354.048 HRZ 7,800.000 38.305 9.691 7,528.980 7,706.980 405.306 7,856.463 40.000 9.691 7,572.763 7,750.763 440.446 End Dir, Start Sail @ 40.000: 7856A60ft MD, 7750.761ft TVD 7,900.000 40.000 9.691 7,606.115 7,784.115 468.032 7,996.450 40.000 9.691 7,680.000 7,858.000 529.144 ,LCU 8,000.000 8,100.000 8,200.000 8,300.000 8,400.000 8,500.000 8,600.000 8,700.000 8,707.897 UJU 8,800.000 8,900.000 9,000.000 9,100.000 9,200.000 9,300.000 9,400.000 9,500.000 9,600.000 9,700.000 9,800.000 3.00 3.00 3.00 3.00 1.547 8.184 20.034 29.587 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.01 37.063 59.226 86.461 118.694 155.837 197.787 244.430 295.637 351.269 359.174 3.00 3.00 411.173 446.822 0.00 0.00 474.807 536.805 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 539.086 603.365 667.644 731.923 796.201 860.480 924.759 969.038 994.114 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1,053.316 1,117.595 1,181.874 1,246.153 1,310.431 1,374.710 1,438.989 1,503.268 1,567.546 1,631.825 1,696.104 COMPASS . . ConocoPhillips Alaska Inc. NAD 83 HALLIBURTDN Exploration Wells ASP Zone 5 (Kokoda) Plan Report for Kokoda #5 - Kokoda #5 - Kokoda #5 (wp04) Measured Sub-System Vertical Local Coordinates Map Coordinates Dogleg Vertical Depth Inclination Azimuth Depth Depth +N/-S +E/-W Northing Easting Rate Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) (ft) 9,900.000 40.000 9.691 9,138.204 9,316.204 1,735.262 296.332 5,974,215.830 1,738,659.614 0.00 1,760.383 10,000.000 40.000 9.691 9,214.808 9,392.808 1,798.624 307.153 5,974,279.322 1,738,669.605 0.00 1,824.661 10,100.000 40.000 9.691 9,291 .413 9,469.413 1,861.985 317.973 5,974,342.814 1,738,679.596 0.00 1,888.940 10,200.000 40.000 9.691 9,368.017 9,546.017 1,925.347 328.793 5,974,406.306 1,738,689.587 0.00 1,953.219 10,300.000 40.000 9.691 9,444.621 9,622.621 1,988.708 339.613 5,974,469.797 1,738,699.577 0.00 2,017.498 10,400.000 40.000 9.691 9,521.226 9,699.226 2,052.070 350.434 5,974,533.289 1,738,709.568 0.00 2,081.777 10,470.197 40.000 9.691 9,575.000 9,753.000 2,096.548 358.029 5,974,577.859 1,738,716.581 0.00 2,126.898 J2 10,500.000 40.000 9.691 9,597.830 9,775.830 2,115.431 361.254 5,974,596.781 1,738,719.559 0.00 2,146.055 10,600.000 40.000 9.691 9,674.435 9,852.435 2,178.793 372.074 5,974,660.273 1,738,729.550 0.00 2,210.334 10,700.000 40.000 9.691 9,751.039 9,929.039 2,242.154 382.895 5,974,723.764 1,738,739.540 0.00 2,274.613 10,800.000 40.000 9.691 9,827.644 10,005.644 2,305.516 393.715 5,974,787.256 1,738,749.531 0.00 2,338.892 10,900.000 40.000 9.691 9,904.248 10,082.248 2,368.877 404.535 5,974,850.748 1,738,759.522 0.00 2,403.170 11,000.000 40.000 9.691 9,980.853 10,158.853 2,432.239 415.356 5,974,914.240 1,738,769.513 0.00 2,467.449 11,100.000 40.000 9.691 10,057.457 10,235.457 2,495.600 426.176 5,974,977.732 1 ,738,779.504 0.00 2,531.728 11 ,200.000 40.000 9.691 10,134.061 10,312.061 2,558.962 436.996 5,975,041.223 1,738,789.494 0.00 2,596.007 11,220.806 40.000 9.691 10,150.000 10,328.000 2,572.145 439.248 5,975,054.434 1,738,791.573 0.00 2,609.381 Shublik 11,300.000 40.000 9.691 10,210.666 10,388.666 2,622.323 447.816 5,975,104.715 1 ,738,799.485 0.00 2,660.285 11,400.000 40.000 9.691 10,287.270 10,465.270 2,685.685 458.637 5,975,168.207 1,738,809.476 0.00 2,724.564 11,500.000 40.000 9.691 10,363.875 10,541.875 2,749.046 469.457 5,975,231.699 1,738,819.467 0.00 2,788.843 11,600.000 40.000 9.691 10,440.479 10,618.479 2,812.408 480.277 5,975,295.191 1,738,829.457 0.00 2,853.122 11,700.000 40.000 9.691 10,517.084 10,695.084 2,875.769 491.098 5,975,358.682 1,738,839.448 0.00 2,917.400 11,800.000 40.000 9.691 10,593.688 10,771.688 2,939.131 501.918 5,975,422.174 1,738,849.439 0.00 2,981.679 11,900.000 40.000 9.691 10,670.293 10,848.293 3,002.492 512.738 5,975,485.666 1,738,859.430 0.00 3,045.958 11,925.726 40.000 9.691 10,690.000 10,868.000 3,018.793 515.522 5,975,502.000 1,738,862.000 0.00 3,062.494 ....arget (Ivishak).: 11926ft MD; 10868ft TVD, (125ft FNL, 1184ft FEL, Sec5-T 12,000.000 40.000 9.691 10,746.897 10,924.897 3,065.854 523.559 5,975,549.158 1,738,869.421 0.00 3,110.237 12,100.000 40.000 9.691 10,823.501 11,001.501 3,129.215 534.379 5,975,612.650 1,738,879.411 0.00 3,174.515 12,200.000 40.000 9.691 10,900.106 11,078.106 3,192.577 545.199 5,975,676.141 1,738,889.402 0.00 3,238.794 12,265.132 40.000 9.691 10,950.000 11,128.000 3,233.845 552.247 5,975,717.495 1,738,895.909 0.00 3,280.660 TP(BHL,): 12265ftMO, 11127.997ft TVD, (5189ft FNL, 1147ft FEL, Sec32-T Based upon Minimum Curvature type calculations, at a Measured Depth of 12,265.13ft the Bottom Hole Displacement is 3,280.66ft in the Direction of 9.690 (Grid). Plan Annotations Measured Vertical Depth Depth (ft) (ft) 28.010 28.010 6,523.150 6,523.150 6,859.740 6,858.000 7,856.460 7,750.761 11,925.720 10,867.995 12,265.130 11,127.998 Vertical Section Information Local Coordinates +N/-S +E/-W (ft) (ft) 0.000 0.000 0.000 0.000 29.165 4.980 440.444 75.215 3,018.789 515.521 3,233.844 552.246 Corrvnent SHL - 3143ft FNL & 1709ft FEL, SecS- T11 N-RSW Begin Dir @ 3.00 DLS: 6523.15Oft MD,6523.15OO TVD Target (Torok): 68600 MD, 6858.oooft TVD, (3143ft FNL, 1709ft FEL, Se End Dir, Start Sail @ 40.000: 7856.46Oft MD, 7750.761ft TVD Target (Ivishak): 11926ft MD, 10868ft TVD, (125ft FNL, 1184ft FEL, See TD (BHL) : 12265ft MD, 11127.997ft TVD, (5189ft FNL, 1147ft FEL, See: Angle Type Target Origin Azimuth Type (0) 9.691 Slot Origin +NCS +E/-W (ft) (ft) 0.000 0.000 Start TVD (ft) 28.000 TD No Target (Freehand) 22 December, 2004 - 8:21 Page 4 of 5 COMPASS ORIGINAL . . ConocoPhillips Alaska Inc. NAD 83 Exploration Wells ASP Zone 5 (Kokoda) HALLIBURTON North Reference Sheet for Kokoda - Kokoda #5 - Kokoda #5 Coordinate System is US State Plane 1983, Alaska Zone 5 using datum North American Datum 1983, ellipsoid GRS 1980 Projection method is Transverse Mercator (Gauss-Kruger) Central Meridian is -154.00°, Longitude Origin:O.OO°, Latitude Origin:O.OO° False Easting: 1,640,416.667ft, False Northing: 0.0000, Scale Reduction: 0.99991090 Grid Coordinates of Well: 5,972,477.000, 1,738,386.000 Geographical Coordinates of Well: 70° 20' 04.80" N, 153° 1'Z 18.59" W Grid Convergence at Surface is: 0.75° Magnetic Convergence at surface is: -21.93° ( 3 September 2004, , BGGM2004) T M Magnetic MOdel: Date: Declination: I nclination/Dip: Field Strength: BGGM2004 03-Sep-04 22.68° 80.36° 57406 GridNorthisO.75° EastofTrue North (Grid Convergence) Magnetic North is 22,689 East ofTrue North (Magnetic Dedination) Magnetic North is21.939 East of Grid North (Magnetic Convergence) To convert a True Direction to a Grid Direction, Subtract 0.75° To convert a Magnetic Direction to a True Direction, Add 22.68° To convert a Magnetic Direction to a Grid Direction, Add 21.93° 22 December, 2004 - 8:21 Page 5 of 5 COMPASS ORIGiNAL · Kokoda #5. Proposed Completion Schematic wIT' Liner 12/14/04 20" Conductor ~+1.108' MD (80') J Surfaoe Casing 13-318" 68# L-80 @ +1- 2500' MD Depths are based on est rig RKB Brookian Formation @ 6858' Intermediate #1 9-5/8" 40.0# L-80 BTC (+1- 7996' MDI7858'TVD) Intermediate #2 csg. 7" 26.0# L-80 BTCM (+1- 11,926' MD/1 O,868'TVD) Ivishak Formation @ 10,868' TVD, 11,926' MD Production Liner 4-1/2" 12.6# L-80 IBT-M (+1- 12,265' MDI 11,128' TVD) Doyon 141 RKB to LDS 28' l 4-1/2" FMC Gen V Tubing Hanger, 4-1/2" L-80 IBT-M pin down w/2.3' pup. Special Drift to 3.91" 1 jt 4-1/2" 12.6# L-80 IBT-M Tubing Special Drift to 3.91" 4-1/2" 12.6# L-80 IBT-M Spaoeout Pups Special Drift to 3.91" 4-1/2" Cameo DS Landing Nipple w/3.875" No-go profile set @ +1- 500' 4-1/2" 12.6# L-80 IBT-M Tubing. Special Drift to 3.843" 4-W' X 1" Cameo KBG-2 GLM wI dummy valve @ 2500' +1- 4-1/2" 12.6# L-80 IBT-M Tubing. Special Drift to 3.843" 4-Yz" X 1" Cameo KBG-2 GLM wlRK shear out valve 1 jt 4-1/2" 12.6# L-80 IBT-M tubing. Special Drift to 3.843" 4-1/2" Cameo "DB" nipple wI 3.813" profile @ xxxx' MD 1 jt 4-1/2" 12.6# L-80 IBT-M tubing 4·Yz" Weatherford Fiber Optic Gauge Mandrel w/cable to surfaoe @ xxxx' MD 1 joint 4-1/2" 12.6# L-80 IBT-M tubing 190-47 PBR with seal assembly, 15' Stroke, 4.75" ID, 8.25" OD Seoop Guide 4-Yz" x 9-5/8" Baker S-3 Permanent Packer 1 jt 4-1/2" 12.6# L-80 IBT-M tubing 4-1/2" Baker "CMU" Sliding Sleeve wI "3.75" DB profile @ xxxx' MD Liner Assemblv 7" x 9-5/8" ZXP Liner Top Packer with C-2 Profile & 10' Tieback Extension 7" x 9-5/8" FlexLock Liner Hanger 7" Baker Insert Landing Collar 7" Float Collar 7" Float Shoe 4-1/2" 12.6# L-80 IBT-M tubing 4-1/2" Cameo "DB" nipple wI 3.687" profile @ xxxx' MD 1 joint 4-1/2" 12.6# L-80 IBT-M tubing Baker locator sub @ xxxx' MD 5" Baker Bullet seal assembly wI 15' stroke, 4-1/2" L-80 IBT box up @ xxxx' MD Liner Assembly (run on drillDiDe). Baker 7" x 4-1/2" 'ZXP' Liner Top Packer with HR profile & 15' Tieback Ext. 5.75" OD, 5.00" IC Baker 7" x 4-1/2" 'FlexLock' Liner Hanger 4-1/2" 12.6# L-80 IBT-M liner as needed 4-1/2" Baker Landing Collar @ 8091' DPM 1 jt 4-1/2" 12.6# L-80 IBT-M tubing 4-1/2" Baker Float Collar 2 jts 4-1/2" 12.6# L-80 IBT-M tubing 4-1/2" Baker Float Shoe ORIGINAL TJB 12114/04 Rig: Doyon 141 Location: Exploration Client: CPAI Revision Date: 12/17/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com < TOC at Surface Previous Csg. < 20", 91.5# casing at 80' MD < Base of Permafrost at 753' MD (753' TVD) < Top of Tail at 1,700' MD < 133/8",68.0# casing in 16" OH TD at 2,500' MD (2,500' TVD) Mark of Schlumberger IOIDberg8r Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 350% excess in the permafrost and 45% excess below the permafrost. The top of the tail slurry is designed to be at 1,700' MD. Lead Slurrv Minimum pump time: 220 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 3 1.0190 ft 1ft x (80') x 1.00 (no excess) = 3 0.4206 ft 1ft x (753' - 80') x 4.50 (350% excess) = 0.4206 ft3/ft x (1700' - 753') x 1.45 (45% excess) = 81.5 ft3 + 1273.8 ft3+ 577.5 ft3 = 1932.8 ft3 14.45 ft3/sk = Round up to 440 sks 81.5 ft3 1273.8 ft3 577.5 ft3 1932.8 ft3 434.3 sks Have 410 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurrv Minimum pump time: 170 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.52 ft3/sk 0.4206 ft3/ft x (2500' - 1700') x 1.45 (45% excess) = 0.8407 ft3/ft x 80' (Shoe Joint) = 487.9 ft3 + 67.3 ft3 = 555.2 ft31 2.52 ft3/sk = Round up to 230 sks 487.9 ft3 67.3 ft3 555.2 ft3 220.3 sks BHST = 70°F, Estimated BHCT = 75°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume Cumulative Stage Time Time (min) (bbl) (min) CW100 5 50 10.0 10.0 Drop Bottom Plug 5.0 15.0 MudPUSH XL 5 50 10.0 25.0 Lead Slurry 7 349 49.9 74.9 Tail Slurry 6 103 17.2 92.1 Drop Top Plug 5.0 97.1 Displacement 7 347 49.6 146.7 Slow Rate 3 15 5.0 151.7 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* XL, Pv? 17-21, Ty ? 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ORIGINAL Rig: Doyon 141 Location: Exploration Client: CPAI Revision Date: 12/16/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com Previous Csg. < 133/8",68.0# casing at 2,500' MD < Top of Tail at 5,858' MD < 95/8", 40.0# casing in 121/4" OH TD at 7,996' MD (7,858' TVD) ScblulI glP Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 50% excess. Tail slurry is designed for 1000' MD above Brookian - (2138' MD annular length). Tail Slurrv Minimum thickening time: 230 min. (Pump time plus 90 min.) 15.8 ppg Class G + 0.2%046, 0.3%065, 0.07 B155, 0.4% D167 -1.16 ft3/sk 3 0.3132 ft 1ft x 2138' x 1.50 (50% excess) = 0.4257 ft3/ft x 80' (Shoe Joint) = 1004.4 ft3 + 34.1 ft3 = 1038.5ft3/1.16 ft3/sk= Round up to 900 sks 1004.4 ft3 34.1 ft3 1038.5 ft3 895.3 sks BHST = 160°F, Estimated BHCT = 124°F. (BHST calculated using a gradient of 1.9°F/100 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume Cumulative Stage Time Time (min) lbb!) lmin} CW100 5 50 10.0 10.0 Drop Bottom Plug 5.0 15.0 MudPUSH II 5 50 10.0 25.0 Tail Slurry 5 186 37.2 62.2 Drop Top Plug 5.0 67.2 Displacement 7 580 82.9 150.1 Slow Rate 3 20 6.7 156.8 MUD REMOVAL Recommended Mud Properties: 9.8 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv ? 19-22, Ty ? 22-29 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ORIGI~~AL Rig: Doyon 141 Location: Exploration Client: CPAI Revision Date: 12/16/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com Top of Tail at < 7,646' MD < Liner Top at 7,846' MD Previous Csg. 95/8",40.0# casing at 7,996' MD < 7",26.0# casing in 8 1/2" OH TD at 11,926' MD (10,868' TVD) Preliminary Job Oeslgn based on limited input data. For estimate purposes only. IIblPg8P Volume Calculations and Cement Systems Volumes are based on 50% e2<cess. Displacement is calculated with a 5.0"- 19.5# drill string. Tail Slurrv Minimum thickening time: 180 min. (pump time plus 90 min.) 15.8 ppg Class G + 0.4% D167 + 0.15% B155 + 0.4% D65 + 0.2% D46 -1.16 ft3/sk Liner Caq: 0.2894 ft 1ft x 200' x 1.00 (no excess) = Liner Lar!': 3 0.1585 ft 1ft x (7996' - 7846') x 1.00 (no excess) = Annular Volume: 0.1268 ft3/ft x (11926' - 7996') x 1.50 (50% excess) = Shoe Volume: 3 0.2148 ft 1ft x 80' x 1.00 (no excess) = Totals: 57.9ft3 + 23.8ft3 + 747.5ft3 + 19.3ft3 = 848.5 ft3/1.16 ft3/sk = Round up to 740 sks 57.9 ft3 23.8 ft3 747.5 ft3 19.3 ft3 848.5 ft3 731.5 sks BHST = 21rF, Estimated BHCT = 168°F. (BHST calculated using a gradient of 1.9"F/100 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume Cumulative Stage Time Time (min> lbb ) lmin) CW100 5 50 10.0 10.0 MudPUSH II 5 50 10.0 20.0 Tail Slurry 5 153 30.6 50.6 Drop Top Plug 3.0 53.6 Displacement 5 282 56.4 110.0 Slow Rate 3 10 3.3 113.3 MUD REMOVAL Recommended Mud Properties: 11.5 ppg, As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 13.0 ppg MudPUSH* XL, Pv? 19-22, Ty ? 22-29 Centralizers: Recommend 1 per joint from 7846' MD to TD for proper cement placement. Mark of Schlumberger ORIGIN~At" Rig: Doyon 141 Location: Exploration Client: CPAI Revision Date: 12/16/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com Top of Tail at < 11,576' MD < Liner Top at 11,776' MD Previous Csg. 7", 26.0# casing at 11,926' MD < 41/2", 12.6# casing in 6 1/8" OH TD at 12,265' MD (11,128' TVD) Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 50% excess. SchlumblPl8P Tail Slurry Minimum thickening time: 140 min. (pump time plus 90 min.) 15.8 ppg Class G + 2.0 gps 0600G + 0.02% 8155 + 0.3% D65 + 0.2 gps D47 -1.16 ft3/sk Liner Cag: 0.0785 ft 1ft x 200' x 1.00 (no excess) = Liner Lap..: 3 0.1276 ft 1ft x (11926' - 11776') x 1.00 (no excess) = Annular Volume: 0.0942 ft31ft x (12265' - 11926') x 1.50 (50% excess) = Shoe Volume: 3 0.0854 ft 1ft x 80' x 1.00 (no excess) = Totals: 15.7ft3 + 25.5ft3 + 47.9 ft3 + 7.7ft3 = 96.8 ft3/1.17 ft3/sk = Round up to 90 sks 15.7 ft3 25.5 ft3 47.9 ft3 7.7 ft3 96.8 ft3 82.7 sks BHST = 222°F, Estimated BHCT = 172°F. (BHST calculated using a gradient of 1.9°F/100 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume Cumulative Stage Time Time (min) (bb ) (min) CW100 5 10 2.0 2.0 MudPUSH II 5 20 4.0 6.0 Tail Slurry 5 18 3.6 9.6 Drop Top Plug 5.0 14.6 Displacement 5 178.2 35.6 50.2 Slow Rate 3 10 3.3 53.5 MUD REMOVAL Recommended Mud Properties: 11.5 ppg. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 13.0 ppg MudPUSH* II, Pv? 19-22, Ty ? 22-29 Centralizers: Recommend 1 per joint from 11776' MO to TO for proper cement placement. Mark of Schlumberger ORIG'~Ll\L,. o 1,000 _ L I 2,000 I I - , T - J - I 3,000 L _ 1. I I I 4,000 I I T - , -, I I I 5,000 L _..L_..J I I I I 6,000 I -, T - ì "1 - -I- I I I --- I I Ë I I I .c:: 7,000 _ L_ ._ --.l _ _! !.. I ... I Q I I .J _ --1_ I #5 ROP I I I L _ L _ ..1 _ .1 _ --1 _ _I_ I I I I I I I I I I I I ¡--I--I- I I I I r -, I I L _Ml iWi I I I I 8,000 I I I I I I I r - T , - ,- -r , T - T I I I I I I I I I I I I I I 9,000 L - ~ ~ - -' _1"- _L _L L - ~ - L I I I I I I I I I 10,000 I - , I I I .- T - ï I I 11,000 _ L I .L _-' 12,000 -I-T-,-¡ I I 13,000 _ L _ .L _ J_ 14,000 I 1- -I- I I I I I I , , -- ¡- - I - í I I I .i _ J ), ...J _ _I _ _I_ I I I I I %1 '1 - I - -I Ii I _..l _ ..J , I I I T I I I I T -, I I I I _L_L I I I J. _ J _ _I .l _ -1 _-.J --'--'- .L _ _L _ ..J _ __I _ _1_ _ ..J _ _I_ I I I I I I L _ L I I I I I r - T I I T - T I I I I I I J. _ .J. _ --1 I I" - Î - -I- I I I I .1_...J_ I I I I I I _.1_ _1_ _ L _ I I I I 1--1--1- I I I I I I I I I I --1- - I - I - T I I I I I I I I I ì - I - -1- I I I I I I I I -!--i-T-ì I I I "I - -1- -I- I I I I I _i_ _1_ I I L _ L _ 1. 1- í- I I I ¡-I- I I I I _ L _ 1. I I .1 I I I I I I r-T-ì-j I I I _ L _ 1. _ J _ -Ì _ _I _ _1_ _ I I I I I I I I I I I I I I I I I I I I I I I I I '-1-- -1- - ¡- - 1- T - ì i - -I I I I I I L_L_-L ..J _ _1_ --1- I I -1- -:- -!- I I I I I I I L_1._-.1_..J I I I I _1- _I_ I J _ -"- - T-i-, I _1- _ I I I I L _ 1. _ .J I _1__1__1- I I I I I I I - ---; --I I I I -1- - :' : ': I I I -1- -¡-- I I I -T-ì-, I I I I r - r-T-¡-î I I I I _ _ 1_ _ L _ L I I - , I ~I I I -I-I-T I I I I I I I I _ i_ _ L _ L _ l. I I I --¡- -:- -I-- I I I I I I 1. _ .J _ ..J _ _I I I I I I I _1__L_1-_1._-1 I I I I I I I I I I I I I -.J _ _1_ _I_ I I I I I I I I I I I I I I " ..J _ _I_ I I I I I I I I I ì -I - -I- I I i _ ..J_ I I 'I I I I I I -r-I-T I I I I ì - I - -I- I !---I-T-ì- -1- -I-- I I I I I I I I I I I I _ 1__ _ L _ L _ 1- _ --1 _ -Ì _ _1_ _I_ I I I I I I I I I I I I I I I I - ¡- - T - ì - ì - -I - -1- - I I I I I I I I I I I I I I I I I I I I I I I I L_l_--1_.J _.1__1_ I I I I I I I I I I I I I I I I I I I 1 I I I I I I 1 I I I I I --i- -1- -¡-- T -I ì - -1- -¡- I I I I I I I I I I 1 I .. <iWj Ilia löUi . I I I I I , I I J ._...I _I ._1__ I I I I I I I I - ì - -1- " --1 _ -Ì _ _1_ I I I I -T - I - -1- I I I I _1- _I__ I I I I I I I I - I" -¡ I I -I ,~ I I I __ L _ l _ --1 I I L _ 1 _ --1 _ .J I I I I ~.I__í__I_ I \1 _.1_ _ i_ I _ .1 _ --1 o 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 60 62 64 66 68 70 Days Kokoda # 1 Info , . . 20cf ' 2- s;¡ Steve, received your telephone message. Think we are answering your questions- if not please advise! , ahD 'A.c..C/~£s ?d;'~ · Kokoda #1 surface coordinates in NAD 27 ASP5 are: X=606,278 & Y=5,954,597~v") ¡¿o£.da.. :5' þeA-t4~- ____ 0 J1> · The Pre-drill seismic pore pressure analysis dated 11/20/04 from Comisky indicates"no shallow hazards at the ~~. proposed surface locations". We do not anticipate any shallow gas. As alwaY~,-mitigation procedures for oS- Exploration wells will be in effect i.e. Mud Loggers form spud to TD, diverter drills, controlled drilling throughout the surface hole, 10 ppg from spud, and heightened crew awareness. Any questions, please advise. Tom 265-6377 275-7352 (pager) 1 of 1 1/4/20053:14 PM . MEMO 1:0:\ . .00 . a. a. ,. . 2.8a.7.Ei07Ei ]l;D 27 bll- .087 IllIE'ASAl - i ~ ¡¡¡ oj ~ ~ . 7U o CHASE SHARON K.ALLSUP-DRAKE CONOCOPHILLlPS ATO 1530 700 G ST. ANCHORAGE AK · 995d1 {Ð ¡;,ed~~rt"·Iu"5 ~llI8on8l.Ck 1087 . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME 'Z-Dcj -z~'1 koLccLs- PTD# Development Service /""" ,/ Exploration Stratigraphic CHECK WHAT ADD-ONS ·'CLUE"· APPLIES (OPTIONS) MULTI The permit is for a new wenbore 'segment of LATERAL existing well . Permit No, API No. . (If API number Production. sbould continue to be reponed as last two. (2) digits a function 'of tbe original API number. stated are between 60-69) above. Pll..OT BOLE ]n accordance witb· 20 AAC 25.005(1), aU (PH) records, data and logs acquired for the pilot bole must be clearly differentiated ID both name (name on permit plus PH) .' and API Dumber (SO - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved suhject ·to full EXCEPTION .' compliance witb 20 AAC 2S..05S~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spa dng ex ception. (Company Name) assumes the liability of any protest to the spacing .e:Jception tbat may occur. / DRY DITCH AU dry ditch sample sets submitted to tbe / SAMPLE Commission must be in no greater than 30' sample intervals from below tbe permafrost or from where samples are first caught and ] 0' sample iIiter:vaJs through target ZODes. D D Well bore seg Annular Disposal On Program EXP OnlOff Shore Unit Well Name: KOKODA 5 EXP I PEND GeoArea P_CAI, ~O%APC); .lower po_rtion _of i!1tßr:valin M 081737' (60% CI?AI.40% A~GL AA_Oß1 84P 160% IIIPRA well; _S_urfC!c_e_a!1d top productive produ_ctiv_eJntervaJ aod_1Q in aod_landpwoer (federaL Governmenti-. 1 will be 5 milesto 60%, APC 40%) 10.5 milesJo (GPAJ Exploratory wel 60th affe_ct_ed leases _have_ s_ame _OW!1ers the SSE the SSE. ~roposed K:okoda lIIearest exjstiog welUs CC!ribou 26-22 ~1 . Yes Yes Yes No_ Yes Y_es Yes Yes Yes Yes _Yes NA NA NA _NA NA NA Initial ClasslType INC Field & Pool b9uodary n_amß_a!1d oumb_er JQcatßd :.... ..... .Jo"nl~"" nnn' _ Jocatßd ¡ 'rom drj ling unit Jocatßd ¡ 'rom other welJs _S_ufficient acr i ' ....",," JfdeviC!ted, Permit fee C!ttached _LeC!sß number appropriate _U_nique welt ~.. ..._ \.t,,"",~..~¿_.... --f""~VI We Wel Wel [r. u, .,,,._.g unjt js weJlbore plat Operator only C!ffected party _Opßrator has_apprppriate_ bond inJorce. Permit co_nserva_tion order Pßrmit C!dmioistrati\(e_apprpvaJ Can permit be approved before 1 ~ ..on" ...n'. Well Jocated within C!rea C!ndstral ed by_l!1jectipo Order # (put 10# in cpmme!1tsi- (For AJI WßIJs_ wit!1in Jl4)"oile_area_of re ified (Fpr y' """"J ......~,dL servjcewell only) thC!n_ 3 montt)s (Forsßr:vice well onJy) duration_of prß-productioo less Pre-produced i!1jßctor 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 7 Administration ca!1 be issued without c_a!1 be issued wjthout Date Appr SFD 1/4/2005 da_ta indiçatess!JrfC!ce _casing_ this C!reC!.Offset wßI co_ntain_water with <10,000 ppm TDS._SFD Casiog depth similar: to other_ weJls in that an!1ulC!r _disposal my be proposed_. ,ð,nyhydrocarbons wi No rßserve_pjtplanoe_d, All waste to approve_da!1ouJus_or dispo»C!1 wells. Rig js e_quippedwith »teelpits. . 11I0 well» proxim_ate, Maximum formatipo prßssure t1.8_EMW jn8.5"-hoIß. MW plannßd up tpJ2.0ppg _ _l:Iigh estimated formC!tiO!1 pressure mC!y_b_e_aJith_ologicC!1 effect on_ seismic, _ M,ð,SI? calculale_dat 4986 psUn 8.5"-_h_ole. 5000 psi BQP testappropriate_and plaoned. however testing _maynotbe possjbJe. H2S Drjlljng works!1ould be_ completed, Without Yes Yes Yes No Yes Yes Yßs NA _NA Yes Yes Yes _Y_es Yes Yes No_ NA ACMP_ finding 9f Con_si»te!1cy_h_as been Jssued_ for tbis pr9ject CO!1ductor string_PJQVid!:!d might 11I0 know!1 USDWs, C!S proposed_ will protecta!1Y subcpßrmafrost »and be ÇQvered, & surfCJ>g known USQWs _CMT vol adeq uate_ to circulate_on _cooductor_ _S_urfC!ce _C<lsing_ p:rotects al CMT vol adßqu_ateJo tie-in Jong string to surf çsg_ CMTwill coverall koown-Pfo_ductive bori~Ol1s T" B& permafrost C, AdequateJC!nkageor re_serye pit Casi!1g desig!1s ade~ua_te for beeo approvßd Jfare-drilt bC!sa 10-403 for abandon_ment _Adequatewellbore separatio_nproposed t reguJa_tioos_ listadequate in _commeots) .Is prese!1ce_ of H2S gas_ probablß MechanicaLcoodjtio!1 of wells within ,ð,OR verified (For s_ervjce wßIJ only) Kdivßcter required, does _DriUiog ", .,..o ."nr"_1 n ~nh _BOPEs : BOPE¡test to_(puJ ChOke I ~ w/APt R~-53 (May 134) Work w peration _sbutdown meßt I,~", ..._...."'....ru .....,,,ematic_& eq_uip reguJaJioo psig raliog C!ppropriate; 8 9 20 ,21 b2 b3 24 25 26 27 28 29 30 31 Engineering Date 1/5/2005 Appr TEM 32 33 34 Rig IS equipped with _sensors _a!1d alarms. isu!1likely. penetraJi!1g the Lisburoe" Remote exploraJion wel See_ c_omm_e!1ts,_ b_elow, s_eismic_pore_pressure aoaJy_sis No_ Yes NA_ NA Yßs c_a!1 be issued w/o_ hydrogen_ s_ulfide meC!sures Pßrmit _D_ata_preseoted 011 pote_ntiC!1 overpressurß _Zone» 35 36 37 38 39 Geology filß, 1?1D 20~253P). _(i!1 Kokoda lIIon_e _anticipated per _Seismic_analysjs_ of shaJlow gas_zP!1es_ Date 1/4/2005 Appr SFD off-shore) (if Seabedcondjtipo survey Contact namelphoneJor Tom Brassfield 265-6377 Seismic pore pressure prediction indicates elevated pressure likely at base permafrost and again from 7100' to TD. Specifics are discussed in "Maximum Anticipated Surface Pressure and Casing Design" section. Well will be spud with 10 ppg mud, and mud weights up to 12 ppg will be used. Mitigation procedures will be in effect (mud logged from base conductor to TD, gas sensors, H2S sensors, diverter drills, controlled drilling throughout the surface hole, and heightened crew awareness - see T rassfield email dated 12/29/2004\. ffs- weels.ly progress_reports [exploratoryo!1ly] Date Engineering Commissioner: Date: 1/6/J Geologic Commissioner DlS . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation, 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. · · · AtJ0tl/ ~ r 2Ð4-z.-r;A Conoc¿¡;hillips Alaska, Inc. FINAL WELL REPORT MUDLOGGING DATA KOKODA #5 Provided by: ~ EPOCH Approved by: Andrew Buchanan Compiled by: Brian O'Fallon Fletcher England . John Morris Date: 04/10105 Distribution: ..../ ConocoPhillips Alaska, Inc. Kokoda #5 · TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW............. ......................... ...... ........................................................ 2 1.1 Equipment Summary ............ ............ .......... .............. ............................................................ ................. 2 1 .2 Crew............................................................ ............ ..... ........... ................................................ ................ 2 2 WELL DETAILS .......... .... .... ................... ............................. ..... ....................... ...... .... ..................................3 2.1 Well Summary............. ............................. ........ ........ ................................ ...... .... ............. ............. ............. 3 2.2 Hole Data..................................................................................... ........................................................... 3 3 GEOLOGICAL DATA. ........... ......... .......... ............................................. ..................... ...... .... ........... ............ 5 3.1 Lithostratigraphy.............................................................. ..... ............. ........................................... .......... 5 3.2 Mudlog Summary ............. ................... ............. ......u... ........................... ................... .............. ...........u... 6 3.3 Gas Samples.............................................................................................................. ............ .......... .... 12 3.4 Connection Gases...................................... .... ........ ........... ..................................................... ........... ... 14 3.5 Sampling Program I Sample Dispatch ................................................................... .............................15 4 PRESSURE / FORMATION STRENGTH DATA.....................................................................................16 4.1 Formation IntegrityJLeak Off Tests ................................... ........... .... ................... .................................16 4.2 Wireline Formation Tests ..................... ..... ................ ................. .............. ................... ................... ...... 16 4.3 Pore Pressure Evaluation Introduction ................................................................................................16 · 4.4 Pore Pressure Evaluation Conclusions ............................. .......... ...................... .......................................17 4.5 Pore pressure evaluation.......................... .... ............................................................... ........... ........ ..... 25 5 DRILLING DATA........................................... .... .......... .... .............. ............... ............ .............. ....... .... ........ 26 5.1 Survey Data........................................................ .................................................. ..................... ...........26 5.2 Bit Record ........ ...... ..... .................................. ............... ............... .................... ......... .... .............. ...... ...... 29 5.3 Mud Record.................................................................. ........... ...................... .......................................30 6 MORNING REPORTS .............................................................................................................................. 32 Enclosures 2"/100' Formation Log (MD) 2"/100' Formation Log (TVD) 2"/100' Drilling Dynamics Log 2"/100' Gas Ratio Log 2"/100' LWD / üthology Log 2"/100' Pore Pressure Log · ~ EPOCH 1 ../ ConocoPhillips Alaska, Inc. Kokoda #5 · 1 MUDLOGGING EQUIPMENT & CREW 1.1 Eauioment Summary · Parameter Equipment Type I Position Total Comments Downtime QGM Agitator (Mounted in possum Ditch gas belly) 0 Flame ionization total gas & chromatography. Effective Circulating Density From Sperry-Sun 0 (ECO) Hook Load / Weiaht on bit Hvdraulic pressure transducer 0 Mud Flow In Derived from StrokeslMinute and 0 Pump Output Mud Flow Out From Quadco 0 Mudlogging unit computer HP Compaq Pentium 4 (X2, DML & 0 system Rigwatch) Mudlogging unit DAC box In-unit data collection/distribution 0 center Pit Volumes, Pit Gain/Loss From Quadco 0 Pump Pressure From Quadco 0 Pump stroke counters Magnetic proximity sensor 0 Quadco Well Monitoring Quadco System in Mudlogging Unit 0 Components Primary draw-works block position Cable loose at Rate of penetration indicator, Optical encoder on 20 min. sensor, used drawworks TOTCO RPM From Quadco 0 Torque From Quadco 0 1.2 Crew Unit Type Unit Number Arctic Series 10 Skid ML012 Mudloggers Years D~ls Sample Years Days Technician Days *1 Catchers Brian O'Fallon 17 29 Randy Unger 5 7 None John Morris 31 18 Robert Haverfield 1 29 Fletcher Enaland 4 11 Todd Baham 1 22 James Finan 3mo. 0 Mike Menzel 1 mo. 0 *1 Years experience as Mudlogger "2 Days at wellsite between spud and total depth of well · ~ EPOCH 2 y/ ConocoPhillips Alaska, Inc. Kokoda #5 · 2 WELL DETAILS 2.1 Well Summary Well: Kokoda #5 API Index #: 50--279-20012-00 Lat: 70020'04.802"N Field: NPRA Surface Co-Ordinates: Long: 153°12'18.605W SEC 5 T11N R5W 2136' FSL 1709' FEL Borough: North Slope Primary Target Depth: 6675' State: Alaska TD Depth: 11122'MD 110139' TVD Rig Name I Type: Doyon #1411 Arctic Triple Suspension Date: Primary Target: Lower Cretaceous Torok License: (Brookian) Sands Spud Date: 3f712005 Ground Elevation: 134.4' pad, 131.6' ground Completion Date: Not completed RT Elevation: 162.4' Completion Status: Plugged and Abondoned Secondary Target N/A Depth: Classification: Exploration TD Date: 4/412005 TD Fonnation: Late Triassic Shublik Days Testing: 0 Days Drilling: 29 · 2.2 Hole Data Hole Maximum Depth TD Mud Dev. Casingl Shoe Depth FIT MD TVDSS Weight Coring MD TVDSS Section (ft) (ft) Fonnation (ppg) (oinc) Liner (ft) (ft) (ppg) Conductor 108' +54' Colville Gr NA NA 20" 108' +54' NA 16" 2615' -2453 Nanushuk 9.9 NA 13 3/8" 2609' -2447' 16.1 12 114" 8040' -7741 Miluveach 10.2 NA 9 5/8" 8031' -7734' 14.0 8112" 11122' -10138 Shublik 12.3 NA N/A N/A N/A N/A Additional Comments The Kokoda 5 was spudded on March 7, 2005, and plugged 47 days later on April 23. T oIal depIh was reached on April 4, at 11122'MD. The objective total depth ofthe Kokoda 5 was to be 300 feet below the top of the Ivishak Objective at an estimated 12245'MD. However, the well was plugged at 11122'MD, after attempts to run a 7" liner to bottom failed. The Kokoda 5 was spudded two days after moving from the Kokoda 1 pad. Conductor pipe, 20-inch, had been set at 108'. Three hole sections were drilled, a 16" surface hole to 2615', a first intermediate section, 12 %"to 8040', and a second intermediate section, 8 %"to 11122. A fourth hole was to be6118". The well was drilled vertically to 6500', directionally gradually to 40 degrees at approximately 8500', and a tangent maintained at 35- 40 degrees to total depth. Problems encountered included a weather delay while drilling surface, a lost circulation zone at 10968', and tight hole and sloughing $hale conditions building angle and in the tangent section. · ~ EPOCH 3 ",,/ ConocoPhillips Alaska,lnc. Kokoda #5 · A 16" surface hole was drilled to 261S' with 9.8 ppg 6% KCI spud mud, using a rotary assembly and requiring only one bit. Overall drilling was much slower than the surface hole of KoQda 1, which was a smaller 12 %" hole and drilled with a mud motor assembly. Drill rate, because of the high volume of cuttings from a 16" hole, was limited to 1 00-1 SO feet per hour to ensure sufficient hole cleaning. However, control drilling was often not necessary, as drilling proved more difficult than anticipated, averaging 47 feet per hour. Increasingly tight conditions from expansive clays were encountered, especially when backreaming connections. Surface hole needed 7 days to drill, including a three day phase 3 weather delay at 1061'. E-Iogs were not run, and despite some minor difficulty in cleaning the hole, and numerous tight spots in running casing, 13 %" casing was set successfully at 2609'. · Drilling commenced on the 12 %" hole on March 17, and, after a formation integrity test at 263S' of 16.1 ppg EMW, the intermediate section was completed after four BHA runs and three bits on March 26 at 8040'. The first bit (#2) was drilled to 37S6', averaging 90 feet an hour, and rerun after an MWD failure to 6384'. The rerun bit averaged only 54 feet per hour after slowing down at the end to 20-30 feet per hour, and was pulled after a failed sliding attempt. A mill tooth bit was used to drill to 7400', but continued drilling slow, averaging 26 feet per hour including sliding intervals while building angle. A PDC bit was used to complete the section, averaging 45 feet per hour. Intitially, the PDC did not drill any better than the mill tooth, but fast drilling, especially rotary drilling, in the HRZ and Miluveach shales is largely responsible for the improved ROP. Sliding overall became increasingly difficult while building angle, and attempted only briefly with the final PDC bit run, fatting a little short of the tangent angle that had been anticipated at casing depth. All four assemblies were similar, using a mud motor. Though slow, drilling was steady, with only minor tight hole problems whether it be drilling, backreaming after connections, tripping, or running 9 S/8" casing. Casing was set successfully at 8031'. Drilling commenced at 8040' with the 8 W hole section on March 28th, and completed to 11 ,122' on April 4 with one drilling assembly and one bit averaging 34 feet per hour. Drilling averaged 50-60 feet per hour initially and a wiper trip at 93S0' went well, but sloughing shale and tight hole conditions prevailed after 9500', making sliding to maintain angle extremely slow and tedious. A 12 stand wiper trip at 10417' pulled tight and required back reaming out, and some reaming back to bottom. Rotary drilling went well, though sporadically slow, until formation changed at 1096S' to an ashy sand. Circulation was lost at 10968', but recovered completely with slow pump rates after an LCM pill was dropped. Drilling was delayed a full day until a re-supply of mud arrived from Alpine. Drilling continued with LCM added to the mud and losses of 20-30 barrels per hour. Drilling averaged 5-10 feet an hour from 10965' to casing depth at 11,122, which included but one 5-foot slide. Tight hole and sloughing shale was extremely troublesome, and attempts to run or prepare to run the 7" linerto total depth failed after rigorous hole cleaning. The situation was further complicated by the well flowing or "breathing" during tripping, as the "charged" lost circulation zone retumed some of the mud lostwhiJedrilling or circulating. After reaching total depth and on numerous wiper trips, it was necessary to trip out backreaming and conditioning the hole, in part to replace potentially contaminated mud "breathing out" from the lost circulation zone. A first attempt to run a 7 inch liner, which had to be constantly rotated and worked down the hole, resulted in the liner being released at 8900' and sliding down to 9260'. Inspection of the running tool showed no damage to the tool, and a second running tool was run to the top of the liner. Further attempts to run the liner to bottom failed, and the liner was pulled out of the hole. While attempting to prepare the hole for a second liner run, a reaming assembly with a 9 3/8 inch reamer in the BHA was lost while backreaming out of the hole after reaming to bottom. The assembly was stuck and attempts to work the pipe free resulted in a pin being sheared off on the drill pipe 1222' above the bit. Attempts to recover the fish failed. The liner was run to 8430' on April 22, and with subsequent plugging procedures the well finished on April 23, 200S. · ~ EPOCH 4 'r/ ConocoPhillips Alaska, Inc. Kokoda #5 . 3 GEOLOGICAL DATA 3.1 Lithostratioraphy LWO tops refer to provisional picks provided by the Wellsite Geologist. . PROGNOSED LWD PICK FORMATION MD TVDSS MD TVDSS (ft) (ft) (ft) (ft) Base Permafrost 733' -575' 910' -748' Nanushuk 1288' -1130' 1390' -1228' Torok Formation 3368' -3210' 3254' -3092' Torok objective 6839' -6680' 6675' -6512' Top HRZ 7693' -7460' 7618' -7383' LCU 7976' -7680' 7889' -7614' UJU 8687' -8225' 8590' -8183' J2 10450' -9575' 10550' -9682' Shublik 11200' -10150' 11032' -10063' Ivishak 11905' -10960' Not Penetrated TO 12445' -10995' 11122' -10139' . [:I EPOCH 5 ..../ ConocoPhillips Alaska, Inc. Kokoda #5 · 3.2 Mudloa Summary Maximum 128 Maximum 24 Total Gas units Minimum o Avera e 6 Similar to the Kokoda 1, the Kokoda 5 drilled out of the conductor at 108' RKB into a massive moderately well sorted olive gray sand oUhe Colville Group, with grains dominantly quartz and silicates and sizes up to pebble, and with some interbedded poorly sorted conglomerates and claystone.. This upper sand was underlain by a clayey zone with interbedded coals, associated ash fall tuff, and some sand and siIIstone down to 300 feet. The rest of the permafrost included interbedded sand, clay, silt, and minor ash, with coarser conglomeratic sands to 400 feet and fine grained sands to the base of the permafrost. The sands were mostly medium gray with fewer silicates. Samples consisted of mostly unconsolidated grains and rare triable sands, dominantly quartz with minor silicates and an increase in lithics, mostly carbonaceous, grain and matrix supported, and occasional streaks of dense sandstone with slight calcareous cement. Claystones were mostly medium gray, some lighter or darker, with brownish hues do to some slightly organic clays, and slight carbonaceous matter in the form of silts, fines, clasts, and minor partings. Claystone was typically very soft, pasty, and massive, often variably sitty to sandy and grading to siltstone and sand, with some minor disseminated micas. Scattered shell fragments were observed. Gas increased overall gradually with depth from trace to 24 units, with some minor peaks of 4- 6 units in the coals, and only methane observed in the chromatograph. Base of Pennafrost to top Nanushuk · 910' to 1390' MD (-748' to -1228' TVDSS) Drill Rate (ftIhr) Total Gas (units Maximum Minimum AveraQe Maximum Minimum AveraQe 100 8.4 66.1 73 2 24 Continuing in the Colville Group, this brief section shows a decrease in overall sand. The section is predominantly claystone, variably silty to sandy, often grading to, or with thin beds and lamina of siltstone and fine grained sands, all of similar character and composition to the lower permafrost. Gas continued a gradual increase peaking at 73 units in sandy clays and sand above the Nanushuk, with the first observed traces of ethane. Nanushuk to top Torok 1390' to 3254' MD (-1228' to -3092' TVDSS) Drill Rate (ftIhr) Total Gas (units Maximum Minimum AveraQe Maximum Minimum AveraQe 206 2.5 79.0 1130 10 50 The Nanushuk included massive silty sands with interbedded claystone and siltstone from 1390' to 2830', and dominantly claystone with thin beds and laminations of siltstone to very fine and fine lower sand to 3254'. A gas peak of 1130 units at 1600' in sandy siltstone correlated with a 422 unit peak in heavier mud in the Kokoda 1, and had the same chromatograph signature of unusually high isobutane along with only methane, ethane, and minor propane. Gas generally ranged from 30-80 units with the exception of this peak, higher in sandy intervals with higher penetration rates, and dropping off to 30 units in claystone. lsobutane and propane fell off in low gas and dropped off completely after 2200'. Ethane diminished to sometimes trace amounts in low gas below 2500'. · Sands in the upper section were medium gray to medium light gray mostly with brownish hues, very fine to fine and sometimes medium, with various degrees of rounding, sorting, and consolidation, from angular to [:I EPOCH 6 Conoc;-Pt,illips Alaska,lnc. Kokoda #5 · subrounded, poorly to well sorted, and soft and matrix supported to fñable to occasionally well consolidated \Vith less matrix and slight calcareous cement. Constituents included dominantly quartz, and gray, black, green, amber, and reddish grains including lithics, carbonaceous in part, and some silicates including trace mica. Porosities were generally poor to possible fair in part, and no fluorescence or cuts. Claystone and siltstone were various shades of gray and brownish gray, and variably silty to very fine sandy, often slightly organic overall with slight to trace amoun1s of carbonaceous matter, including silts, fines, and minor flakes and partings. Claystone occasionally graded to carbonaceous shale or ash fall tuff, especially in the upper section. Silts were primarily quartz, the carbonaceous matter, and minor silicates, and of similar composition grading to very fine to fine lower sandstone. Other accessories included slightly scattered micro pyrite and micro flakes of mica, occasional pyrite clusters, and non to slightly calcareous. Torok to Torok objective 3254' to 6675' MD (-3092' to -6512' TVDSS) Drill Rate (ftIhr) Total Gas (units Maximum Minimum Average Maximum Minimum Avera!1e 226 6.5 65.1 78 6 32 The Torok can be divided into three sections, from 3254' to 3750', claystone with interbedded siltstone and sandstone, from 3750' to 5600', dominantly claystone with overall increasing shaliness \Vith depth, and 5600' to 6675', claystone often grading to shale and with interbedded siltstone and sandstone. Trace amounts of propane, butane, and pentane can be identified with the top of the Torok, gradually increase in the upper section, and are pervasive throughout. · The first section from 3245' to 3750', included mostly medium gray and some medium light and medium dark gray claystones and siltstones, some with brownish hues, and medium light to medium gray sandstone. The peak gas of 78 units occurred in a sand near the top of this section, which had measurable amounts of pentane, higher than butanes and propane. The sand was mostly very fine grained but with scattered fine to coarse lower grains, subangular, poorly to moderately sorted, mostly quartz with some lithics, mostly carbonaceous, and minor silicates, mostly friable and grain supported with clay and very slight calcareous matrix, and poor porosities. Sandy intervals throughout the rest of the section had very fine to fine lower grains and similar character and composition. Claystones were variably silty and sandy, non to slightly calcareous, with scattered silts and fines of organic and carbonaceous matter, and traces of mica and pyrite. Pentanes dropped off after the initial sand, and remained in trace amounts, less than butanes and propane, throughout the Torok. The second section from 3750' to 5600', included medium to medium dark gray claystones with variable brownish hues, and some darker claystone and generally darker shales deeper in the section. Claystone was varbiably silty some grading to siltstone with slight very fine grains. Other constituen1s included slightly to occasionally moderately organic/carbonaceous, with slight overall silts and fines and occasional partings of carbonaceous matter, traces to slight scattered micro pyrite to a faint sheen on some planar surfaces, traces to slight scattered micro flakes of mica, and generally non calcareous. The third section from 5600' to 6675' included claystone, siltstone, and shale similar to the second section, except locally ashy with lighter colors. Sandstones were light to medium light gray, very fine to fine grained, subangular to angular; moderately to well sorted, grain and matrix supported with ashy clay, and moderately well to poorly consolidated with slight to trace calcareous cement and very poor to poor porosities. Grain constituents included mainly quartz, some lithics including lightly upeppered- with carbonaceous grains, and minor silicates. · ~ EPOCH 7 y/ ConocoPhillips Alaska. Inc. Kokoda #5 Torok objective to top HRZ · 6675' to 7618' MD (-6512' to -7383' TVDSS) Drill Rate (ftIhr) Total Gas (units Maximum Minimum Average Maximum Minimum AveraQe 73 8.6 28.6 617 12 106 The Torok objective included the three oil bearing sandstone intervals observed in Kokoda 1, including sandstone intervals at the top and base, and a middle sandstone. The middle sandstone lies between two sections of interbedded siltstone, claystone, shale, sandstone, and ash fall tuff, with some thin oil bearing sands observed in the lower section. The three sandstone intervals are characterized by high show gas, up to 617 units, in massive sandstones with thin interbeds of claystone, ash, siltstone, and shale. The sandstones intervals are 6675'to 6770', peaking at 289 units, 7130'to 7235', peaking at 154 units, and 7470-7620', peaking at 617 units. Pentanes, occurring as trace amounts in the Torok shales, increased dramatically in the Torok: objective, and all the gases methane through pentane in descending order, were recorded throughout. Background gas, at 15 units above the objective, measured 12 to 60 units and averaged 20-~0 units in the interbedded zones from 6770' to 7130' and 7235' to 7470' between the sandstone intervals. Show gas in the lower zone included 115 units in a thin sand at 7276', and peaked at 180 units in an oil bearing sandstone at 7370' to 7395'. · All three sandstone bodies and the two smaller sands between the second and third intervals, were light to medium gray, with pervasive brownish hues, and of similar character and composition, except in the lower basal sandstone. The overall character of the sandstone was very fine to fine, subangularto subrounded, moderately to moderately well sorted, grain and some matrix supported with ashy to slightly argillaceous (carbonaceous/organic) clay, poorly to moderately well consolidated with a very slight to slight calcareous cement, and very poor to poor visible porosities. Grain sizes were overall notably slightly larger after 7520' in the basal sand sequence, mosUy friable sandstone with some better sorting and rounding, predominantly fine grains with fewer very fine, and mostly subrounded and moderately well sorted. Composition of the three sandstone bodies was dominantly clear to translucent quartz, 60% in the upper zone, to 70 and 75% in the middle and basal sands, respectively. other grain clasts included detritallithics, mostly carbonaceous, and some silicates. Oil fluorescence, which appeared to decrease overall with depth in the Kokoda 1, was a persistent dull to moderate 40-60% in the structurally higher Kokoda 5, with diffuse to slow blooming and trace slow streaming cuts. The two zones, 6770' to 7130' and 7235' to 7470', included interbedded medium to dark gray claystone, siltstone, and shale, with various brownish hues, light gray very fine to fine lower sandstone, and light gray ash fall tuff, often with brownish hues. The brownish color was due to various degrees of organic clay, and slightto some moderate silts, fines, flakes, and occasional partings of carbonaceous matter. Some shales graded to carbonaceous shale especially at the top of the second zone, beginning above a sand bed above the base of the second sandstone interval. Slight disseminated micro pyrite occurred throughout, except in sandstone. Top HRZ to lCU 7618' to 7889' MD (-7383' to -7614' TVDSS) Drill Rate (ftIhr) Total Gas (units Maximum Minimum Average Maximum Minimum AveraQe 140 10.1 71.4 441 145 269 The HRZ is dominated by dusky brown to dark brownish gray carbonaceous shale, with highly to some moderately organic clay, and common flakiness orfissility, especially in the upper shales, due to remnant carbonaceous matter and occasional bookleaf partings of carbonaceous matter. Micro pyrite occurs throughout, as lightly scattered, to a faint sheen on remnant carbonaceous partings. The shales are apparenOy a source rock with a pervasive diffuse oil cut, but it should be noted that the drilling mud was carrying 2% oil. Ash fall tuff is readily identified by a yellow gold mineral fluorescence in 5-10% of the sample in the upper HRZ diminishing to a trace at the base. The ash occurs as thins beds and lamina in the shale, sometimes grading to ashy organic claystone, and argillaceous very fine grained sandstone with diminishing mineral fluorescence and · weak oil fluorescence and cut. Gas remained high after the Torok objective decreasing only gradually through U EPOCH 8 .,.../ ConocoPhillips Alaska, Inc. Kokoda #5 . the HRZ, and continuing to carry all the gases, methane through pentane, in significant amounts in descending order. LCU to UJU 7889' to 8590' MD (-7614' to -8183' TVDSS) Drill Rate (ftIhr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 124 8.8 61.7 203 19 87 This zone includes the Miluveach Shales and the basal J4 Sandstone. Background gas before casing averaged approximately 180 units, and approximately 50 units after until the J4 Sandstone, carrying all the gases in descending order, methane through pentane. All samples had a weak cut, and the drilling mud continued to carry 2% oil. The Miluveach has dark organic rich shales, grayish brown to brownish black, firm with platiness aind common fissility, scattered micro fine pyrite throughout with an occasional sheen on bedding surfaces, and non to occasionally slightty calcareous. Shales grade to clay as they become more easily hydrated and are soft and amorphous in sample. Traces to slight amounts of very fine sand and silt from dissolved clay and shale cuttings or from thin stringers or laminations occur throughout the section. The J4 Sandstone is a 35 foot glauconitic sandy siltstone at the base, with silts and very fine to fine grains of mostty quartz. Gas peaked at only 125 units, there was no observed fluorescence, and cut was indistinguishable from other lithologies. UJU to J2 . 8590' to 10550' MD (-8183' to -9682' TVDSS) Drill Rate (ftIhr) Total Gas (units Maximum Minimum AveraQe Maximum Minimum AveraQe 162 6 52 476 40 120 After fining downward immediately below the J4, the Kingak, down to 10192', is dominated by moderately organic to organic shale with a persistent scattering of micro pyrite. Shales are dusky yellowish brown to brownish black to grayish brown to brownish gray, fairly to well indurated, generally exhibiting pastiness with incipient or dense fissility, to flakiness and fissility. Texture is often matte to resinous due to a spattering of micropyrite on carbonaceous residue. Some claystone, overall decreasing with depth, is generally soft to moderately soft as is mostly hydrated in sample. Traces of silt and very fine sand from hydrated claystone and shale, and lamina to thin beds of argillaceous siltstone and sandstone are common. Sandstone is often glauconitic. An overall increase in silt is seen between 9800' and 9900', possibly a poorly developed J3, but shale than continues to dominate down to 10192'. From 10192' to 10550' is dominantly interbedded variably argillaceous siltstone and shale with thin beds of very fine sandstone. Siltstone/Sandstone is medium dark gray to light gray, often with brownish hues,silttover¡fine and scattered fine grains, angular to subrounded, and poorly to moderately well sorted, generally better sorted and slightly argillaceous grading to sandstone, and poorly sorted grading to argillaceous siltstone. Grains are predominantty quartz, and slight carbonaceous silts and fines and minor other Iithics. Some cleaner sands were well consolidated with siliceous cement, but in general moderately to poorly consolidated with increasing argillaceous matrix, and overall visible porosities were very poor to poor. Traces of pyrite were observed in argillaceous siltstone. Shales were dusky yellowish brown, to medium to dark gray with brownish hues, mostly smooth to resinous to slightly silty texture, thinly bedded and grading to siltstone. Composition was slightty to moderately organic, occasionally slightly calcareous, and with the resinous texture due to slight micro pyrite and carbonaceous residue. Structure was firm, brittle and platy with distinct edges, to slightty firm and tabular with some fissility, to occasionally soft and hydrated grading to claystone. . Gas peaked at 476 units in pressured shales, and decreased in the silty section below 10192' probably due to ~ EPOCH 9 · · · ÌIo"'/ ConocoPhillips Alaska, Inc. Kokoda #5 the abrupt decrease in organic argillaceous matter. However, gas typically increased in siltstone and sandstone intervals relative to surrounding shales. A sandy zone had high gas of 361 units at 8673'. All gases, methane to pentane, continued in descending order, and samples continued to cut with 2% oil in the mud. There were no significant shows, however, through this section. J2 to Shublik 10550' to 11032' MD (-9682' to -10063' TVDSS) Drill Rate (Whr) Total Gas (units Maximum Minimum Average Maximum Minimum AveraQe 130 2.4 42 477 0 144 This section can be divided into three intervals, an interval of very fine grained sandstone and siltstone with thinly interbedded argillaceous siltstone and shale from 10550' to 10800', a fining downward section to mostly organic/carbonaceous shale to 10965', the top of a fine grained ashy sandstone bed which grades into the Shublik. Siltstone and sandstone in the J2 were light to dark gray with brownish hues, and similar to the overlying sands from 10192' to 10550', but with more abundant very fine grained sandstone, moderately to poorly consolidated, and often cleaner but with a slightly ashy argillaceous matrix, traces of calcite cement, and only slightly siliceous. A trace of cuttings were slightly glauconitic. Thin shale beds were also similarto those of the over1ying interval. Fining downward from 10,800, the dark organic/carbonaceous shale was non calcareous until after 10,920', and were then commonly slightly to moderately calcareous above the ashy sandstone. Circulation was lost at 10968', immediately after drilling into the ashy sandstone, and regained after pumping an lCM sweep. Drilling continued with losses of 20-30 barrels per hour down to casing point, with some minor flow from the ·charged sandstone- breathing between connections and occasionally while tripping. The character and composition of the sand was notably different than the J2. While 80% quartz, the remaining 20% was primarily gray to black silicates. Grains were fine to very fine and trace medium, with a predominance of lower fine, angular to subrounded, and recovered mostly as loose grains in samples. Abundant shavings of non calcareous white clay, presumably ash (possibly kaolic), some sandy in part to minor poorly consolidated clayey very fine grained sandstone, occurred with the sand. The ash was commonly faintly streaked with minor dark gray carbonaceous clay. The lost circulation indicates some porosity, but there was no oil fluorescence. Brown platy shale, distinctly different from the darker overlying shales, appeared to be interbedded with this upper sand and ash. Gas increased with the cleaner sands in the J2, and again at the top of the third interval in organic rich shales. The peak gas of 477 units appeared to be a silty to sandy interval in the shale below the J2. There was no oil fluorescence in the J2, but possibly some hydrocarbon potential in the cleaner sands. Gas decreased approaching the Shublik in part due to slower rates of penetration and decreasing pressure, and lithologic changes including the emergence of calcareous shales, ashy sandstone, and ash. Methane through pentane were measured throughout, and cuttings continued to cut with 2% oil in the drilling mud. Shublik 11032' to 11122' MD (-10063' to -10139' TVDSS) Drill Rate (Whr) Total Gas (units Maximum Minimum AveraQe Maximum Minimum AveraQe 29.9 5.2 13.9 222 123 173 Below the ashy sand and grading into the Shublik, the white ash was abruptly very calcareous, and logged as calcareous tuff, but could have been logged as marl, or more generally a limestone, with less deference to a [:I EPOCH 10 · · · conoc~illips Alaska, Inc. Kokoda #5 possible origin. The ash was commonly streaked with dark gray carbon¡¡lceous clay and with increasing organics logged as tuffaceous claystone, dark gray calcareous clays mostly streaked or laminated with white calcareous tuff. The calcareous clays and ash were interbedded with non calcareous organic shale. Gas varied slightly relative to lithology and rate of penetration, maintaining a 173 unit average, increasing in organic zones and decreasing in less argillaceous ashy zones. Methane through pentane, in decreasing abundance, were measured throughout, and no shows were recorded. A persistent cut from 2% oil in mud continued to total depth. ~ EPOCH 11 Conoc~Phillips Alaska, Inc. Kokoda #S · 3.3 Gas Samples 1 it 0 OSI% M th E - I t · un = . 0 e ane ~qUlva en Sample Depth Units C1 C2 C3 iC4 nC4 iCS nCS # (feet) 1 u=O.OS% (ppm) (ppm) (ppm) (ppm) (ppm) (ppm) (ppm) M.E. 1 500 3 686 2 1000 20 3844 3 1500 55 13833 42 4 1604 920 177158 43912 65 3618 5 2000 36 7515 44 6 2500 22 4171 9 7 3000 25 5753 6 8 3500 40 8810 39 8 3 4 3 2 9 4000 46 10826 87 26 6 7 2 2 10 4500 31 6649 61 17 4 2 0 0 11 4600 31 6800 49 14 4 3 1 1 12 4700 32 7632 53 14 4 4 1 1 13 4800 36 8928 61 20 5 6 2 1 14 4900 38 8844 69 23 7 4 1 0 15 5000 45 10728 89 29 9 6 2 1 16 5100 35 7312 74 25 7 4 2 1 17 5200 28 5432 58 25 9 5 1.5 1 18 5300 24 5450 65 24 4 2 1 0 19 5400 22 5219 74 31 15 11 7 6 20 5500 22 5007 81 33 11 7 2 1 21 5600 24 5346 88 33 14 11 5 0 22 5700 23 5217 88 33 12 8 2 0 23 5800 16 3045 65 25 8 6 2 1 24 5900 24 4421 99 32 10 6 3 1 25 6000 18 3538 97 34 11 7 3 1 26 6100 15 2557 78 25 8 5 2 1 27 6200 25 5099 180 60 14 10 5 1 28 6300 32 7291 313 109 21 16 5 1 29 6400 17 3945 146 65 16 10 1 0 30 6500 10 2331 126 63 11 11 5 0 31 6600 15 2743 174 91 10 17 5 2 32 6682 98 16607 1764 1378 184 340 74 69 33 6700 234 34154 4057 3473 516 939 195 188 34 6710 273 40128 4809 4152 597 1104 258 264 35 6720 236 35280 3979 3368 486 908 205 198 36 6730 176 24757 3230 3061 463 877 200 196 37 6740 150 19216 2785 2940 477 908 214 212 38 6750 180 23322 3213 3221 511 961 229 231 39 6760 85 12411 1866 2092 356 688 183 190 40 6800 39 3459 520 712 138 303 88 96 41 6900 29 3510 323 348 69 165 57 67 42 7000 15 1647 145 136 25 64 26 20 43 7100 17 2764 234 164 26 56 15 15 44 7132 78 13824 1222 821 166 237 41 37 · ~ EPOCH 12 . . . ConocóPhillips Alaska, Inc. Kokoda #5 Sample Depth Units C1 C2 C3 iC4 nC4 iC5 nC5 # (feet) 1 u=O.05% (ppm) (ppm) (ppm) (ppm) (ppm) (ppm) (ppm) M.E. 45 7171 121 20562 2125 1521 310 461 147 107 46 7180 59 7946 990 831 188 294 103 84 47 7200 47 5873 756 689 159 263 97 84 48 7300 42 5210 663 552 106 226 73 65 49 7372 102 19282 1692 1025 129 325 85 86 50 7400 47 6596 776 589 98 250 91 74 51 7470 100 18222 1935 1258 160 409 96 103 52 7500 230 40876 4899 2883 294 758 158 177 53 7528 492 126645 14223 7947 729 1890 323 382 54 7548 406 78431 10062 5955 592 1577 283 344 55 7573 509 125620 16686 9654 942 2379 395 484 56 7588 580 167803 21489 11504 1021 2687 461 600 57 7613 618 179374 22890 12278 1089 2939 495 645 58 7650 310 44374 7209 5367 582 1714 370 434 59 7700 362 68135 8892 5741 594 1881 361 484 60 7750 284 47924 5947 4341 502 1581 329 451 61 7800 229 30928 4470 3733 462 1473 316 430 62 7850 189 25024 3233 2900 387 1240 276 369 63 7900 164 20007 2864 2776 389 1201 293 405 64 8000 180 23467 3118 2870 422 1141 269 353 65 8100 33 3926 560 506 100 216 70 88 66 8209 53 6862 1050 960 176 316 50 84 67 8300 70 10349 1473 1170 202 341 65 82 68 8400 80 12745 1829 1327 220 374 100 109 69 8500 71 11654 1625 1102 174 311 77 78 70 8600 104 17512 2487 1548 225 409 98 94 71 8676 285 45307 6646 3917 517 954 236 224 72 8700 129 19483 3270 2259 339 634 154 157 73 8800 72 9447 1700 1344 226 454 134 152 74 8900 72 10182 1676 1172 195 402 126 127 75 8996 100 14550 2448 1485 225 453 139 136 76 9100 117 18282 3072 1735 258 520 156 151 77 9200 109 15456 2938 1738 263 534 178 184 78 9300 97 13522 2574 1445 220 445 144 134 79 9398 105 14202 2891 1616 254 507 245 267 80 9500 110u 15185 3000 1635 261 512 184 161 81 9600 68u 8281 1845 1102 198 388 201 203 82 9700 89u 11988 2553 1347 230 418 166 130 83 9800 69 8927 1889 1097 209 361 151 114 84 9930 104 14875 3076 1508 272 442 207 166 85 9954 206 34427 6275 2444 368 591 275 202 86 10036 470 113826 18733 5632 720 1063 432 305 87 10160 178 30463 4873 1976 335 530 263 199 88 10290 100 17071 2757 1253 243 370 240 203 89 10420 86 10777 2615 1582 310 469 203 123 90 10550 70 12013 1554 619 115 178 134 108 91 10680 119 27429 3152 1217 208 267 134 93 92 10810 144 33321 3870 1649 329 403 204 134 93 10940 253 64065 4939 1601 413 465 370 259 ~ EPOCH 13 .....,/ ConocoPhillips Alaska, Inc. Kokoda #5 · 3.4 Connection Gases 1 it 0 05% M th E - I t · un = . 0 e ane :qulva en Depth Units (feet) 8192' 4 8283' 3 8469' 4 8562' 4 8655' 4 8748' 2 8841' 5 8934' 2 9026' 3 9120' 4 9212' 3 9490' 4 9583' 4 9769' 5 9862' 15 9954' 10 1 0047' 35 10140' 75 10233 ' 400 10325' 440 10511 ' 100 10603' 200 10696' 180 10789' 183 10882' 188 10973' 30 11068' 210 · [:I EPOCH 14 ../ ConocoPhillips Alaska, Inc. Kokoda #5 . 3.5 Sampling Program I Sample Dispatch Set Type I Purpose Frequency Interval Dispatched to CPAI Unwashed Biostratigraphy 30' 108' -11122' MD ABV 100 A 619 East Ship Creek Ave Ste 102 Set owner: CPAI Anchorage, AK 99502 Attn: D. Przywojski CPAI Unwashed Biostratigraphy 30' 108' -11122' MD ABV 100 B Set owner: Pioneer 619 East Ship Creek Ave Ste 102 Resources Anchorage, AK 99502 Attn: D. Przywojski CPAI Unwashed Biostratigraphy 30' 108' -11122' MD ABV 100 C 619 East Ship Creek Ave Ste 102 Set owner: Anadarko Anchorage, AK 99502 Attn: D. Przywoiski CPAI Washed, screened & dried 30' 108' -11122' MD ABV 100 D Reference Samples 619 East Ship Creek Ave Ste 102 Set owner: CPAI Anchorage, AK 99502 Attn: D. Przywojski CPAI Washed, screened & dried 30' 108' -11122' MD ABV 100 E Reference Samples 619 East Ship Creek Ave Ste 102 Set owner: CPAI Anchorage, AK 99502 Attn: D. Przywojski Washed, screened & dried CPAI Reference Samples 30' 108' -11122' MD ABV 100 F 619 East Ship Creek Ave Ste 102 Set owner: Pioneer Anchorage, AK 99502 Resources Attn: D. Przvwoiski CPAI Washed, screened & dried 30' 108' -11122' MD ABV 100 G Reference Samples 619 East Ship Creek Ave Ste 102 Set owner: AOGCC Anchorage, AK 99502 Attn: D. Przvwoiski CPAI Washed, screened & dried 30' 108' -11122' MD ABV 100 H Reference Samples 619 East Ship Creek Ave Ste 102 Set owner: BLM Anchorage, AK 99502 Attn: D. Przywojski CPAI Washed, screened & dried 30' 108' -11122' MD ABV 100 I Reference Samples 619 East Ship Creek Ave Ste 102 Set owner: Anadarko Anchorage, AK 99502 Attn: D. Przvwoiski Cali-Bond Gas bags Routine intervals and 500' 500' - 4500' MD lsotech Laboratories, Inc. J significant peaks above 100' 4500' - 11070' MD 1308 Parkland Court background Champaign, IL 61821 Set owner: CPAI K Onsite Samplex Samples 30' 108' -11122' MD To on-site geologist . . Sample frequency was locally altered according to drill rate constraints and zones of interest. ~ EPOCH 15 Conoc;Phillips Alaska, Inc. Kokoda #5 · 4 PRESSURE I FORMATION STRENGTH DATA 4.1 Fonnation Intearity/Leak Off Tests FORMATION Nanushuk Miluveach 4.2 Wireline Fonnation Tests No Data. 4.3 Pore Pressure Evaluation Introduction Trend Indicators The following pore pressure parameters are considered to provide relìable ìndìcators for pore pressure trends during the drilling of a well; · Background Gas (BG) Resistivity (RES) Hole Conditions (HC) Wiper Gas (WG) Trip Gas (TG) Mud Weight (MW) Connection Gas (CG) Pore Pressure (PP) D exponent (DX) Corrected D exponent (DXC) Equìvalent Cìrculøting Density (ECD) Quantitative Methods The primary indicators used for pore pressure evaluation were gas trends relative to MW and ECD, including increases in BG, appearance and trends of CG, and magnitudes of TG and WG. Regional pore pressure trends provided by ConocoPhillips, and surface manifestations of hole conditions were also considered. As a reference, PP is calculated intitially with a formula provided by Epoch, and than modified using the indicators described above, and DXC and RES data. The formula uses DX, ECD, and BG: PP = ECD - (1-«.001*BG)+(O.052*DX») The formula has limitations such as it doesn't allow for a PP more than 1 ppg less than ECD, BG must be differentiated from show gas and gas carried from over pressure zones, and is dependent on reliable DX data. However, the formula proved useful in helping establish a PP range, when establishing trends, as with DXC data, with data points in shale intervals. The DXC and RES data, as in the Kokoda 1, did not establish reliable trends, at least for quantitative analysis, but overall did help to support qualitative analysis of gas trends. However, the variable nature of the shales, including variably silty, sandy, organic, shaley (mostly claystone), and sometimes calcareous, and factors such as controlled drill rates, PDC bits, and a deviated hole and sliding intervals especially below intermediate casing, all contributed to the absence of reliable quantitative evaluation of DXC and RES, and affected gas trends as well. · DXC and RES data were plotted versus depth for each hole section. Trend lines were established through [1 EPOCH 16 y ConocoPhillips Alaska, Inc. Kokoda #5 · shale and claystone intervals, although data for sandy (including show) intervals was also plotted. RES and ECO data were provided by Sperry Sun (MWO). Pore Pressure is evaluated below for each hole section. 4.4 Pore Pressure Evaluation Conclusions 1) Suñace Hole - 16" (108' to 2615') The OXC data for the 16" hole, drilled vertically with a rock bit with a MW of 9.3-9.9 ppg, is reasonably consistent with gas trends to suggest only slight deviations in pore pressure estimated to vary from 8.7 to 9.2 ppg. The ECO average was around 10.2 ppg for the large surface hole, and there was no measurable CG. WG at 1061' was only 22 units, and after pulling out of the hole and waiting on weather for two days after the wiper trip, only 6 units of TG. WG at 2615' before running casing was 110 units. Gas peaked at 1130 units at 1600', but measured only 20 to 40 units through clay zones below the permafrost to casing depth. RES points are widely scattered in the permafrost and overall not very reliable with the large hole, but below the permafrost, however, does appear to support the OXC and gas trends with a trend line established through clay zones. · Both BG and OXC indicate a slight pressure transition from 1350' to 1600', and low WG and TG at 1061' with low BG to 1350' suggest a normal pressure gradient of 8.7 to 8.8 ppg before the transition. At casing depth, the 110 units of WG occurred after reaming to bottom, and was grem:er than the peak gas while circulating after tripping in through the high gas zone at 1600 feet and working the pipe and reaming between 1670-1700', only 42 units. For this reason, low BG through clay zones, the lack of CG, and OXC trends, pore pressure is only estimated to peak at 9.2 ppg at 1600' and to vary slightly before returning to a normal pressure gradient of 8.8 ppg at casing depth. 2) 12.25" hole (2615' to 8040') Pore pressure is estimated to vary from 8.7 ppg to 9.9 ppg, maintaining a normal 8.7 to 8.8 gradient 2615' to 6670' in Torok Shale, increasing gradually to 9.7 in the objective sands to the top of the HRZ at 7600', and increasing slightly to 9.9 ppg in shales to casing depth. Mud weight wa~ maintained at 9.6-9.7 ppg in the lower Nanushuk and Torok shales, increased just above the Torok objective to 9.8 and gradually increased to 10.1+ at total depth. ECO's in the 12.25" hole averaged 10.0 ppg in the Torok, varying between 9.8 and 10.2, and increased from 9.8 to 10.4+ through the objective sands down to casing depth, overall increasing relative to MW. Gas data is the most reliable for estimating pore pressure trends through this hole section, supported by OXC and to some lesser degree by RES. OXC and RES, while supporting pore pressure trends, are not quantitative. The shift from 6384' to 7400' is a separate bit run. OXC data before the shift substantially supports a normal pressure gradient for the Torok Shale, and after 7400' indicates, though not quantitatively, some pore pressure increase. The upward OXC trend from 6384' to 7400' through much of the Torok objective, is probably due to gradual bit wear and lithology variations, and does not reflect the increasing pressure. The slight downward slope on the RES through the Torok Shale probably supports a normal gradient as the slope is constant, but lithology variations and the presence of hydrocarbons obscure trends in the objective, and the low resistivities in the HRZ and LCU might indicate pressure changes in part, but are primarily the result of lithologic changes, in particular the organic nature of the shales. · BG gas and a lack of CG, as with the OXC, support a normal pressure gradient of 8.7-8.8 ppg, well below ~ EPOCH 17 · · · .../ ConocoPhillips Alaska. Inc. Kokoda #5 the ECO and MW measured in the Torok Shale. BG through claystones varied from 14 to 40 units. Gradual pore pressure increases, from 8.8 to 9.9 ppg, from the top of the Torok objective to casing depth in the lCU, is supported by gas data, especially CG and WG. CG was first encountered at 6812' after drilling the first Torok objective Sand, and was observed after each connection to casing point. Connection gas was consistenUy 5 units with a 9.8 ppg MW until the second objective. Connection gas varied from 10-70 units, beginning in the second objective sand to total depth, with MW from 10 to 10.1 + ppg. The highest CG occurred at 7556' in the basal sand above the HRZ, due to an estimated 9.7 ppg and after high show gas in an oil zone. TG measured only 375 units with a 10.0 MW at 7400' after a bit run while drilling the Torok objective, while WG of 545 units with a 10.1 + was measured off bottom in the lCU before the casing run. This relatively high WG and a slight increase in CG from the HRZ to the lCU, support the estimated peak in pore pressure of 9.9 ppg at casing depth. 3) 8 %" hole (8040' to 11,122') A gradual pore pressure increase persisted in the lCU and UJU, accelerated in a sandy interval above the J2, and peaked at an estimated 11.8 ppg at the top of J2 sand. Drilling began with a significantly overbalanced MW of 11.3 in anticipation of increasing pressure. MW was raised gradually to an 11.8 ppg, increased to 12.0 ppg after significant CG above the J2 sand, and maintained to a 12.1 to 12.2 approaching casing point. ECO varied relative to MW, from 12.0 to 12.9. Circulation was lost at 10968' in ashy sand with a 12.8 ECO, but recovered with slow pump rates and lCM in a 12.0 mud. Minor losses of 20-30 barrels per hour continued while drilling with lCM enriched mud and normal pump rates. CG was the best indicator of pore pressure, and CG, RES, and DXC indicate a peak pore pressure in a silty zone at approximately 10,250'. CG peaked at 400 and 440 units over BG at 10,233' and 10,325', respectively, while drilling with an 11.8 ppg MW and 12.7 ppg ECD. RES and DXC data bottomed well below trend lines at approximately 10,140', in the shale above this silty zone. OXC data appears quite random due to numerous slides throughout the 8 ~ hole section, but OXC data rotating through shale or claystone falls below the trendline on the chart, and appear to be consistent with pressure trends. The RES trend line is established through shaly zones. RES data in sandy, silty, and calcareous zones were above the trend line. It is difficult to estimate pore pressure below the J2 sand. While lost circulation, DXC, and RES indicate a substantial pore pressure drop significantly below the approximate 12.8 ECP measured while drilling, high CG and BG and the lost circulation zone "breathing" with the pumps off indicate pressures remain relatively close to the J2. However, on wiper trips after total depth while reaming to bottom, gas was highest with approximately a 0.5 ppg mud cut while reaming near the top of the J2 sand, concluding that pressure was highest at this point. Pore pressure is estimated to have dropped slightly to 11.5 ppg in the lost circulation zone and 11.6 ppg at total depth. [;I EPOCH 18 1.5 0.5 DXC vs - 16" . 500 1000 1500 DEPTH o o 2000 2 . . 2500 3000 19 100 . . Kokoda #5 vs - 16" . .. .. . . . . . . o 500 1000 1500 DEPTH . . . 2000 2500 3000 20 2 - 1.5 0.5 o 2000 Kokoda #5 DXC VB DEPTH - 12.26" . 3000 5000 DEPTH 7000 6000 4000 8000 21 Kokoda #6 vs 100 . . 10 1 2000 3000 4000 5000 DEPTH 6000 7000 8000 22 VB - 8.5" .. 8500 9000 9500 10000 10500 DEPTH 11000 11500 23 Kokoda #5 vs 100 ; . t . 10 . 1 8000 8500 9000 9500 10000 10500 11000 DEPTH 11 500 24 . conoCailliPS Alaska, Inc. Kokoda #5 . 4.5 Pore pressure evaluation Formation Primary Secondary Interval Tops Pore Pressure (EMW) Trend Source of Interval Lithology Lithology MD rvDSS Min Max Trend Indicators Quantitative (%) (%) (ft) (ft) (ppg) (ppg) Estimate Permafrost Sd 50% Clyst 30% 108 +54 8.7 8.8 Flat BG RES,DXC Base Permafrost Clyst 70% Sltst/Sd 25% 910 -748 8.8 8.9 Flat BG,WG,TG RES,DXC Nanushuk Clyst 40% Sst/Sd 30% 1390 -1228 8.8 9.2 SIi Up-Dn BG,WG RES,DXC Torok Formation Clyst/Sh 70% Sltst 20% 3254 -3092 8.7 8.8 Flat BG,WG,TG RES,DXC Torok objective Sst 50% Sltst 25% 6675 -6512 8.9 9.7 Up BG,CG,TG RES,DXC HRZ Sh/Clvst 90% Ash 5% 7618 -7383 9.7 9.7 Flat BG,CG RES,DXC LCU Sh/Clyst 90% Sst/Ash 10% 7889 -7614 9.8 10.4 Up BG,CG,WG,TG RES,DXC UJU Sh/Clyst 70% Sltst 20% 8590' -8183 10.4 11.8 Up BG,CG,WG RES,DXC J2 Sltst/Sst 80% Sh 20% 10550' -9682 11.5 11.8 Sli Dn BG,CG,WG RES,DXC Shublik Ash 40% Clvst 40% 11032' -1 0063 11.5 11.6 Flat BG,CG,WG RES,DXC Total Depth 11122' -10139 11.6 11.6 NOTE: Clyst = Claystone/Clay, Sd = Sand, Sltst = Siltstone, Sh = Shale, Sst = Sandstone, Ash = Ash Fall Tuff [:I EPOCH 25 ConocJ'Phillips Alaska. Inc. Kokoda #5 · 5 DRILLING DATA · · 5.1 Survey Data Measured True Vertical Dogleg Incl. Azim. Vertical Northings Eastings Depth (0) (0) Depth (ft) (ft) Section Rate (ft) (ft) (ft) (°/1 DOff) 107.00 0.00 0.00 107.00 0.00 0.00 0.00 0.00 205.91 0.14 161.68 205.91 -0.11 0.04 -0.11 0.14 297.77 0.00 247.75 297.77 -0.22 0.07 -0.20 0.15 385.76 0.31 133.16 385.76 -0.38 0.25 -0.34 0.36 479.23 0.38 186.44 479.23 -0.86 0.40 -0.78 0.34 569.56 0.22 227.13 569.56 -1 .28 0.24 -1 .22 0.28 659.63 0.36 263.67 659.63 -1 .43 -0.17 -1.44 0.25 750.31 0.12 267.15 750.30 -1 .46 -0.55 -1.54 0.26 840.81 0.25 301.87 840.80 -1.36 -0.82 -1 .48 0.19 931.51 0.06 341 .26 931.50 -1.21 -1.01 -1.36 0.23 1023.61 0.22 339.56 1023.60 -1.00 -1.08 -1.16 0.17 1116.58 0.31 204.23 1116.57 -1.06 -1 .25 -1 .25 0.54 1201.99 0.53 201.45 1201.98 -1.64 -1 .49 -1.87 0.25 1303.26 0.44 228.69 1303.25 -2.33 -1.95 -2.62 0.24 1396.03 0.48 226.10 1396.01 -2.83 -2.50 -3.21 0.05 1488.71 0.57 235.50 1488.69 -3.36 -3.16 -3.85 0.13 1581.75 0.48 267.60 1581.73 -3.64 -3.93 -4.25 0.33 1674.18 0.74 264.62 1674.15 -3.71 -4.92 -4.49 0.28 1766.29 0.68 267.82 1766.25 -3.79 -6.06 -4.76 0.08 1857.47 0.53 278.25 1857.43 -3.75 -7.01 -4.88 0.20 1951.31 0.25 220.73 1951.27 -3.85 -7.58 -5.07 0.48 2046.84 0.44 257.08 2046.80 -4.09 -8.07 -5.39 0.29 2136.23 0.36 261.54 2136.18 -4.20 -8.68 -5.61 0.09 2232.77 0.44 267.94 2232.72 -4.26 -9.35 -5.78 0.09 2324.93 0.48 284.44 2324.88 -4.18 -10.07 -5.81 0.15 2415.55 0.36 292.72 2415.50 -3.97 -10.71 -5.72 0.15 2509.22 0.25 320.26 2509.16 -3.70 -11.11 -5.52 0.19 2576.21 0.20 327.75 2576.15 -3.50 -11.26 -5.34 0.09 2664.50 0.19 3.59 2664.44 -3.23 -11.33 -5.09 0.13 2757.69 0.17 359.29 2757.63 -2.93 -11 .32 -4.80 0.02 2850.85 0.14 18.03 2850.79 -2.69 -11 .29 -4.55 0.07 2941.34 0.12 29.84 2941 .28 -2.50 -11.21 -4.35 0.03 3035.44 0.12 4.34 3035.38 -2.31 -11.15 -4.15 0.06 3129.42 0.09 339.55 3129.36 -2.14 -11.17 -3.99 0.06 3219.32 0.14 281.87 3219.26 -2.05 -11 .30 -3.93 0.13 3307.06 0.28 234.38 3307.00 -2.16 -11.57 -4.07 0.24 3404.57 0.33 228.81 3404.51 -2.48 -11.98 -4.46 0.06 3495.94 0.43 218.34 3495.88 -2.92 -12.39 -4.97 0.13 [:I EPOCH 26 · · · -.-/ ConocoPhillips Alaska. Inc. Kokoda #5 Measured True Vertical Dogleg Incl. Azim. Vertical Northings Eastings Depth (0) (0) Depth (ft) (ft) Section Rate (ft) (ft) (ft) (0/10Oft) 3586.84 0.47 219.69 3586.78 -3.48 -12.84 -5.59 0.04 3683.21 0.53 225.35 3683.14 -4.10 -13.41 -6.29 0.08 3775.07 0.44 220.57 3775.00 -4.66 -13.94 -6.94 0.11 3858.81 0.31 229.34 3858.74 -5.05 -14.32 -7.39 0.17 3961.20 0.45 260.58 3961.12 -5.29 -14.92 -7.73 0.24 4053.74 0.58 281.78 4053.66 -5.26 -15.74 -7.83 0.25 4147.14 0.64 282.59 4147.06 -5.05 -16.71 -7.79 0.06 4239.50 0.67 297.46 4239.41 -4.69 -17.69 -7.60 0.19 4332.88 0.36 294.03 4332.79 -4.32 -18.44 -7.36 0.33 4427.00 0.56 300.24 4426.90 -3.97 -19.11 -7.13 0.21 4518.90 0.40 329.28 4518.80 -3.47 -19.65 -6.73 0.31 4611.20 0.61 323.76 4611.10 -2.80 -20.10 -6.15 0.24 4703.33 0.66 325.42 4703.22 -1.97 -20.69 -5.43 0.06 4797.11 0.88 347.68 4796.99 -0.83 -21.15 -4.37 0.40 4890.21 0.76 348.81 4890.08 0.48 -21.42 -3.13 0.13 4983.09 0.83 331.85 4982.95 1.68 -21.86 -2.02 0.26 5075.50 0.57 59.18 5075.36 2.51 -21.78 -1.19 1.06 5168.90 0.56 52.46 5168.75 3.02 -21.03 -0.56 0.07 5262.12 0.74 71.00 5261.97 3.50 -20.09 0.06 0.30 5353.33 0.75 75.60 5353.17 3.84 -18.96 0.59 0.07 5447.33 0.66 74.84 5447.16 4.13 -17.85 1.07 0.09 5537.97 0.50 95.58 5537.80 4.23 -16.96 1.31 0.29 5631.46 0.63 80.56 5631 .28 4.27 -16.04 1.51 0.22 5725.07 0.44 101 .24 5724.89 4.29 -15.18 1.67 0.29 5818.04 0.59 103.98 5817.86 4.10 -14.37 1.63 0.16 5910.47 0.59 115.72 5910.28 3.79 -13.49 1.46 0.13 6003.68 0.37 115.44 6003.49 3.45 -12.79 1.25 0.23 6093.00 0.72 120.88 6092.80 3.04 -12.04 0.97 0.40 6189.56 0.83 116.08 6189.36 2.42 -10.90 0.55 0.13 6282.99 0.81 151.25 6282.78 1.54 -9.97 -0.16 0.53 6369.93 0.72 140.34 6369.71 0.58 -9.32 -1.00 0.20 6461.71 0.36 355.93 6461.49 0.42 -8.98 -1.10 1.13 6554.22 3.53 338.51 6553.93 3.36 -10.04 1.62 3.45 6647.26 6.13 340.17 6646.63 10.70 -12.78 8.40 2.80 6734.53 9.65 346.74 6733.06 22.21 -16.04 19.20 4.16 6832.68 12.47 351 .28 6829.38 40.70 -19.53 36.83 3.00 6925.71 15.53 359.65 6919.65 63.09 -21.13 58.63 3.94 7017.42 17.18 6.09 7007.65 88.84 -19.77 84.25 2.67 7110.87 20.91 10.72 7095.98 118.96 -15.20 114.71 4.30 7203.83 25.41 12.18 7181.42 154.78 -7.90 151.24 4.88 7296.40 27.35 13.77 7264.35 194.85 1.35 192.29 2.23 ~ EPOCH 27 · · · Conoc;p"illips Alaska. Inc. Kokoda #5 Measured True Vertical Dogleg Incl. Azim. Vertical Northings Eastings Depth (0) (0) Depth (ft) (ft) Section Rate (ft) (ft) (ft) (°/1000) 7390.66 27.93 14.34 7347.85 237.27 11.97 235.90 0.67 7483.05 29.46 14.75 7428.89 280.21 23.11 280.10 1.68 7575.33 30.63 14.99 7508.77 324.86 34.98 326.12 1.27 7662.36 31.28 15.30 7583.40 368.08 46.68 370.68 0.76 7761.65 31.60 15.54 7668.11 418.00 60.44 422.21 0.34 7854.77 31.93 15.74 7747.29 465.21 73.66 470.97 0.37 7947.27 32.47 13.87 7825.56 512.86 86.25 520.06 1.22 8122.47 34.08 13.73 7972.04 606.20 109.17 615.93 0.92 8209.75 35.36 14.84 8043.78 654.37 121.45 665.47 1.64 8306.17 36.39 15.09 8121.90 708.95 136.04 721.73 1.08 8400.40 37.01 14.16 8197.46 763.44 150.26 777.84 0.89 8493.22 38.96 12.44 8270.61 819.03 163.38 834.85 2.39 8585.55 40.18 9.54 8341.79 876.76 174.57 893.64 2.40 8678.76 39.62 9.27 8413.29 935.75 184.35 953.43 0.63 8772.87 39.84 9.23 8485.67 995.11 194.02 1013.57 0.23 8860.48 39.65 10.47 8553.04 1050.30 203.60 1069.58 0.93 8958.61 39.64 9.50 8628.60 1111.96 214.46 1132.19 0.63 9050.85 41.33 8.32 8698.75 1171.12 223.72 1192.07 2.01 9143.01 40.29 10.04 8768.51 1230.58 233.32 1252.29 1.66 9235.25 40.05 8.51 8838.99 1289.30 242.91 1311 .79 1.10 9328.27 41.68 7.43 8909.33 1349.58 251.35 1372.63 1.91 9421.60 40.61 7.02 8979.61 1410.50 259.07 1433.98 1.19 9514.22 39.58 6.77 9050.46 1469.72 266.23 1493.56 1.13 9607.02 38.79 8.08 9122.39 1527.86 273.80 1552.14 1.23 9699.72 38.96 7.66 9194.56 1585.49 281.77 1610.29 0.33 9792.15 39.14 6.97 9266.34 1643.25 289.18 1668.48 0.52 9885.15 38.89 7.05 9338.60 1701.36 296.32 1726.96 0.28 9977.87 39.60 8.04 9410.41 1759.50 304.03 1785.57 1.02 10070.73 40.93 7.42 9481 .27 1818.97 312.09 1845.55 1.49 10163.72 41.83 8.65 9551.04 1879.83 320.69 1906.99 1.31 10253.23 41.60 7.12 9617.86 1938.83 328.86 1966.52 1.17 10348.47 40.83 8.26 9689.5 2001.01 337.25 2029.23 1.13 10436.10 40.32 8.11 9756.06 2057.43 345.36 2086.21 0.6 10534.07 39.35 7.35 9831 .29 2119.62 353.81 2148.93 1.1 10626.82 38.4 6.42 9903.5 2177.41 360.79 2207.07 1.21 10718.28 38.3 8.35 9975.24 2233.67 368.08 2263.76 1.31 10812.47 36.95 7.42 10049.84 2290.62 375.97 2321.23 1.55 10904.08 35.78 7.67 10123.6 2344.47 383.1 2375.51 1.29 10997.28 36.03 4.65 10199.1 2398.8 388.96 2430.05 1.92 11052.91 35.05 5.45 10244.36 2431.02 391.81 2462.28 1.95 11122.00 35.05 5.45 10301.36 2470.75 395.58 2502.01 0.00 [:I EPOCH 28 . conoCailliPS Alaska, Inc. Kokoda #5 . 5.2 Bit Record Depth In Total Bit Avg. WOB PP Bit Make Type Jets I TFA MD I TVDSS Footage Hrs ROP (Klbs) RPM (psi) Wear BHA (ft) (ftlhr) 16" Hole 1 Hughes T11C 1x12,3x20 108' / +54' 2399' 50.9 47.1 15.8 136 1993 2-2-WT -A-E-IN-NO- TD 11.031 " 121/4" Hole 2 SDBS FS2663 8x13/ 2615'1-2453' 1140' 12.7 89.8 8.7 93 1845 1-1-WT -G-X-1 /16" -NO- 1.037" DTF 2RR1 SDBS FS2663 8x13 3756'/-3594' 2628' 49.1 53.5 11.2 98 2260 Not graded /1 .037" 3 Hughes MXC1 3x18,1X12/ 6384'/-6221' 1016' 39.6 25.7 43.1 58 2815 2-2-WT -A-E-IN-NO-HRS 0.856" 4 Hughes HCR605 7x13/ 7400'1-7194' 640' 14.1 45.4 10.0 79 2879 1-1-CT -G-0-1 /16" -NO- TD 0.907" 8 Yz" Hole 5 Hughes HCR605 5x15 8040'1-7741' 3082' 90.7 34.0 20.2 64 3214 3-3-WT -A-D-IN-CT - TD /0.863" [:I El">OCH 29 . conoCailliPS Alaska, Inc. Kokoda #5 . 5.3 Mud Record Contractor: MI MdT 6% KCI S d / KCI P I u Iype: 0 pu olymer Date Depth MW ECD VIS PV yp Gels FL FC Sols OIW Sd pH CI Ca (ppg) (ppg) (s/qt) (cc) (%) Ratio (%) (mill) (mill) 16" section 3/7/05 119 9.8 10.15 120 27 53 18/23/25 6 1/ 7.5 /93 0.5 9.8 33000 400 3/8/05 1061 9.8 10.28 110 23 48 18/23/27 4.8 11 9 /91 1.5 9.0 33000 300 3/9/05 1061 9.8 10.28 112 26 52 17/22/25 3.8 1/ 8.5 191.5 1 9.5 34000 300 3/10/05 1061 9.8 10.28 105 25 51 17/20/24 5.1 11 8 /92 0.5 8.9 34500 300 3/11/05 1280 9.8 10.20 125 28 52 17/22/24 4.5 1/ 8 192 1 9.0 31000 280 3/12/05 2170 9.8 10.22 106 29 55 19/29/37 3.8 1/ 7.5 1/92 1.25 9.5 33500 160 3/13105 2615 9.8 10.20 101 26 56 20/33/42 4.5 1/ 8 /92 0.75 9.7 32000 180 3/14/05 2615 9.8 10.20 83 25 51 20/28/35 4.5 1/ 8 192 1 9.2 29500 240 3/15/05 2615 9.7 10.20 47 14 22 8/13/15 4.6 1/ 7.5 1/92 7.3 31000 40 12 %" section 3/16/05 2615 9.6 10.20 50 14 23 9/12/15 5.6 1/ 7 1/93 0.1 9.2 32500 400 3/17/05 3680 9.6 10.13 50 16 26 13/21/27 4.8 1/ 8.5 1/91 0.3 9.5 31500 550 3/18105 4290 9.6 10.13 51 18 32 13/23/28 5.8 11 8 2/91 0.2 9.7 29000 600 3/19/05 5244 9.7 9.90 45 12 26 10/17/26 7.6 1/ 7 2/91 0.2 9.5 31000 270 3/20/05 6242 9.7 9.91 44 14 21 6/18/23 5.8 1/ 8 2/90 0.2 9.4 31000 120 3/21/05 6384 9.7 9.86 46 14 19 7/15/20 5.2 1/ 8 2/90 0.1 9.4 32000 80 3/22/05 6800 9.8 9.94 46 14 19 7/24/30 5.0 1/ 8 2/90 0.2 9.4 38000 80 3/23/05 7359 10.0 10.13 47 17 22 7/19/22 5.0 1/ 10 2/88 0.2 9.3 40000 80 3/24/05 7400 10.0 10.14 49 17 22 6/16/22 4.8 1/ 10 2/88 0.2 9.3 38500 80 3/25/05 8040 10.1 10.45 51 19 28 7/20/26 4.8 1/ 11 21/68 0.2 9.0 34000 80 3/26/05 8040 1 0.1 10.45 55 15 18 4/15/20 4.6 1/ 10 2/88 0.1 9.2 35000 80 3/27/05 8040 10.2 1 0.45 50 18 20 5/14/19 4.8 1/ 11 2/87 0.2 9.0 29000 120 8 %" section 3/28/05 8250 11.5 12.32 53 21 35 8/24/31 4.8 1/ 16 2/82 0.2 10.5 31000 320 3/29/05 9020 11.6 12.54 60 25 36 11/26/30 4.0 1/ 15 3/82 0.2 9.1 32000 280 3/30/05 9525 11.8 12.72 57 25 35 14/34/40 4.6 1/ 17 2.5/80.5 0.2 8.8 33000 240 3/31/05 10240 11.8 12.75 47 21 33 14/28/32 4.9 1/ 17 3/80 0.2 9.0 32500 240 4/1/05 10542 12.1 12.95 51 18 40 12/20/25 4.9 1/ 18.5 3/78.5 0.2 9.1 33000 200 4/2/05 10968 12.0 12.77 50 18 32 n/a 5.0 2/ 17 3/80 0.2 9.1 33000 240 4/3/05 11002 12.0 12.65 49 24 26 1 0/18/26 4.4 2/ 17 3/80 0.2 9.0 36000 80 £:I EPOCH 30 . conoCailliPS Alaska, Inc. Kokoda #5 . Date Depth MW ECD VIS PV YP Gels FL FC Sols OIW Sd pH CI Ca (ppg) (ppg) (s/qt) (ee) (%) Ratio (%) (mill) (mill) 4/4/05 11122 12.1 12.83 52 22 36 10/21/26 4.0 1/ 18 3/79 0.2 9.0 33500 240 4/5/05 11122 12.2 N/A 49 22 34 1 0/18/22 3.7 2/ 18 3/79 0.2 9.0 34000 220 4/6/05 11122 12.1 N/A 53 21 38 11/18/22 3.5 2/2 18 3/79 0.2 8.9 35000 320 4/7/05 11122 12.1 N/A 51 20 32 10/15/18 3.7 1/2 17.5 4/79 0.2 9.0 32000 240 4/8/05 11122 12.2 N/A 59 25 44 13/20/23 3.5 1/2 18 3/79 0.2 9.4 32000 260 4/9/05 11122 12.4 N/A 56 20 37 10/15/17 3.4 1/2 18 3/79 0.2 9.1 34000 220 4/10/05 11122 12.5 N/A 58 20 37 1 0/14/15 3.5 1/2 19 3/78 0.2 9.1 33500 240 4/11/05 11122 12.4 N/A 60 20 34 1 0/14/16 3.4 1/2 18.5 3/79 0.2 8.9 33500 240 4/12/05 11122 12.4 N/A 56 20 31 8/12/15 3.3 1/2 19 3/78 0.1 10.2 32500 220 4/13/05 11122 12.4 N/A 56 19 29 8/12/14 3.4 1/2 19 3/78 0.2 9.5 32500 240 4/14/05 11122 12.3 N/A 58 23 39 1 0/13/16 3.5 1/2 18 2/80 0.1 9.2 34000 200 4/15/05 11122 12.3+ N/A 52 22 38 11/14/18 2.8 1/2 19 3/78 0.1 9.2 32500 120 4/16/05 11122 12.3+ N/A 53 25 41 11/15/18 2.4 1/2 18.5 3/79 0.1 9.0 33000 120 4/17/05 11122 12.3+ N/A 56 28 39 12/12/23 2.5 1/2 18 3/79 0.1 9.2 32500 140 4/18/05 11122 12.5 N/A 63 31 45 15/22/26 2.8 1/2 19.5 3/78 NA 9.1 31500 160 4/19/05 11122 12.5 N/A 58 28 43 14/19/23 2.6 1/ 18 3/79 Tr 9.2 32500 120 4/20/05 11122 12.5 N/A 72 30 45 14/19/24 2.5 1/ 18 3/79 NA 9.0 31500 120 4/21/05 11122 12.5 N/A 68 30 45 14/22/26 2.7 1/ 19 3/78 NA 9.3 31500 120 4/22/05 11122 12.6 77 30 44 14/21/27 2.6 1/ 19 3/78 0.1 9.3 31000 120 Abbreviations MW = Mud Weight WL = Water or Filtrate Loss Ca = Hardness Calcium YP = Yield Point Gels = Gel Strength CI = Chlorides PV = Plastic Viscosity Sd = Sand content VIS = Funnel Viscosity Sols = Solids ECD = Effective Circulating Density FC = Filter Cake O/w = Oil to Water ratio n EPOCH 31 6 MORNING REPORTS · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: LUTRICK I RIZEK MARK WOODS Current Depth (MD): 108 Current Depth (TVD): 108 24 hr Footage (MD): 0 Current Operations: Picking up pipe Date: 3fllOS Time: 0330 Mud Properties E MW: Gels: Gas Data: Nlone Operational Summary: Rig move, rig up, pick up pipe from pipe shed. · Calibrations: Calibrated chromatograph and total gas analyzer Failures: Daily Cost: $2630 · [:I EPOCH 32 ConocoPhillips Alaska Inc. Kokoda #5 Daily Report · Report for: LUTRICK / RIZEK MARK WOODS Date: 3/8/05 Time: 0330 Current Depth (MD): 244 Current Depth (TVD): 244 24 hr Footage (MD): 136 Current Operations: Drilling D "Ir P t n mg arame ers ROP: Current: 59 Max: 109 Toraue: Current: 0 Max: 1 WOB: Current 7.4 Max: 8 RPM: Current: 116 Max: 118 PP: Current: 465 Max: 551 Lag: Strokes: 588 Time: 4.9 Surf-Surf: Strokes: 605 Time: 5.05 ECD: Current: 9.93 Max: 6 400 MW Change: Mud Loss event: Depth: Depth : From: Volume: To: Reason: 219/219 Gas Events · NONE Depth C1 C2 C3 C41 C4N C51 C5N (MDITVD) Connection C1 C2 C3 C41 C4N C51 C5N Gases NONE Gas Samples No. Depth (MDfTVD) TG C1 C2 C3 C41 C4N C51 C5N NONE Lithologies: Current: ClaystonelTuff 40%, Coal 30%, Sand/Conglomerate 30% Last 24 hrs: Conglomerate, sandstone, claystone, coal, siltstone, tuff Operational Summa/)': PU DP from pipe shed, test diverter, PU BHA, test lines, fill conductor, spud 8:40 PM 3fl/05, clean cement out of conductor, bu/)' BHA past stabilizer, PU collars, drill to 244' at report time. Calibrations: Calibrated chromatograph and total gas analyzer. Failures: Daily Cost: $2630 · U EPOCH 33 · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: WINFREY I RIZEK MARK WOODS Date: 3/9/05 Current Depth (MD): Current Depth (TVD): 24 hr Footage (MD): 1061 1061 817 Current Operations: Pulling out of hole Time: 0330 D 1r P t n mg arame ers ROP: Current: na Max: 128 Torque: Current: na Max: 1 WOB: Current na Max: 18 RPM: Current: na Max: 136 PP: Current: na Max: 1535 Lag: Strokes: 2500 Time: 15.3 Surf-Surf: Strokes: 2587 Time: 15.8 ECD: Current: na Max: 4.8 300 MW Change: Mud Loss event: Depth: Depth : From: Volume: To: Reason: 809 I 809 · Gas Events Wiper Gas Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N 22u 1061/1061 Connection C1 C2 C3 C41 C4N C51 C5N Gases NONE G S as amples No. Depth (MDfTVD) TG C1 C2 C3 C41 C4N C51 C5N 1 500/500 3 686 2 1000/1000 20 3844 Lithologies: Current: 60% claystone, 20% each sandstone, siltstone Last 24 hrs: Sandstone, claystone, siltstone, minor coal near surface Operational Summary: Drill to 1061', Phase III weather conditions, CBUx2, std 1 std back, eire, POOH to conductor, RIH, CBU, POOH. Calibrations: Tested chromatograph and total gas analyzer, okay. Failures: none Daily Cost: $2630 · [:I EPOCH 34 · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: WINFREY I RIZEK MARK WOODS Date: 3/10/05 Time: 0330 Current Depth (MD): Current Depth (TVD): 24 hr Footage (MD): 1061 1061 o Current Wait on Weather Operations: o 11" P t n mg arame ers ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: . Surf-Surf: Strokes: Time: ECD: Current: Max: 3.8 300 MW Change: Mud Loss event: Depth: Depth : From: Volume: To: Reason: Gas Data I Ditch Gas: I Current: ~I Max: I 0 Avg BG : .. na ¡- · Gas Events I Depth (MDrrvD): I none Depth (MD/TVD) C1 C2 C3 C41 C4N C51 C5N Connection C1 C2 C3 C41 C4N C51 C5N Gases none G S as amples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Last 24 hrs: No new fonnation drilled Operational Summary: Wait on weather Calibrations: Tested chromatograph and total gas analyzer, okay Failures: none Daily Cost: $2630 · ~ EPOCH 35 ConocoPhillips Alaska Inc. Kokoda #5 Daily Report · Report for: WINFREY / RIZEK MARK WOODS Current Depth (MD): Current Depth (TVD): 24 hr Footage (MD): 1061 1061 o Current Operations: Wait on weather Date: 3/11/05 Time: 0330 DrillinQ Parameters ROP: Current: Max: TorQue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: LaQ: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: 5.1 300 MW Change: Mud Loss event: Depth: Depth: From: Volume: To: Reason: · Gas Events none Depth (MDfTVD) C1 C2 C3 C41 C4N C51 C5N Connection C1 C2 C3 C41 C4N C51 C5N Gases none G S as amples No. Depth (MDfTVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Last 24 hrs: No new fonnation drilled Operational Summary: Wait on weather Calibrations: Calibrated total gas analyzer and chromatograph Failures: none Daily Cost: $2630 · ~EPOCH 36 ConocoPhillips Alaska Inc. Kokoda #5 Daily Report · Report for: WINFREY I RIZEK MARK WOODS Current Depth (MD): Current Depth (TVD): 24 hr Footage (MD): 1445 1445 384 Current Operations: Drilling Date: 3/12/05 Time: 0330 D "II" P t n mg arame ers ROP: Current: 91 Max: 97 TOrQue: Current: 0 Max: 1 WOB: Current 11.9 Max: 26 RPM: Current: 132 Max: 138 PP: Current: 1624 Max: 1634 Lag: Strokes: 3630 Time: 20.4 Surf-Surf: Strokes: 3787 Time: 21.3 ECD: Current: 10.0 Max: 4.5 280 MW Change: Mud Loss event: Depth: Depth: From: Volume: To: Reason: Gas Data Ditch Gas: Avg BG : Current: 44 30 rising to 45u at report time 1370/1370 · Gas Events Trip Gas Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N 6u 1061/1061 Connection C1 C2 C3 C41 C4N C51 C5N Gases None G S as amples No. Depth (MDfTVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Siltstone 40%, claystone 30%, sandstone 20%, ash 10% Last 24 hrs: Claystone, sandstone, siltstone, ash Operational Summary: Wait on weather, drill to 1445' at report time. Calibrations: Calibrated total gas analyzer and chromatograph Failures: none Daily Cost: $2630 · [:I EPOCH 37 TOBY ARCHULETA Date: 3/13/05 Time: 0330 Current Depth (MD): 2255 Current Depth (TVD): 2255 24 hr Footage (MD): 810 Current Operations: Drilling · Drilling Parameters ROP: Current: 30 Max: 156 Torque: Current: 1.6 Max: 8 WOB: Current 28 Max: 32 RPM: Current: 133 Max: 147 PP: Current: 1772 Max: 1973 Lag: Strokes: 5742 Time: 31.9 Surf-Surf: Strokes: 6043 Time: 33.6 ECD: Current: 10.0 Max: 3.8 160 MW Change: Mud Loss event: Depth: Depth : From: Volume: To: Reason: 1600/1600 Gas Events Wiper Gas Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N 38u 1896/1896 Connection C1 C2 C3 C41 C4N C51 C5N Gases None G S · as amples No. Depth (MDnvD) TG C1 C2 C3 C41 C4N C51 C5N 3 1500/1500 55 13833 42 4 1604/1604 920 177158 43912 65 3618 5 2000/2000 36 7515 44 Lithologies: Current: 90% claystone, 10% siltstone Last 24 hrs: Claystone, sandstone, siltstone, carbonaceous shale, tuff, coal Operational Summary: Drilled to 1803', circ and ream, tight, drilled to 1896', CBUx2, short trip to 1060', RIH and drill to 2255' at report time. Calibrations: Tested total gas analyzer and chromatograph, okay. Failures: none Daily Cost: $2630 [:I EPOCH 38 · . ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: WINFREE / RIZEK TOBY ARCHULETA Date: 3/14/05 Time: 0330 Current Depth (MD): 2615 Current Depth (TVD): 2615 24 hr Footage (MD): 360 Current Operations: Circulating hi-vis sweep D 11" P n mg arameters ROP: Current: na Max: 77 Torque: Current: 0 Max: 3.8 WOB: Current na Max: 38 RPM: Current: 134 Max: 137 PP: Current: 1800 Max: 2127 Lag: Strokes: 6650 Time: 37.8 Surf-Surf: strokes: 7020 Time: 39.9 ECD: Current: 10.01 Max: 4.5 180 MW Change: Mud Loss event: Depth: Depth : From: Volume: To: Reason: . Gas Events Wiper Gas Depth (MD/TVD) C1 C2 C3 C41 C4N C51 C5N 110u 2615/2615 Max gas while reaming tight spot @ +1- 1690 below high gas zone 42u Connection C1 C2 C3 C41 C4N C51 C5N Gases None Lithologies: Current: 70% claystone, 20% siltstone, 10% sand Last 24 hrs: Claystone, siltstone, sandstone, minor very hard claystone/shale Operational Summary: Drill to surface TD of2615', hole tight, backream every 45' then every 30', hole tight when backreaming connections, CBU, eirc sweep with little increase in cuttings, POOH with tight spots to +/- 600', RIH, tight @ 1690', 42u max gas while reaming tight spot below gas zone from +/-1600', continue TIH, eirc, 110u max gas, pump hi-vis sweep and continue eirc hole clean at report time. Calibrations: Tested total gas analyzer and chromatograph, okay. Failures: none . Daily Cost: $2630 [:I EPOCH 39 . ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: WINFREE / RIZEK TOBY ARCHULETA Date: 3/15/05 Time: 0330 Current Depth (MD): Current Depth (TVD): 24 hr Footage (MD): 2615 2615 o Current Operations: RIH in casing w DP o II· P ri mg arameters ROP: Current: na Max: na TOrQue: Current: na Max: na WOB: Current na Max: na RPM: Current: na Max: na PP: Current: na Max: na Lag: Strokes: na Time: na Surf-Surf: Strokes: na Time: na ECD: Current: na Max: na 4.5 240 MW Change: Mud Loss event: Depth: Depth : From: Volume: To: Reason: . Gas Events Max gas CBU after landing Depth (MDnvD) C1 C2 C3 C41 C4N C51 C5N casing 35u 2609' I 2609' Connection C1 C2 C3 C41 C4N C51 C5N Gases na Lithologies: Current: Last 24 hrs: No new formation drilled. Operational Summary: Circulate hole clean, POOH, LD BHA, rig up and run casing, tight @ +/-300', wash from 2408' to 2609', land casing, eirc, 35u max gas, RD casing equipment, RIH in casing with DP at report time. Calibrations: Tested total gas analyzer and chromatograph, okay. Failures: none Daily Cost: $2630 . [:I EPOCH 40 · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: Winfree / Wilson Toby Archuleta Date: 3/16/05 Time: 0330 Current Depth (MD): 2615 Current Depth (TVD): 2615 24 hr Footage (MD): 0 Current Test BOP's Operations: D 11" P t n 109 arame ers ROP: Current: na Max: na Torque: Current: na Max: na WOB: Current na Max: na RPM: Current: na Max: na PP: Current: na Max: na Lag: Strokes: na Time: na Surf-Surf: Strokes: na Time: na ECD: Current: na Max: na 4.6 40 MW Change: Mud Loss event: Depth: Depth: From: Volume: To: Reason: · Gas Events Max gas circ thru DP in Depth (MD/TVD) C1 C2 C3 C41 C4N C51 C5N casing 36u Connection C1 C2 C3 C41 C4N C51 C5N Gases na Lithologies: Current: Last 24 hrs: No new formation drilled. Operational Summary: RIH in casing with DP, sting into float collar, condition hole, perform cement job, LD pup joints, flush stack, POOH, nipple down diverter, LD seals, clear rig floor, LD landing joint, nipple up, LD DP, body test BOPE to 3500, Calibrations: Tested total gas analyzer and chromatograph, okay. Failures: none Daily Cost: $2630 · [:I EPOCH 41 · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: Winfree / Wilson Toby Archuleta Date: 3/17/05 Time: 0330 Current Depth (MD): 2615 Current Depth (TVD): 2615 24 hr Footage (MD): 0 Current Operations: Casing test D "II" P t n mg arame ers ROP: Current: na Max: na TOrQue: Current: na Max: na WOB: Current na Max: na RPM: Current: na Max: na PP: Current: na Max: na Lag: Strokes: na Time: na Surf-Surf: Strokes: na Time: na ECD: Current: na Max: 5.6 400 MW Change: Mud Loss event: Depth: Depth: From: Volume: To: Reason: Gas Data I Ditch Gas: I Current: ¡-r] Max: I 0 . Avg BG : .. na ¡- · Gas Events I Depth (MD/1VD): None Depth (MD/TVD) C1 C2 C3 C41 C4N C51 C5N Connection C1 C2 C3 C41 C4N C51 C5N Gases na Lithologies: Current: Last 24 hrs: No new formation drilled. Operational Summary: PU DP, test BOP's, MU new BHA and RIH, MWD failure, POOH to change out MWD, RIH, test MWD, continue RIH, PU singles and single into hole, tag up @ 2523', test casing at report time. Calibrations: Calibrated total gas analyzer and chromatograph. Failures: none Daily Cost: $2630 · ~ EPOCH 42 ConocoPhillips Alaska Inc. Kokoda #5 Daily Report · Report for: Winfree / Wilson Toby Archuleta Date: 3/18/05 Time: 0330 Current Depth (MD): 3756 Current Depth (TVD): 3755 24 hr Footage (MD): 1141 Current Operations: Trip for LWD problems. Drilling Parameters ROP: Current: 103 Max: 206 Torque: Current: 6.4k Max: 11k WOB: Current 12k Max: 15k RPM: Current: 94 Max: 95 PP: Current: 1900 Max: 1920 Lag: Strokes: 4724 Time: 32.1 Surf-Surf: Strokes: 5393 Time: 36.7 ECD: Current: 10.24 Max: 10.37 4.8 550 MW Change: Mud Loss event: Depth: None Depth: None From: Volume: To: Reason: 3285/3284 · Gas Events Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N Connection None C1 C2 C3 C41 C4N C51 C5N Gases G S as amples No. Depth (MDITVD) TG C1 C2 C3 C41 C4N C51 C5N 7 3000/3000 25 5753 6 8 3500/3500 40 8810 39 8 3 4 3 2 Lithologies: Current: 80% claystone, 20% siltstone Last 24 hrs: 60% claystone, 20% siltstone, 20% sand and sandstone. Operational Summary: Drill cement, shoe track and formation to 2635', displace with 9.6 ppg mud. FIT @ 2635' = 16.1 EMW. Drill to 3756', trip for LWD problems. Calibrations: Tested total gas analyzer and chromatograph, okay. Failures: none Daily Cost: $2630 · [:I EPOCH 43 · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: Winfree / Wilson Toby Archuleta Date: 3/19/05 Time: 0300 Current Depth (MD): 4410 Current Depth (TVD): 4410 24 hr Footage (MD): 654 Current Operations: Drilling. D "II" P t n 109 arame ers ROP: Current: 80 Max: 226 Torque: Current: 5K Max: 11k WOB: Current 12K Max: 15k RPM: Current: 100 Max: 100 PP: Current: 2000 Max: 2050 Lag: Strokes: 5617 Time: 37.2 Surf-Surf: Strokes: 6399 Time: 42.4 ECD: Current: 9.98 Max: 10.20 5.8 600 MW Change: Mud Loss event: Depth: None Depth: None From: Volume: To: Reason: 4177/4177 · Gas Events Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N Trip gas 3756/3756 77u Connection NONE C1 C2 C3 C41 C4N C51 C5N Gases G S as amples No. Depth (MDITVD) TG C1 C2 C3 C41 C4N C51 C5N 9 4000/4000 46 10826 87 26 6 7 2 2 Lithologies: Current: 70% claystone, 20% shale, 10% siltstone Last 24 hrs: 70% claystone, 25% siltstone, 5% shale, trace sand Operational Summary: Trip for LWD problems. Drill from 3756' to 4410' at report time. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $2630 · [:I EPOCH 44 · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: Winfree / Wilson Toby Archuleta Date: 3/20105 Time: 0330 Current Depth (MD): 5340 Current Depth (TVD): 5340 24 hr Footage (MD): 930 Current Operations: Drilling. D rillina Parameters ROP: Current: 50 Max: 145 Torque: Current: 2K Max: 8K WOB: Current 10K Max: 15K RPM: Current: 96 Max: 100 PP: Current: 2150 Max: 2260 LaQ: Strokes: 6920 Time: 45.5 Surf-Surf: strokes: 7873 Time: 51.8 ECD: Current: 9.98 Max: 10.16 7.6 270 MW Change: Mud Loss event: Depth: None Depth: None From: Volume: To: Reason: 4986/4986 · Gas Events Depth (MDrrvD) C1 C2 C3 C41 C4N C51 C5N Wiper Gas 5241/5241 155u Connection C1 C2 C3 C41 C4N C51 C5N Gases NONE Gas Samples No. Depth (MDITVD) TG C1 C2 C3 C41 C4N C51 C5N 10 4500/4500 31 6649 61 17 4 2.5 1.5 1 11 4600/4600 31 6800 49 14 4 3 1 1 12 4700/4700 32 7632 53 14 4 4 1 1 13 4800/4800 36 8928 61 20 5 6 2 1 14 4900/4900 38 8844 69 23 7 4 1 0 15 5000/5000 45 10728 89 29 9 6 2 1 16 5100/5100 35 7312 74 25 7 4 2 1 17 5200/5200 28 5432 58 25 9 5 1.5 1 18 5300/5300 24 5450 65 24 4 2 1 0 Lithologies: Current: 70% CLAYSTONE, 20% SHALE, 10% SILTSTONE Last 24 hrs: 70% CLAYSTONE, 20% SHALE, 10% SILTSTONE. Operational Summary: Drill from 4410' to 5241', wipe hole. Drill to 5340' at report time. · Calibrations: Chromatograph, THA. Failures: None ~Em~M 45 . ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: Winfree / Wilson Toby Archuleta Date: 3/21/05 Time: 0330 Current Depth (MD): 6300 Current Depth (TVD): 6300 24 hr Footage (MD): 960 Current Operations: Drilling Drillino Parameters Rap: Current: 20 Max: 119 Torque: Current: 4.5k Max: 11k WOB: Current 10k Max: 15k RPM: Current: 102 Max: 102 PP: Current: 2350 Max: 2500 Lao: Strokes: 7763 Time: 51 Surf-Surf: Strokes: 8885 Time: 58 ECD: Current: 9.89 Max: 9.99 5.8 120 MW Change: Mud Loss event: Depth: None Depth: None From: Volume: To: Reason: . Gas Events Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N Connection C1 C2 C3 C41 C4N C51 C5N Gases NONE Gas Samples No. Depth (MDITVD) TG C1 C2 C3 C41 C4N C51 C5N 19 5400/5400 22 5219 74 31 15 11 7 6 20 5500/5500 22 5007 81 33 11 7 2 1 21 5600/5600 24 5346 88 33 14 11 5 0 22 5700/5700 23 5217 88 33 12 8 2 0 23 5800/5800 16 3045 65 25 8 6 2 1 24 5900/5900 24 4421 99 32 10 6 3 1 25 6000/6000 18 3538 97 34 11 7 3 1 26 6100/6100 15 2557 78 25 8 5 2 1 27 6200/6200 25 5099 180 60 14 10 5 1 28 6300/6300 32 7291 313 109 21 16 5 1 Lithologies: Current: 60% claystone, 20% siltstone, 20% shale Last 24 hrs: 50% claystone, 20% siltstone, 20% shale, 10% sandstone Operational Summary: Drill from 5340' to 6300' at report time. . Calibrations: Chromatograph, THA. Failures: None ~EP@@I3P 46 · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: Winfree I Wilson Toby Archuleta Date: 3/22/05 Time: 0330 Current Depth (MD): 6386 Current Depth (TVD): 6386 24 hr Footage (MD): 86 Current Operations: Drilling 0"11" P n mg arameters ROP: Current: 0 Max: 38 Toraue: Current: 0 Max: 11k WOB: Current 0 Max: 15 RPM: Current: 76 Max: 100 PP: Current: 2440 Max: 2520 Lag: Strokes: 7793 Time: 51.6 Surf-Surf: strokes: 8927 Time: 59.1 ECD: Current: 9.88 Max: 9.90 5.2 80 MW Change: Mud Loss event: Depth: None Depth: None From: Volume: To: Reason: · Gas Events Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas 6386/6386 200u Connection C1 C2 C3 C41 C4N C51 C5N Gases None I ~~sr:~ (MDITW) I TG I CI I C2 I C3 I ~t I ~N I CSt I CSN I Lithologies: Current: 50% claystone, 30% shale, 10% tuff, 10% siltstone Last 24 hrs: 50% claystone, 30% shale, 10% tuff, 10% siltstone Operational Summary: Drill to 6386'. Trip due to slow ROP. Run in hole. Circulate bottoms up. No drilling data below 6386' available at report time. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $2630 · ~ EPOCH 47 ConocoPhillips Alaska Inc. Kokoda #5 Daily Report · Report for: Lutrick / Wilson Toby Archuleta Date: 3/23/05 Time: 0330 Current Depth (MD): 6960 Current Depth (TVD): 6952 24 hr Footage (MD): 574 Current Operations: Drilling Dlr P t n mg arame ers Rap: Current: 40 Max: 83 TOrQue: Current: 4.5k Max: 7k WOB: Current 45 Max: 48 RPM: Current: 78 Max: 82 PP: Current: 2750 Max: 2850 Lag: Strokes: 8506 Time: 56 Surf-Surf: Strokes: 9748 Time: 64.1 ECD: Current: 9.87 Max: 9.9 5 80 MW Change: Mud Loss event: Depth: 6800 Depth: None From: 9.7 Volume: To: 9.8 Reason: Planned · Gas Events Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N Connection C1 C2 C3 C41 C4N C51 C5N Gases 5 6812/6810 5 6905/6902 Gas Samples No. Depth (MDITVD) TG C1 C2 C3 C41 C4N C51 C5N 29 6400/6400 17 3945 146 65 16 10 1 0 30 6500/6500 10 2331 126 63 11 11 5 0 31 6600/6600 15 2743 174 91 10 17 5 2 32 6682/6681 98 16607 1764 1378 184 340 74 69 33 6700/6699 234 34154 4057 3473 516 939 195 188 34 6710/6709 273 40128 4809 4152 597 1104 258 264 35 6720/6719 236 35280 3979 3368 486 908 205 198 36 6730/6729 176 24757 3230 3061 463 877 200 196 37 6740/6739 150 19216 2785 2940 477 908 214 212 38 6750/6749 180 23322 3213 3221 511 961 229 231 39 6760/6759 85 12411 1866 2092 356 688 183 190 40 6800/6798 39 3459 520 712 138 303 88 96 41 6900/6898 29 3510 323 348 69 165 57 67 Lithologies: Current: 30% claystone, 30% shale, 20% siltstone, 10% sandstone, 10% tuff Last 24 hrs: 40% claystone, 20% shale, 20% siltstone, 15% sandstone, 5% tuff · Operational Summary: Drill from 6386' to 6960' at report time. Calibrations: Chromatograph, THA. Failures: None [:Io}i)P@@J¥ 48 · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: Lutrick / Wilson Toby Archuleta Date: 3/24/05 Time: 0330 Current Depth (MD): 7400 Current Depth (TVD): 7355 24 hr Footage (MD): 440 Current Operations: TRIPPING. D P rilling arameters ROP: Current: 0 Max: 68 Torque: Current: 0 Max: 10k WOB: Current 0 Max: 55 RPM: Current: 0 Max: 80 PP: Current: 0 Max: Lag: Strokes: 9037 Time: 59.5 Surf-Surf: Strokes: 10355 Time: 68.1 ECD: Current: 10.16 Max: 10.16 5 80 MW Change: Mud Loss event: Depth: 7030 Depth: None From: 9.8 Volume: To: 10.0 Reason: Planned 7388/7344 · Gas Events Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N Connection C1 C2 C3 C41 C4N C51 C5N Gases 5u 6998/6990 5u 7090/7080 10u 7185/7167 30u 7278/7247 30u 7370/7329 Gas Samples No. Depth (MDITVD) TG C1 C2 C3 C41 C4N C51 C5N 42 7000/6991 15 1647 145 136 25 64 26 20 43 7100/7086 17 2764 234 164 26 56 15 15 44 7132/7015 78 13824 1222 821 166 237 41 37 45 7171/7152 121 20562 2125 1521 310 461 147 107 46 7180/7160 59 7946 990 831 188 294 103 84 47 7200/7178 47 5873 756 689 159 263 97 84 48 7300/7268 42 5210 663 552 106 226 73 65 49 7372/7331 102 19282 1692 1025 129 325 85 86 50 7400/7355 47 6596 776 589 98 250 91 74 · Lithologies: Current: 30% claystone, 20% sandstone, 20% tuff, 20% siltstone, 10% shale Last 24 hrs: 40% claystone, 20% sandstone, 10% tuff, 20% siltstone, 10% shale Operational Summary: Drill to 7400'. Circulate hole clean. Pull out of hole. Calibrations: Chromatograph, THA. Failures: NONE ~lW@@M 49 · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: Lutrick I Wilson Toby Archuleta Date: 3/25/05 Time: 0345 Current Depth (MD): 7400 Current Depth (TVD): 7355 24 hr Footage (MD): 0 Current Operations: Wash/ream to bottom. Drillina Parameters No new hole.) ROP: Current: Max: TOrQue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: 4.8 80 MW Change: Mud Loss event: Depth: None Depth: None From: Volume: To: Reason: Gas Data (No new hole.) I Ditch Gas: I Current: P Max: I . Avg BG: .. 40 . · Gas Events I Depth (MD/TVD): Depth (MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas 7400fi355 375u Connection C1 C2 C3 C41 C4N C51 C5N Gases I ~~ r:~~ ~~D~~Olr) TG I CI I C2 I C3 I ~I I ~N I œl I C5N I Lithologies: Current: No new hole. Last 24 hrs: Operational Summary: Trip out of hole. Test BOPs. Run in hole to shoe. Cut and slip drilling line. Run into hole. Wash/ream to bottom. Calibrations: Chromatograph. THA. Failures: None Daily Cost: $2630 · [:I EPOCH 50 · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: Lutrick / Wilson Toby Archuleta Date: 3/26/05 Time: 0230 Current Depth (MD): 8040 Current Depth (TVD): 7903 24 hr Footage (MD): 640 Current Operations: Wiper trip. Drilling Parameters Rap: Current: 73 Max: 139 TorQue: Current: 8K Max: 11K WOB: Current 14K Max: 39K RPM: Current: 81 Max: 85 PP: Current: 3000 Max: 3400 La,,: Strokes: 10060 Time: 66.2 Surf-Surf: Strokes: 11492 Time: 75.6 ECD: Current: 10.45 Max: 10.45 4.8 80 Gas Data Ditch Gas: Avg BG : Gas Events 7613n541 · Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N Connection C1 C2 C3 C41 C4N C51 C5N Gases 10 7463n411 70 7556n492 30 7649/7571 20 7742/7651 20 7834n729 30 7927n808 30 8020n886 Gas Samples No. Depth (MDrrVD) TG C1 C2 C3 C41 C4N C51 C5N 51 7470n417 100 18222 1935 1258 160 409 96 103 52 7500n443 230 40876 4899 2883 294 758 158 177 53 7528n467 492 126645 14223 7947 729 1890 323 382 54 7548n485 406 78431 10062 5955 592 1577 283 344 55 7573n506 509 125620 16686 9654 942 2379 395 484 56 7588n519 580 167803 21489 11504 1021 2687 461 600 57 7613n541 618 179374 22890 12278 1089 2939 495 645 58 7650n572 310 44374 7209 5367 582 1714 370 434 59 7700n615 362 68135 8892 5741 594 1881 361 484 60 7750/7658 284 47924 5947 4341 502 1581 329 451 61 7800n700 229 30928 4470 3733 462 1473 316 430 62 7850/7743 189 25024 3233 2900 387 1240 276 369 63 7900n785 164 20007 2864 2776 389 1201 293 405 64 8000n869 180 23467 3118 2870 422 1141 269 353 · Lithologies: Current: 60% Shale, 30% Claystone, 10% Carbonaceous Shale Last 24 hrs: 30% Carbonaceous shale, 30% Sandstone, 20% Shale, 20% Claystone Operational Summary: Wash/ream to bottom. Drill from 7400' to 8040'. Circulate hole clean. Wipe hole. Calibrations: None Failures: None UoJmRQ(i2Hj 51 · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: Lutrick./ Wilson Mark Wood Date: 3/27105 Time: 0330 Current Depth (MD): 8040 Current Depth (TVD): 7903 24 hr Footage (MD): 0 Current Operations: Running casing. Drillino Parameters No new hole) ROP: Current: Max: TOrQue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lao: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: 4.6 80 MW Change: Mud Loss event: Depth: None Depth: None From: Volume: To: Reason: · Gas Events Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N Wiper Gas 8040'fi903' 545u Connection C1 C2 C3 C41 C4N C51 C5N Gases Gas Samples (No new hole) No. Depth (MDITVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: No new hole Last 24 hrs: Operational Summary: Finish wiper trip. Circulate. Pull out of hole. Rig up and run casing. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $2630 · ~ EPOCH 52 ConocoPhillips Alaska Inc. Kokoda #5 Daily Report · Report for: Lutrick / Wilson Mark Wood Date: 3/28/05 Time: 0200 Current Depth (MD): Current Depth (TVD): 24 hr Footage (MD): 8040 7903 o Current Operations: Pick up drill pipe. Drilling Parameters (No new hole) ROP: Current: Max: Toraue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: LaQ: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: 4.8 120 MW Change: Mud Loss event: Depth: None Depth: None From: Volume: To: Reason: Gas Events · Depth (MDfTVD) C1 C2 C3 C41 C4N C51 C5N Casing Bottoms-up 8040/7903 380u Connection C1 C2 C3 C41 C4N C51 C5N Gases Gas Samples (No new hole) No. Depth (MDfTVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: No new hole. Last 24 hrs: Operational Summary: Run casing. Circulate and cement casing. Change pipe rams. Make up BHA. Pick up drill pipe. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $2630 · ~ EPOCH 53 · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: Lutrick / Wilson Mark Wood Date: 3/29/05 Time: 0330 Current Depth (MD): 8430 Current Depth (TVD): 8220 24 hr Footage (MD): 390 Current Operations: Drilling D 1r n !nO Parameters ROP: Current: 60 Max: 111 Torque: Current: 6K Max: 9K WOB: Current 10K Max: 10K RPM: Current: 90 Max: 90 PP: Current: 2900 Max: 2900 Lao: Strokes: 4293 Time: 33.5 Surf-Surf: Strokes: 5781 Time: 45.2 ECD: Current: 12.49 Max: 12.49 4.8 320 8040 10.0 MW Change: Depth: 8066 From: 10.2 8250 11.3 Mud Loss event: Depth: None Volume: · Gas Data Ditch Gas: Avg BG : Gas Events 10.2 To: 11.3 11.5 Planned Reason: Planned Planned 8428/8219 Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N Connection C1 C2 C3 C41 C4N C51 C5N Gases 4 8192/8029 3 8283/8103 G S as amples No. Depth (MDITVD) TG C1 C2 C3 C41 C4N C51 C5N 65 8100n953 33 3926 560 506 100 216 70 88 66 8209/8043 53 6862 1050 960 176 316 50 84 67 8300/8116 70 10349 1473 1170 202 341 65 82 68 8400/8196 80 12745 1829 1327 220 374 100 109 Lithologies: Current: 60% shale, 30% claystone, 10% sand Last 24 hrs: 60% shale, 20% claystone, 10% siltstone, 10% sand Operational Summary: Pick up drill pipe. Flush casing annulus. Cut drilling line. Pick up drill pipe. Test casing. Drill float, cement, casing shoe and 20' new hole. Perform FIT. Drill ahead. · Calibrations: Chromatograph, THA. Failures: None Daily Cost: $2630 ~ EPOC~H 54 · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: Lutrick / Rezik Mark Wood Date: 3/30/05 Time: 0330 Current Depth (MD): 9240 Current Depth (TVD): 8843 24 hr Footage (MD): 810 Current Operations: DRILLING D rillinQ Parameters ROP: Current: 47 Max: 163 Torque: Current: 8K Max: 9K WOB: Current 12 Max: 12 RPM: Current: 90 Max: 90 PP: Current: 3300 Max: 3300 LaQ: Strokes: 4794 Time: 36.9 Surf-Surf: Strokes: 6439 Time: 49.5 ECD: Current: 12.64 Max: 12.64 4.0 280 Planned Gas Data Ditch Gas: Avg BG : 8673/8408 Gas Events · Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N Connection C1 C2 C3 C41 C4N C51 C5N Gases 4 8469/8251 4 8562/8323 4 8655/8326 2 8748/8465 5 8841/8536 2 8934/8607 3 9026/8677 4 9120/8752 3 9212/8821 Gas Samples No. Depth (MDITVD) TG C1 C2 C3 C41 C4N C51 C5N 69 8500/8275 71 11654 1625 1102 174 311 77 78 70 8600/8352 104 17512 2487 1548 225 409 98 94 71 8676/8334 285 45307 6646 3917 517 954 236 224 72 8700/8428 129 19483 3270 2259 339 634 154 157 73 8800/8505 72 9447 1700 1344 226 454 134 152 74 8900/8581 72 1 0182 1676 1172 195 402 126 127 75 8996/8655 100 14550 2448 1485 225 453 139 136 76 9100/8737 117 18282 3072 1735 258 520 156 151 77 9200/8812 109 15456 2938 1738 263 534 178 184 · Lithologies: Current: 60% SHALE, 20% CLAYSTONE, 20% SILTSTONE Last 24 hrs: 40% SHALE, 30% CLAYSTONE, 20% SILTSTONE, 10% SAND Operational Summary: Drill ahead. Calibrations: Chromatograph, THA. Failures: NONE ~:LßI1Qwl31i 55 · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: Lutrick / Rezik Mark Wood Date: 3/31/05 Time: 0330 Current Depth (MD): 9750 Current Depth (TVD): 9234 24 hr Footage (MD): 510 Current Operations: Drilling D "II" P t n mg arame ers ROP: Current: 35 Max: 143 Torque: Current: 6k Max: 9k WOB: Current 12k Max: 18k RPM: Current: 90 Max: 94 PP: Current: 3100 Max: 3320 Lag: Strokes: 4915 Time: 40.3 Surf-Surf: Strokes: 6650 Time: 54.5 ECD: Current: 12.5 Max: 12.7 4.6 240 MW Change: Depth: 9397' From: 11.7 Mud Loss event: Depth: None Volume: · Gas Data Ditch Gas: Avg BG : Gas Events To: 11.8 Reason: Increased gas/ splintery shale 9271/8867 Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N Connection Gases C1 C2 C3 C41 C4N C51 C5N 4u 9490/9032 4u 9583/9103 Wiper Gas 445u peak 160u 9397/8961 backaround Gas Samples No. Depth (MDfTVD) TG C1 C2 C3 C41 C4N C51 C5N 78 9300/8890 97u 13522 2574 1445 220 445 144 134 79 9398/8962 105u 14202 2891 1616 254 507 245 267 80 9500/9040 110u 15185 3000 1635 261 512 184 161 81 9600/9116 68u 8281 1845 1102 198 388 201 203 82 9700/9192 89u 11988 2553 1347 230 418 166 130 Lithologies: Current: 70% shale, 20% claystone, 10% siltstone Last 24 hrs: 60% shale, 20% claystone, 15% siltstone, 5% sand Operational Summary: Drill to 9397', wipe hole to shoe. Drill ahead. · Calibrations: THA. Failures: None [:fl!reffl 56 . ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: Lutrick / Rezik Mark Wood Date: 4/1/05 Time: 0330 Current Depth (MD): 10410' Current Depth (TVD): 9734' 24 hr Footage (MD): 660' Current Operations: Drilling D "II" P t n mg arameers ROP: Current: 100 Max: 150 Torque: Current: 7.5k Max: 10K WOB: Current 12k Max: 12K RPM: Current: 90 Max: 92 PP: Current: 3400 Max: 3400 Lag: Strokes: 5255 Time: 42.4 Surf-Surf: strokes: 7101 Time: 57.3 ECD: Current: 12.76 Max: 12.84 4.9 240 Depth: None Depth: None From: Volume: To: Reason: 10032/9451 . Gas Events Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N Connection C1 C2 C3 C41 C4N C51 C5N Gases 5 9769/9248 15 9862/9320 10 9954/9392 35 10047/9463 75 10140/9506 400 10233/9602 440 10325/9671 Gas Samples No. Depth (MDrrvD) TG C1 C2 C3 C41 C4N C51 C5N 83 9800/9272 69 8927 1889 1097 209 361 151 114 84 9930/9295 104 14875 3076 1508 272 442 207 166 85 9954/9314 206 34427 6275 2444 368 591 275 202 86 10036/9454 470 113826 18733 5632 720 1063 432 305 87 10160/9548 178 30463 4873 1976 335 530 263 199 88 10290/9645 100 17071 2757 1253 243 370 240 203 . Lithologies: Current: 50% Siltstone, 40% Shale, 10% Sandstone Last 24 hrs: 60% Shale, 20% Siltstone, 15% Claystone, 5% Sand/Sandstone Operational Summary: Drill to 10402'. Circulate bottoms up. Drill to 10410' at report time. Calibrations: THA. Failures: None ~~@Ja1> 57 ConocoPhillips Alaska Inc. Kokoda #5 Daily Report · Report for: Lutrick / Rezik Wood / Kuzminskas Date: 4/02105 Time: 0330 Current Depth (MD): 10650 Current Depth (TVD): 9917 24 hr Footage (MD): 240 Current Operations: Drilling. D 11" P n mg arameters ROP: Current: 15 Max: 109 Torque: Current: 7.5k Max: 10k WOB: Current 14k Max: 15k RPM: Current: 90 Max: 95 PP: Current: 3400 Max: 3450 Lag: Strokes: 5386 Time: 44.1 Surf-Surf: Strokes: 7282 Time: 59.7 ECD: Current: 12.7 Max: 12.9 4.9 200 MW Change: Mud Loss event: Depth: 10417 Depth: None From: 11.8 Volume: To: 12.0 Reason: Conn. gas 10615/9890 Gas Events · Wiper Gas Depth (MDrrvD) C1 C2 C3 C41 C4N C51 C5N 855 10417/9739 Connection C1 C2 C3 C41 C4N C51 C5N Gases 100 10511/9812 200 10603/9881 Gas Samples No. Depth (MDrrvD) TG C1 C2 C3 C41 C4N C51 C5N 89 10420/9743 86 10777 2615 1582 310 469 203 123 90 10550/9841 70 12013 1554 619 115 178 134 108 Lithologies: Current: 40% shale, 40% siltstone, 20% sandstone Last 24 hrs: 40% shale, 40% siltstone, 20% sandstone Operational Summary: Drill to 10417'. Circulate and raise mud weightto 12.0 ppg. Wipe hole. Drill ahead. Calibrations: THA Failures: None Daily Cost: $2630 · [:I EPO(~H 58 · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: Lutrick / Rezik Wood / Kuzminskas Date: 4/3/05 Time: 0330 Current Depth (MD): Current Depth (TVD): 24 hr Footage (MD): 10968 10176 318 Current Operations: Circulating D 11" P t n mg arame ers Rap: Current: 0 Max: 129 Torque: Current: 6k Max: 10k WOB: Current 0 Max: 17k RPM: Current: 40 Max: 90 PP: Current: 475 Max: 3300 Lag: Strokes: 5606 Time: 187 Surf-Surf: Strokes: 7563 Time: 252 ECD: Current: nla Max: 12.8 5.0 240 MW Change: Mud Loss event: Depth: None Depth: 10968 From: Volume: 360 bbl To: Reason: 10865/10092 · Gas Events Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N Connection C1 C2 C3 C41 C4N C51 C5N Gases 180 10696/9957 183 10789/10031 188 10882/101 05 G as SamPles No. Depth (MDITVD) TG C1 C2 C3 C41 C4N C51 C5N 91 10680/9945 119 27429 3152 1217 208 267 134 93 92 10810/10047 144 33321 3870 1649 329 403 204 134 93 10940/10152 253 64065 4939 1601 413 465 370 259 Lithologies: Current: 50% shale, 20% carbonaceous shale, 20% siltstone, 10% tuff Last 24 hrs: 40% shale, 40% siltstone, 20% sandstone Operational Summary: Drill to 10968'. Lost circulation. Restored circulation with LCM pill. Circulate and wait on arrival of new mud. Calibrations: Failures: Chromatograph, THA. None · Daily Cost: $2630 ~ EPOCH 59 · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: Lutrick I Rezik Wood / Kuzminskas Date: 4/04/05 Time: 0330 Current Depth (MD): Current Depth (TVD): 24 hr Footage (MD): 11 020 10215 52 Current Operations: Drilling D 11" P n mg arameters ROP: Current: 4 Max: 77 Torque: Current: 6.5k Max: 12k WOB: Current 27 Max: 30 RPM: Current: 90 Max: 90 PP: Current: 2800 Max: 3300 Lag: Strokes: 5697 Time: 48.3 Surf-Surf: Strokes: 7663 Time: 64.9 ECD: Current: 12.7 Max: 12.7 4.4 80 MW Change: Mud Loss event: Depth: None Depth: None From: Volume: To: Reason: 10979 · Gas Events Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N Connection C1 C2 C3 C41 C4N C51 C5N Gases 30 109731 I ~la::(MMW) I TG I C1 I C2 I C3 I C41 I C4N I C51 I C5N I Lithologies: Current: 40% tuff, 40% shale, 20% sand/sandstone Last 24 hrs: 40% tuff, 40% shale, 20% sand/sandstone Operational Summary: Circulate. Drill ahead. Calibrations: THA. Failures: None Daily Cost: $2630 · [:I EPOCH 60 . ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: Lutrick / Rezik Kuzminskas Date: 4/05/05 Time: 0130 Current Depth (MD): Current Depth (TVD): 24 hr Footage (MD): 11122 10301 102 Current Operations: Back ream D 11 n inQ Parameters ROP: Current: 0 Max: 29 TOrQue: Current: 5k Max: 12K WOB: Current 0 Max: 30K RPM: Current: 89 Max: 95 PP: Current: 1625 Max: 3080 LaQ: Strokes: 6018 Time: 5104 Surf-Surf: Strokes: 7994 Time: 68.3 ECD: Current: nla Max: 12.85 4.0 240 MW Change: Mud Loss event: Depth: None Depth: None From: Volume: To: Reason: 11068/10256 . Gas Events Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N Connection C1 C2 C3 C41 C4N C51 C5N Gases 210 11 068/1 0256 G S as amp es No. Depth (MDrrvD) TG C1 C2 C3 C41 C4N C51 C5N 94 11070/10258 188 45819 3779 1288 221 326 139 100 Lithologies: Current: 50% tuffaceous claystone, 30% calcareous tuff, 20% shale Last 24 hrs: 40% calcareous tuff, 30% tuffaceous claystone, 30% shale Operational Summary: Drill to 11122'. Circulate bottoms up. Well breathing. Attempt to POOH on elevators-unsuccessful. Back ream out of hole. Calibrations: NONE Failures: NONE Daily Cost: $2630 . ~ EPOCH 61 · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: M. Winfree / G. Rezik M. Kuzminskas Date: 4/6/05 Time: 0330 Current Depth (MD): Current Depth (fVD): 24 hr Footage (MD): 11122 10301 o Current Operations: Pump out of hole. Drilling Parameters No new hole) ROP: Current: Max: TOrQue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: 5.5 220 MW Change: Mud Loss event: Depth: None. Depth: 9400' From: Volume: 90 bbl To: Reason: Gas Data from back reaming. Ditch Gas: Current: 35 Avg BG: 150 Depth (MDITVD): Approx. 9294' · Gas Events (No new hole) Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N C1 C2 C3 C41 C4N C51 C5N Gas Samples (No new hole) No. Depth (MDfTVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: No new hole Last 24 hrs: Operational Summary: Back ream out of hole, packed-off and lost circulation at 9400'. Re-establish circulation. Continue back reaming out of hole to casing. Pump sweep. Pump out of hole. Calibrations: None Failures: None Daily Cost: $2630 · ~ EPOCH 62 ConocoPhillips Alaska Inc. Kokoda #5 Daily Report . Report for: M. Winfree I G. Rezik M. Kuzminskas Date: 4nl05 Time: 0330 Current Depth (MD): Current Depth (TVD): 24 hr Footage (MD): 11122 10301 o Current Operations: Reaming DrillinQ Parameters No new hole) ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: LaQ: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: 3.5 320 MW Change: Mud Loss event: Depth: None Depth: None From: Volume: To: Reason: 8105' . Gas Events Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N Bottom-up inside casing 7979' 74u C1 C2 C3 C41 C4N C51 C5N I ~os i:~ ¡~OD~~l TG I C1 I C2 I C3 I C41 I ~N I C51 I C5N I Lithologies: Current: No new hole Last 24 hrs: Operational Summary: Pull out of hole. Change BHA. Run in to casing shoe. Cut drilling line. Circulate. Ream hole. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $2630 . ~ EPOCH 63 · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: M. Winfree / G. Rezik M. Kuzminskas Date: 4/08/05 Time: 0330 Current Depth (MD): Current Depth (TVD): 24 hr Footage (MD): 11122 10301 o Current Operations: Reaming Drilling Parameters No new hole) ROP: Current: Max: Toraue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: 3.7 240 MW Change: Mud Loss event: Depth: None Depth: None From: Volume: To: Reason: 8405' · Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C51 C5N Wiper Gas 8560' C1 C2 C3 C41 C4N C51 C5N 90 Gas Samples (No new hole) No. Depth (MDfTVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Shale: 1-10 mm diam; platy to blocky and occasionally sub-splintery cuttings. Last 24 hrs: Operational Summary: Ream to 8560'. pump out of hole to 8000'; circulate bottoms up. Run in hole to 8270'. Reaming at 8506' at report time. Calibrations: None Failures: None Daily Cost: $2630 · [:I EPOCH 64 · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: M. Winfree / G. Rezik M. Kuzminskas Date: 4/9/05 Current Depth (MD): Current Depth (TVD): 24 hr Footage (MD): 11122 10301 o Current Operations: Reaming Time: 0330 Drilling Parameters No new hole) Rap: Current: Max: Toraue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: 3.5 260 MW Change: Mud Loss event: Depth: None Depth: 8511' From: Volume: 40 To: Reason: 10235 · Gas Events (None noted) Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N C1 C2 C3 C41 C4N C51 C5N Gas Samples (No new hole) No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Shale: 1-18 mm diameter, mostly flaky and blocky, common splintery shape. Last 24 hrs: Operational Summary: Packed-off, losing circulation while backreaming at 8511'. Re-establish circulation. Backream to shoe and pump sweep. Run in hole to bridge at 8323'. Wash and ream to 10680'. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $2630 · ~ EPOCH 65 · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: M. Winfree I G. Rezik M. Kuzminskas Date: 4/10105 Time: 0330 Current Depth (MD): Current Depth (TVD): 24 hr Footage (MD): 11122 10301 o Current Operations: Pulling out of hole. Drilling Parameters No new hole) ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: 3.4 220 Reason: Hole stability MW Change: Mud Loss event: Depth: 11122' From: 12.2 Depth: 10968' Volume: 135 bbl To: 12.4 Gas Data Ditch Gas: Current: Depth (MDITVD): Approx. 9000' A BG: 170 · Gas Events Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N None C1 C2 C3 C41 C4N C51 C5N Gas Samples (No new hole) No. Depth (MDITVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Shale: 1-10 mm diam; non calc; platy-blocky; occ subsplintery. Last 24 hrs: Operational Summary: Wash and ream from 10680' to 11122'. Circulate and raise mud weight to 12.3+ ppg. Pump and rotate out to 10770'. Pump LCM pill. Pump and rotate out to 8200'. Calibrations: THA. Failures: None Daily Cost: $2630 · ~ EPOCH 66 · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: M. Winfree I G. Rezik M. Kuzminskas Date: 4/11/05 Time: 0330 Current Depth (MD): Current Depth (TVD): 24 hr Footage (MD): 11122 10301 o Current Operations: Run 7" liner. Drilling Parameters No new hole) ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: strokes: Time: ECD: Current: Max: 3.5 240 MW Change: Mud Loss event: Depth: None Depth: None From: Volume: To: Reason: Gas Data Ditch Gas: Current: 28 Depth (MDITVD): Approx. 7539' · Avg BG : 70 Gas Events Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N None C1 C2 C3 C41 C4N C51 C5N Gas Samples (No new hole) No. Depth (MDITVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Last 24 hrs: Operational Summary: Pump out of hole to 8003'. Pull on elevators to 7539' and monitor well. Circulate bottoms up at 7539' and monitor well. Pull on elevators to 6611'. Pump out of hole to 4289' and monitor well. Pull 5 stands on elevators-fill o.k. Pump dry job, pull out of hole. Lay down BHA. Change rams and test same. Rig up and run 7" liner. Calibrations: Failures: THA. None · Daily Cost: $2630 U EPOCH 67 · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: M. Winfree / G. Rezik M. Kuzminskas Date: 4/12/05 Time: 0330 Current Depth (MD): Current Depth (TVD): 24 hr Footage (MD): 11122 10301 o Current Operations: Pulling out of hole. Drilling Parameters No new hole) ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: 3.4 240 MW Change: Mud Loss event: Depth: None Depth: None From: Volume: To: Reason: 8450' · Gas Events Depth (MDrrvD) C1 C2 C3 C41 C4N C51 C5N C1 C2 C3 C41 C4N C51 C5N I ~~i:~~~~oe) TG I 01 I 02 I 03 I ~I I ~N I 051 I œN I Lithologies: Current: Last 24 hrs: Operational Summary: Continue running 7" liner. Pick up hanger/packer. Circulate one liner volume. Run liner on drillpipe to 8851'. (Liner hanger failed.) Circulate bottoms up. Pull drill pipe out of hole. Calibrations: THA. Failures: None Daily,Cost: $2è~0 · [:I EPOCH 68 · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: M. Winfree I P.Wilson M. Kuzminskas Current Depth (MD): Current Depth (fVD): 24 hr Footage (MD): 11122 10301 o Current Operations: Washing liner to bottom. Date: 4/13/05 Time: 0400 Drilling Parameters No new hole.) ROP: Current: Max: TorQue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: strokes: Time: ECD: Current: Max: 3.3 220 MW Change: Mud Loss event: Depth: None Depth: None From: Volume: To: Reason: Gas Data 8797' Ditch Gas: Current: 130 Max: 235 Depth (MDITVD): Bottoms up from liner. Avg BG : 125 · Gas Events Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N None C1 C2 C3 C41 C4N C51 C5N Gas Samples (No new hole) No. Depth (MDITVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: No new hole. Last 24 hrs: Operational Summary: Continue pulling out of hole. Lay down running tool. Test BOPs. Pick up running tool. Run in hole. Re-Iatch 7" liner. Pull liner out to 8797'. Circulate one liner volume. Run in hole from 8797' to 8871'. Wash liner down to 8925' Calibrations: Failures: THA. None · Daily Cost: $2630 [:I EPOCH 69 · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: M. Winfree I P.Wilson M. Kuzminskas Date: 4/14/05 Time: 0330 Current Depth (MD): Current Depth (TVD): 24 hr Footage (MD): 11122 10301 o Current Operations: Pulling liner out of hole. DrillinQ Parameters No new hole) ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: LaQ: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: 3.4 240 MW Change: Mud Loss event: Depth: None Depth: None From: Volume: To: Reason: 9020' · Gas Events Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N None C1 C2 C3 C41 C4N C51 C5N I ~~r~~~~~~~~l TG I C1 I C2 I C3 I C41 I ~N I C51 I C5N I Lithologies: Current: No new hole. Last 24 hrs: Operational Summary: Wash and ream 7" liner from 8925' to 9060'. Work tight hole. Wash and ream 8982' to 9040'. Work tight hole. Pump out of hole from 8642' to 7991'. Circulate bottoms up, pump sweep, circulate. Pump out of hole from 7991' to top of liner. Pull liner out of hole. Calibrations: THA. Failures: None Daily Cost: $2630 · [:I EPOCH 70 . ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: M. Winfree I P.Wilson M. Kuzminskas Date: 4/15/05 Time: 0330 Current Depth (MD): Current Depth (TVD): 24 hr Footage (MD): 11122 10301 o Current Operations: Reaming at 9060' DrillinQ Parameters No new hole) ROP: Current: Max: Toraue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: LaQ: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: 3.5 200 MW Change: Mud Loss event: Depth: None Depth: None From: Volume: To: Reason: 8450' . Gas Events Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N None C1 C2 C3 C41 C4N C51 C5N Gas Samples (No new hole) No. Depth (MDITVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Last 24 hrs: Operational Summary: Continue laying down r liner. Rig down casing equipment. Make up BHA for clean-out run. Run in hole to 8000'. Circulate bottoms up. Run in hole to 8098'. Ream to 9060'. Calibrations: THA. Failures: None Daily Cost: $2630 . U EPOCH 71 ConocoPhillips Alaska Inc. Kokoda #5 Daily Report · Report for: M. Winfree I P.Wilson M. Kuzminskas Date: 4/16/05 Time: 0330 Current Depth (MD): Current Depth (ND): 24 hr Footage (MD): 11122 10301 o Current Operations: Running in hole. Drilling Parameters No new hole) ROP: Current: Max: TOrQue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: 5.2 120 MW Change: Mud Loss event: Depth: None Depth: None From: Volume: To: Reason: 9518' Gas Events · Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N None C1 C2 C3 C41 C4N C51 C5N I ~~s r:~ ~~~~o'r) TG I CI I C2 I C3 I ~I I ~N I C51 I C5N I Lithologies: Current: Last 24 hrs: Operational Summary: Ream from 9060' to 9655'. Monitor well, pump out of hole from 9655' to 8010'. Pump hi viscosity sweep. Pull 10 stands. Pump dry job and pull out of hole to 980'. Monitor well. Rack back heavy weight and jars. Lay down BHA, pick up new BHA including hole opener. Run in hole. Calibrations: THA. Failures: None Daily Cost: $2630 · U EPOCH 72 · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: M. Winfree I P.Wilson M. Kuzminskas Date: 4/17/05 Time: 0330 Current Depth (MD): Current Depth (TVD): 24 hr Footage (MD): 11122 10301 o Current Operations: Opening hole. Drilling Parameters No new hole) ROP: Current: Max: TOrQue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: 2.4 120 MW Change: Mud Loss event: Depth: None Depth: None From: Volume: To: Reason: Depth (MDITVD: 9123 · Gas Events Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N None C1 C2 C3 C41 C4N C51 C5N I ~os r~~~ ~~OD~~l TG I C1 I C2 I C3 I C41 I C4N I C51 I C5N I Lithologies: Current: Last 24 hrs: Operational Summary: Continue running into hole. Slip and cut drilling line. Run in hole to 8060'. Deploy hole opener blades. Open hole from 8060' to 9350'. Calibrations: THA. Failures: None Daily Cost: $2630 · ~ EPOCH 73 . ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: M. Winfree I P.Wilson M. Kuzminskas Date: 4/18/05 Time: 0330 Current Depth (MD): 11122 Current Current Depth (TVD): 10301 Operations: Opening hole at 10580' 24 hr Footage (MD): 0 Drilling Parameters No new hole) ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: 2.5 140 MW Change: Mud Loss event: Depth: None Depth: None From: Volume: To: Reason: 10200 . Gas Events Depth (MDITVD) C1 C2 C3 C41 C4N C51 C5N C1 C2 C3 C41 C4N C51 C5N Gas Samples (No new ho e) I N°·1 Depth (MDnw) TG I C1 I C2 I C3 I ~I I ~N I C51 I C5N I Lithologies: Current: Last 24 hrs: Operational Summary: Open hole from 9350' to 9718', packed off four times from 9658' to 9718'. Work pipe and circulate at 9718'. Open hole from 9718' to 10580'. Calibrations: THA. Failures: None Daily Cost: $2630 . [:I EPOCH 74 · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: M. Winfree I P.Wilson D. OWens Date: 4/19/05 Time: 0300 Current Depth (MD): Current Depth (TVD): 24 hr Footage (MD): 11122 10301 o Current Back-ream. Operations: Drilling Parameters No new hole) ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: 2.8 160 MW Change: Mud Loss event: Depth: None From: Depth: 10816'- Volume: 166bbl 11122' To: Reason: Gas Data Ditch Gas: Avg BG : Depth (MDITVD): 10450 · Gas Events Depth (MDrrVO) C1 C2 C3 C41 C4N C51 C5N None C1 C2 C3 C41 C4N C51 C5N Gas Samples (No new hole) No. Depth (MDrrVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Last 24 hrs: Operational Summary: Open hole from 10580' to 11122'. Increase mud weightto 12.5 ppg. Back-ream to 10240'. Stalled top drive-packing off. Work. pipe and rotate. Attempt to regain circulation. Calibrations: THA. Failures: None Daily Cost: $2630 · [:I EPOCH 75 . ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: D. Lutrick / P.Wilson D. Owens Date: 4/2010S Time: 0330 Current Depth (MD): Current Depth (fVD): 24 hr Footage (MD): 11122 10301 o Current Operations: Test BOP equipment. DrillinQ Parameters No new hole) ROP: Current: Max: TorQue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: LaQ: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: 2.6 120 MW Change: Mud Loss event: Depth: None Depth: None From: Volume: To: Reason: 10204 ' . Gas Events Depth (MDITVD) C1 C2 C3 C41 C4N CSI C5N None C1 C2 C3 C41 C4N CSI C5N G S (N hi) as amples o new 0 e No. Depth (MDITVD) TG C1 C2 C3 C41 C4N CSI CSN Lithologies: Current: Last 24 hrs: Operational Summary: Pull out of hole (no rotation) to 1 034S'. Work. pipe to 10360'. Work. packed-off hole from 10360' to 10204'. Circulate, pump high viscosity sweeps. Run in hole and tag fish at 8979'. Pull out of hole to 6784'. Pump dry job. Pull out of hole. Test BOP equipment. Calibrations: THA. Failures: None Daily Cost: $2630 . ~ EPOCH 76 · ConocoPhillips Alaska Inc. Kokoda #5 Daily Report Report for: D. Lutrick I P.Wilson D. OWens Date: 4/21/0S Time: 0200 Current Depth (MD): Current Depth (TVD): 24 hr Footage (MD): 11122 10301 o Current Operations: Pulling out of hole. Drillino Parameters No new hole) ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lao: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: 2.S 120 MW Change: Mud Loss event: Depth: None Depth: None From: Volume: To: Reason: 8380' · Gas Events Depth (MDITVD) C1 C2 C3 C41 C4N CSI CSN None C1 C2 C3 C41 C4N CSI CSN Gas Samples (No new hole) No. Depth (MDfTVD) TG C1 C2 C3 C41 C4N CSI CSN Lithologies: Current: Last 24 hrs: Operational Summary: Test BOP equipment. Pick up fishing tools and drill collars. Run in hole to 801S'. Work on top drive. Break circulation and wash from 801S' to 8943'. Pump sweep and work pipe from 8943' to 8850'. Wash and rotate-top offish at 8983'. Attempt to latch fish 10 times. Back ream out of hole to 8012'. Pull out of hole. Calibrations: THA. Failures: None Daily Cost: $2630 · ~ EPOCH 77 ConocoPhillips Alaska Inc. Kokoda #5 Daily Report . Report for: B Morrison I P Wilson D. Owens Date: 4/23/05 Time: 0200 11122 10301 o Current Operations: Laying down drill pipe. Drilling Parameters (No new hole) ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: 2.6 120 MW Change: Mud Loss event: Depth: None Depth: None From: Volume: To: Reason: Gas Data Ditch Gas: Avg BG: 8424' . Gas Events Depth (MDfTVD) C1 C2 C3 C41 C4N C51 C5N None C1 C2 C3 C41 C4N C51 C5N G S (N hi) as amples o new 0 e No. Depth (MDfTVD) TG C1 C2 C3 C41 C4N C51 C5N I Lithologies: I Current: I . Last 24 hrs: Operational Summary: Pull out of hole. Lay down BHA. Change out and test rams. Rig up 3 %" casing tools. Pick up 3 %" tubing. Slip and cut drilling line, service top drive. Run in hole to 6511', circulate bottoms up. Run in hole to 7996'. Pump from 7996' to 8424', circulate bottoms up. Spot 20 bbl high viscosity pill at 8392'. Circulate bottoms up. Rig up for cementing. Pump 5 bbls water, pressure test lines, pump 46 bbls cement, 2 bbls water and 131 bbls mud. Pull out of hole from 8331' to 7315'. Drop drill i e wi r. Circulate total volume. La down drill i e. I Ca.librations: I THA. Failures: None . Daily Cost: $2010 [~ EPO(~H 78 I , I - I , I II I I I I I I I I I Ethane -45 -40 -35 -30 > -25 -20 § ~ o ;.. ~ ~ ã oS <JJ ~ U ~ ~ = ...¡,.¡ - <JJ "t:S By Leroy Ellis January, 2006 Terra Nova Technologies, LLC 2435 N. Central Expressway, Ste.1200, Richardson, TX 75080 PH: (214) 712-7319, Fax: (214) 712-7301 www.TerraNovaTech.net , , Table of Contents , , o BJECTIV'E ..................................................................................................................................................1 CON CLUSI 0 NS ............................................................................................................................................1 , IN'TR 0 D U CTIO N .........................................................................................................................................2 BACKGROUND ............................................................................................................................................4 I Bacterial Gas Generation...........................................................................................................................4 Thermogenic Gas Generation.....................................................................................................................4 I MATERIALS AND METHODS ..................................................................................................................5 ø SAMPLE BAGS AND SAMPLING ........ ......... ........ ......... ................... .... ......... .......... .... ...... .......... ...... ........... ........ 5 GAS ANALYSIS.. ...... ......................... ........................................ ................... ...... ................... .......... ..................5 Procedure for gas isotope analyses ............................................................................................................ 5 , RESULTS AND D ISCUSSI 0 N .................................................................................................................... 6 , GAS SHOWS AND GAS CONCEN1RATION LEVELS.............................................................................................6 GAS ISOTOPE SHOWS .. .................................. .... ....................... ............. ............ ...... ............ ............................. 7 It SEALS/FIYDROCARBON COMMUNICATION BARRIERS..... ........ ............. .............................. ....... ............... ......... 8 , RESERVOIR COMP ARlMENT ALIZA TION .. ........ ................. ............................. ............... ..... ................................ 8 I NORTH SWPE NATURAL GAS CORRELATION ..................................................................................................8 Kokoda#5 MGIL gases............ ..... ......... .................. ........ ............... ............................ ......... ............... ........ 9 Kokoda#5 vs. Kokoda# 1 MG1L gases.......................................................................................................1 0 Regional Gas Correlation.... ......................... ............ .............. ............... .................. .......... ................. ......1 0 Cretaceous Gas Correlation................. .................. ............... ........ ......... .......... ........... ...... ...... .................10 Jurassic Gas Correlation........ ................. .... ........................ ........ ............. ............................ ....................10 I MIGRATED THERMOGENIC GAS CHARGE AND MATURITY .............................................................................11 Kokoda#5 Gas Maturity ...........................................................................................................................11 I CHARGING HISTORY ........... ......................................................... ....................... ...... ............... ................... ...12 I A CKN 0 WLEDGMENTS ...........................................................................................................................13 REFERENCES ............................................................................................................................................13 I I I I , I I I I , ø , , , - I I I I I I I Confidential MOIL Analysis of ConocoPhillips Kokoda#5 Interpretation and Conclusions 01-17-06 Terra Nova Technologies Dallas, Texas MUD GAS ISOTOPE ANALYSIS OF THE KOKODA#5 WELL, NORTH SLOPE, ALASKA Leroy Ellis January 2006 OBJECTNE Recent advances in sampling and analytical technology have made it possible to analyze the carbon isotopic composition of methane, ethane, and propane from circulating mud gas streams during drilling of a well. Information of this nature can provide short and intermediate term direct benefits to exploration, including detection of missed pay zones, seal evaluation, and complete reservoir evaluation. To evaluate these potential benefits and directly assist in prospect exploration, a study involving geochemical characterization of gases sampled from circulating mud systems during drilling of the Kokoda#5 well (North Slope, Alaska) was undertaken. CONCLUSIONS · Ninety mud gas samples were taken over the Kokoda#5 well bore. Of this total, eighty- seven mud gas samples taken over a 10,570' depth interval (500-11,070') possessed sufficiently high hydrocarbon gas concentrations for isotopic analysis. Twenty-three samples were selected for isotopic analysis on the C2+ components. · Origin of Main Gas Charge (7,000-8,000' MD) - Kokoda#5 gases provided the best match to HRZ-type/Cretaceous(?) gases, however they are significantly different enough to suggest they may possess a second contributor (i.e. mixed gases), or are single-sourced gases not previously recorded. · Main Gas Charge Maturity (7,000-8,000' MD) - If a dominant or single-sourced gas, Kokoda#5 MGIL gases reveal maturities between 0.65-0.75 Ro. Gases at this maturity were derived near peak oil generation and likely to have been originally associated with oil. It is important to remember for any samples considered to represent gas mixes; maturity estimates may not be reliable or accurate. Kokoda#5 gases are slightly less mature than Kokoda#1 gases, suggesting charge may have originated in the direction of Kokoda#1 and migrated towards Kokoda#5 (i.e. invoking a 'fill-spill' model). · Jurassic Charge (9,500-11,070' MD) - End-member JurassiclKingak-type gases identified reveal maturities between 1.05-1.15 Ro. Isotopic and gas compositional data suggest these gases are likely to have been originally associated with oil, recognizing the 1 Terra Nova Technologies, LLC 2435 N. Central Expressway, Ste. 1200, Richardson, TX 75080, PH: (214) 712-7319, Fax: (214) 712-7301 www.TerraNovaTech.net I , , I . , , , , , , , I I , I I IJ I Confidential MOIL Analysis of ConocoPhillips Kokoda#5 Interpretation and Conclusions 01-17-06 source rock for these gases has since moved through the oil window and is presently gas- prone. · Shallow Gas Charge (1,000-3,500' MD) - Evidence of a shallow migrated gas charge can be observed to occur above an effective major geologic seal identified at approx. 3,500-4,500' MD (Figure 2). These particular gases have been not been identified, however similar occurrences elsewhere on the North Slope have usually been identified as high maturity Shublik migrated gas. The maturity of similar Kokoda#1 shallow gases is estimated to be approximately 0.95 Ro, and therefore of higher relative maturity to deeper gas charges. · Seals - Kokoda#5 MGIL data suggest the presence of numerous sealing lithologies and other hydrocarbon communication baffles/barriers. The 'Main Gas Charge' interval appears to be highly compartmentalized as a result. Strong indications of stratigraphic seals are observed at approximate depths 3,500-4,500', 5,700', 6,400-6,500', 6,900- 7,000', 7,900-8,209', 8,800', 9,600-9,800 and 10,240' MD. Additional suspected seals may be observed at 7,200-7,300' and 7,650' MD within the 'Main Gas Charge' interval. Potential barriers to hydrocarbon communication are observed at approximate depths 7,400' and 7,548' MD within the 'Main Gas Charge' interval. · Compartmentalization - Thirteen distinct mixing lines were observed between depths 1,000-11,070' MD. Ten of these mixing lines appear to represent six charged intervals. The 'Main Gas Charge' zone (Charge 3) was identified between 7,000-8,000 MD and appears highly compartmentalized with 5 mixing lines occurring. Hydrocarbons within these depth intervals may be considered to be in poor communication. · Mud gas isotopic analysis has been shown to be an extremely sensitive tool capable of providing important information on highlighting and characterizing pay zones in addition to identifying stratigraphic trapping seals. The technique allows for detailed petroleum system evaluation through isotopic analysis and characterization of all penetrated reservoir zones. INTRODUCTION Carbon isotopic ratios of hydrocarbon gases can be used to differentiate gas families. The isotopic differences can be interpreted in terms of source of the gas (bacterial vs. thermogenic, for example) and in terms of thermal maturity of the thermogenic gases. This is the basis for much of our understanding regarding the origin of hydrocarbon gases in the subsurface. Traditionally, these ratios are measured on gas samples (usually pressurized) collected from producing wells or production tests. Recent development of inn-GCMS (isotope ratio monitoring-gas chromatography mass spectrometry) has permitted analysis of hydrocarbon gases at very low concentrations and in relatively small sample volumes. 2 Terra Nova Technologies, LLC 2435 N. Central Expressway. Ste. 1200, Richardson, TX 75080, PH: (214) 712-7319, Fax: (214) 712-7301 www.TerraNovaTech.net I . I , , I I , , , , , , I I I I I , Confidential MOIL Analysis of ConocoPhillips Kokoda#5 Interpretation and Conclusions 01-17-06 One of the most exciting potential applications of this new technology is the analysis of hydrocarbon gases dissolved in drilling muds. Standard mud gas analysis depends upon measuring both the ratios of various hydrocarbon species and the total amount of hydrocarbon species, to determine if a petroleum accumulation is likely to occur in a particular reservoir interval. The method can result in false positives, where high gas occurs due to changes in drilling conditions, and in false negatives, where petroleum is not recognized due to suppressed gas readings resulting from overbalanced drilling. Isotopic analysis of mud gas hydrocarbons however, offers a method to overcome these difficulties, as measurement of gas carbon isotopes is essentially independent of gas hydrocarbon concentration. Hence, changes in drilling conditions that create errors in recorded total gas concentrations should not affect the measurement of carbon isotopic compositions. Interpretation of an isotopic signal is based on the following premises. These premises are consistent with available data. · There is relatively little isotopic fractionation during sampling of mud gases. This means that the carbon isotopes can be used to distinguish associated gas from both bacterial gas and other unassociated gases in the same way that one can utilize conventional gas samples sampled at the well-head under pressure. · Generally, economic gas accumulations have heavier (less negative) isotopic ratios than gas in uncharged strata. This means that accumulations can be identified as a "heavy carbon" deviation from the background gas isotopic trend. · Background methane isotopic trends in shale are attributed to in situ generation of methane in lean shales, and can be used to calibrate reservoir maturity trends. In situ hydrocarbon gases can therefore be distinguished from gas that has migrated from deeper, more mature sources. The following 'real-event' scenario illustrates potential applications of this technology. A sand has no gas mudlog show, but wireline logs indicate a high resistivity fluid, and a flushed zone. Is this a gas accumulation not detected by mud logs due to overbalanced mud weight, or is it a wireline log interpretation problem due to salinity? If mud gas methane shows a positive isotopic deviation, it may be indicative of an accumulation. In addition to verifying shows, the routine analysis of mud gas may be used for other exploration and research applications. Some examples include: · Identifying bad production tests due to cement bond failure · Vertical proximity indicator for selection of casing points (on-line sampling only) · Identification of active source rocks and thennal maturity · Identification of regional seals and limits to petroleum bearing parts of basins · Potential for down-dip oil prediction · Better calibration of gas isotope thennal maturity 3 Terra Nova Technologies, LLC 2435 N. Central Expressway, Ste. 1200, Richardson, TX 75080, PH: (214) 712-7319, Fax: (214) 712-7301 www.TerraNovaTech.net , , , , t , I , , I - II , I a I I I I Confidential MOIL Analysis of ConocoPhillips Kokoda#5 Interpretation and Conclusions 01-17-06 BACKGROUND - Gas Types Interpreted from MGIL data (Ellis et al., 2003) Geochemists recognize three major gas types in sedimentary basins: bacterial (or biogenic) gas, thennogenic gas, and mixed gas. Mud gas origin is interpreted by the same methods as conventional gas geochemical interpretation. Bacterial Gas Generation Bacterial gas is a product of shallow subsurface metabolism by microorganisms. It can be identified by its isotopically light methane and by the absence or scarcity of higher hydrocarbons. Depleted or 'light' methane isotopic values of -60 %0 or below are usually attributed to bacterial gas sources. Bacterial gases from the marine environment generally have concentrations of methane at 99.9 vol.% (nonnalized), with ethane and higher hydrocarbons at less than 0.1 vol.%. Bacterial gas is pervasive in the shallow subsurface in settings with rapid accumulation rate and moderately high organic carbon concentrations. Since bacterial methane does not fonn readily in deeply buried sedimentary sections, it presence at great depths is generally a consequence of rapid seal development in rapidly subsiding basins (e.g. Northern Italy, Gulf of Mexico). Thennogenic Gas Generation Thennogenic gas is generated from kerogen or petroleum as a result of heating during burial. Thennogenic hydrocarbon gases typically exhibit 'heavier' carbon isotopic values than bacterial gases and the fraction of heavier hydrocarbons is much greater. In general, the carbon isotopic ratio of methane in thennogenic gas ranges from -20 to -60 %0, and the percent of heavy hydrocarbons relative to total hydrocarbons is up to 50% or more. Two factors control the isotopic composition, the isotopic composition of the starting material, and the temperature at which the gas is generated. Heavier (less negative) carbon isotopic ratios indicate generation in the gas window or generation from coals, whereas lighter carbon isotopic ratios indicate generation in the oil window from marine kerogen. At very low thennal maturity, thennogenic gas may be compositionally and isotopically similar to bacterial gases. Considering the ethane and propane carbon isotopic ratios in addition to the methane carbon can differentiate the source and maturity effects. Gases migrate in the subsurface, so gases of different origin commonly mix. Bacterial gas in deeper basin settings is commonly mixed with a small component of thennogenic gas that raises the gas wetness while maintaining relatively light carbon in the methane. The intennediate compositional and isotopic character of this gas is often hard to differentiate from early thennogenic gases. 4 Terra Nova Technologies, LLC 2435 N. Central Expressway, Ste. 1200, Richardson, TX 75080, PH: (214) 712-7319, Fax: (214) 712-7301 www.TerraNovaTech.net . . I , I I J , , , ø , , I I I I I I Confidential MOIL Analysis of ConocoPhillips Kokoda#5 Interpretation and Conclusions 01-17-06 MATERIALS AND METHODS Sample bags and sampling: Cali-5-bond (Calibrated Instruments Ltd., NY) aluminum- lined I-liter bags were used to collect hydrocarbon gases drawn from the mud pit. An approximate sampling interval of one bag every 150' was used to provide data for establishing a background trend. During 'shows' where elevated gas signatures were to be recorded on the total gas analyzer located in the mudlogging unit, an approximate sampling interval of 1 bag every 10 feet was suggested. Sample bags were filled ~ to % capacity in order to minimize problems associated with overfilling and rupturing of the sample bags. It must be noted that the mudgas technique will show slightly enriched methane compositional values at a level 1 to 2 vol. % (normalized) greater than those obtained from MDT/RFT tests. This is attributed to methane being inherently more mobile, and therefore likely to disperse faster in the mud system relative to heavier ethane and higher gas components. Studies have shown that the ethane and higher gas components are not substantially discriminated against during dissolution in the mud system (L.Ellis, unpublished data). The methane enrichments are small and show mudgas data to be quite robust and accurate in comparison to RFT/MDT test data. Gas Analysis: Table 1 lists data and details of the gas samples collected. Normal detection limits (where 1 vol.% = 10,000 ppm) associated with isotopic analyses of methane, ethane and propane were 0.12,0.06 and 0.04 vol. % respectively. All data were acquired at an analytical precision and accuracy of ± 0.3 %0. Method used for the isotopic analyses of the mud gases are outlined below. Samples that contained low concentrations of hydrocarbon gases required an enrichment technique, effectively permitting isotopic measurement on samples down to 0.08, 0.04 and 0.03 vol. % for methane, ethane and propane respectively. All data were acquired at an analytical precision and accuracy of ± 0.2 %0. Methods used for the isotopic analyses of the mud gases are outlined below. Procedure for gas isotope analyses For determination of the Ô13C of a methane, ethane or propane gas component, the GC- IRMS technique is utilized. This procedure couples a gas chromatograph (GC) to a combustion interface (C) and an isotope ratio mass spectrometer (IRMS). The component of interest must first be separated from other gases in the sample by injecting the GC with enough sample to yield a substantial peak on the IRMS. Solenoid valves on the outlet of the GC column either vent the GC carrier stream or channel it through a combustion furnace. The component of interest is passed through the furnace, where it is oxidized to CO2 and H20 combustion products. The C02 and H20 are then passed through an interface where the H20 is removed, and the CO2 continues into the IRMS where the isotopic value is measured. The IRMS produces reliable data within a predetermined sample signal range, and on! y samples that can produce an appropriate size signal are analyzed or reported. A minimum of 20% of all analyses on the IRMS are QAQC samples, either as duplicate sample analyses or analysis of laboratory reference gases. 5 Terra Nova Technologies, LLC 2435 N. Central Expressway, Ste. 1200, Richardson, TX 75080, PH: (214) 712-7319, Fax: (214) 712-7301 www.TecraNovaTech.net I I I I I I J I I I I I , I I I I I t Confidential MGIL Analysis of ConocoPhillips Kokoda#5 Interpretation and Conclusions 01-17-06 RESULTS AND DISCUSSION Gas shows and I!as concentration levels General trend: Laboratory measured gas concentrations from the sample bags were compared to the recorded gas units determined by the total gas analyzer at the time of sampling. Mud log measured total gas response is proportional to the GC measured total hydrocarbon gases (Table 1). The strongest gas shows recorded were represented by Kokoda#5 depth intervals 6,710', 7,613', 8,676', 1O,036'and 10,940' MD (Table 2, Figure 3). It is important to note, mud gas recorded gas concentrations are not solely attributed to show strength, and may represent the interplay between a variety of factors, namely, drilling conditions related to mud weight or surface air dilution at the mud return receiving tank (i.e. possum belly). Figure 1 shows a plot of ethane/methane ratio with depth. Significant C2/C 1 ratios suggestive of potential thermogenic hydrocarbon charged zones are observed at measured depths; Table 2. Kokoda#S weD gas shows Sample Depth Formation Gas Show C2/C1 *Gas Type (MD) (vol. %) Ratio (Gas assessment only!) 1,500-2,000' 1.3 0.01 Unknown 5,000' 1.0 0.01 Unknown 6,710' 5.4 0.12 > Cretaceous-type input or mixed gas (+Jurassic) 7,131' 2.4 0.10 > Cretaceous-type input or mixed gas (+Jurassic) 7,372' 2.1 0.09 > Cretaceous-type input or mixed gas (+Jurassic) 7,613' 24.9 0.10 > Cretaceous-type input or mixed gas (+Jurassic) 8,676' 5.1 0.14 > Cretaceous-type input or mixed gas (+Jurassic) 10,036' 13.3 0.15 JurassiclKingak-type input 10,940' 5.8 0.07 JurassiclKingak-type input Notes: *, any associated oil source not examined Note* - Well logs should be used to verify if any potential reservoir sands exist at these depths. 6 Terra Nova Technologies, LLC 2435 N. Central Expressway, Ste. 1200, Richardson, TX 75080, PH: (214) 712-7319, Fax: (214) 712-7301 www.TerraNovaTech.net I I I I I I I , I I I I I I I Confidential MOIL Analysis of ConocoPhillips Kokoda#5 Interpretation and Conclusions 01-17-06 Bacterial and thermogenic gas cannot be accurately characterized from methane gas concentrations alone, indeed, mixed gas zones may be especially difficult to interpret. Zones showing a clear thermogenic gas contribution however, can be inferred from an increase in concentration of heavier gas components such as ethane. Bacterial gas will be characterized by lower ethane/methane ratios (typically <0.01 C2/Cl), whereas thermogenic gas is characterized by higher ethane/methane ratios (typically >0.10 C2/Cl). Note* - Low total gas concentrations (TG) may result in erroneous and anomalous C2/Cl ratios. Correlation of any high C2/Cl ratios, or in fact low or absent C2/Cl ratios, with corresponding gas isotopic ratios, will assist in determining which zones of interest may actually be of real or potential significance. Gas isotope shows General trend: Isotope analyses were compared to gas composition data in an effort to determine whether the samples were either taken from intervals falling on background mud gas concentration, intervals with elevated background, or intervals with shows (Figures 2 and 3). Some background total gas concentrations have significantly heavier methane carbon isotopes than surrounding intervals. These are referred to as background isotopic shows. The background isotopic trend results when both conventional (isotopic shows in association with elevated gas shows) and isotopic shows (no associated elevated gas concentrations) are removed. For Kokoda#5, the identification of geologic seals results in multiple background isotopic trends (Figure 2). Typically, the deeper trends may be the result of Raleigh fractionation of carbon from C02 during methanogenesis, as described in ODP literature (e.g. Berner et al., 1992; cf. Ellis, L. 2000-2005 reference list), however in the case of Kokoda#5 multiple hydrocarbon charge events are also a factor. Figure 2 shows a plot of interpolated 13C methane isotopic signature with measured depth (MD). A number of isotopic deviations from the background are apparent, and which indicate potential migrated thermogenic gas/oil charging. Significant isotopic deviations from the background trend are recognized at approximate depths 1,000-4,000', 6,600-6,900', 7,100-7,900' (Main Gas Charge) and 9,930-11,070' MD. The identification of shallow elevated isotopic signals observed above the identified geologic seal at 3,500- 4,500' MD may indicate the presence of stratigraphic conduits linked to deeper, more mature sources (i.e. mature gas migration to shallower stratigraphic horizons). - I Figure 3 shows a plot of % Cl to C6 hydrocarbons and 13C methane isotopic profile measured from sample bags. Comparison of these plot types allows reservoirs charged with migrated thermogenic gas to be identified even against an absence of a significant gas show. Compositional plot (blue) represents interpolated logs taken from a background-sampling interval of approximately every 100'. Strong gas shows at depth 6,710', 7,131', 7,372', 7,470-8,100' and 10,940' MD are associated with isotopic shows - 7 Terra Nova Technologies, LLC 2435 N. Central Expressway, Ste. 1200, Richardson, TX 75080, PH: (214) 712-7319, Fax: (214) 712-7301 www.TerraNovaTech.net I . I I I I I , , , , , , I , I , , , Confidential MOIL Analysis of ConocoPhilIips Kokoda#5 Interpretation and Conclusions 01-17-06 above background, which together with an elevated C2/Cl ratio suggests these intervals may be charged with migrated thermogenic hydrocarbons (i.e. gas and/or oil). *Welllogs should be used to verify if any potential reservoir sands exist at these depths associated with strong gas shows, and also for any indications of migrated thermogenic gas/oil charging. Seals/ Hvdrocarbon Communication barriers Identification of seals is also important in establishing potential migration pathways and compartmentalization. Reservoir sands within identified particular regional seals are likely to contain hydrocarbons of the same type and maturity. Isotopic data reveal migrated gas charging both above and below identified geologic seals (Figure 2). Kokoda#5 MGIL data suggest the presence of numerous sealing lithologies and other hydrocarbon communication baffles/barriers. The 'Main Gas Charge' interval appears to be highly compartmentalized. Seals - Strong indications of stratigraphic seals are observed at approximate depths 3,500-4,500', 5,700', 6,400-6,500', 6,900-7,000', 7,900-8,209', 8,800', 9,600- 9,800' and 10,240' MD. Additional suspected seals may be observed at 7,200-7,300' and 7,650' MD within the 'Main Gas Charge' interval. Baffle/Barriers - Potential barriers to hydrocarbon communication are observed at approximate depths 7,400' and 7,548' MD within the 'Main Gas Charge' interval. Reservoir Compartmentalization Figure 4 shows a plot of methane % vs. del 13C of methane for Kokoda#5 samples. On these plots, straight lines represent 'mixing lines', with 13 distinct mixing lines observed between depths 1,000-11,070' MD (Note. this assumes no significant changes in drilling conditions at the time of sampling). Ten mixing lines appear to represent six charged intervals, the depth range of each line considered to reflect or suggest good hydrocarbon communication. The 'Main Gas Charge' zone (Charge 3) was identified between 7,000- 8,000' MD and appears highly compartmentalized with 5 mixing lines occurring. Shallow Mi¡µ-ated Gas Charge 1 (1.000-3.500' MD) - Gas samples above an identified regional seal at 3,500-4,500' MD reveal 'heavier' isotopic data suggesting the presence of mature migrated thermogenic gas. Gas Charge 2 (6.600-6.900' MD) - Comparison of isotopic data and associated 'mixing lines' suggest gas samples above a suggested seal at 6,900-7,000' MD appear related to the same charge event. 8 Terra Nova Technologies, LLC 2435 N. Central Expressway, Ste. 1200, Richardson, TX 75080, PH: (214) 712-7319, Fax: (214) 712-7301 www.TerraNovaTech.net I I I I I I I , , , , f , I I I I , Confidential MGIL Analysis of ConocoPhillips Kokoda#5 Interpretation and Conclusions 01-17-06 'Main Gas Charge' 3a,b,c1-3 (7.000-8.000' MD) - Comparison of isotopic data and associated 'mixing lines' suggest gas samples above a suggested baffle/barrier at 7,900-8,209' MD appear related to the same charge event. Gases in this depth interval are highly compartmentalized and also appear to be substantially 'diffused' resulting in a blended signal throughout adjoining lithologies. Gas Charge 4 (8,209-8,800' MD) - Comparison of isotopic data and associated 'mixing lines' suggest gas samples below a suggested baffle/barrier at 7,900-8,209' MD appear related to the same charge event. Gas Charges 5 and 6 (9.930-11.070' MD) - Comparison of isotopic data and associated 'mixing lines' suggest gas samples below a suggested baffle/barrier at 9,600-9,800' MD appear related to the same charge event. Mixing lines are defined by data points falling along a straight plotted line, suggesting a depth section in the well that is in good gas communication, and therefore representative of a 'compartment'. Breaks in any of the mixing lines identify approximate depth locations at which lithological barriers to communication may in fact be present. These compartments are plotted on Figure 3 against gas and isotopic depth prof1les. It is important to keep in mind, however, that drilling conditions such as changes in ROP, or an increase in mud weight will also affect the mixing lines resulting in breaks. The compartmentalization boundaries identified at these depths are suggested to represent communication barriers, and may simply indicate a restricted hydrocarbon communication zone, rather than a non-communicating seal. North Slope Natural Gas Correlation Figures 5 and 6 show regional characterization of Kokoda#5 mud gas isotopes to a selected range of relevant North Slope natural gases (incl. Kokoda#I). Figure 5a plots all Kokoda#5 sampled mud gases in which extended isotopic ratios were acquired (n=15, Table 1). Kokoda#5 MGIL gases - Fifteen selected mud gas samples collected over four depth intervals between 2000-10940' MD showed significant variability in constructed carbon isotopic natural gas prof1les (Fig. 5A). Examination of the isotopic trends suggested four broad prof1les/data indicative of four charge events occurring at depthls 2,000', 5,000', 6,710-8,676' and 9,500- 10,940' MD. Gases collected from the 'Main Gas Charge' 6,710-8,676' MD interval revealed additional subtle differences in 'parallel' slope characteristics that apart from maturity variations, also suggests separate charge and lithological/reservoir influences (see Fig. 6A). - 9 Terra Nova Technologies, LLC 2435 N. Central Expressway, Ste. 1200, Richardson, TX 75080, PH: (214) 712-7319, Fax: (214) 712-7301 www.TerraNovaTech.net I I I I I I , I , IJ , f , , II - IJ I - Confidential MOIL Analysis of ConocoPhillips Kokoda#5 Interpretation and Conclusions 01-17-06 Kokoda#S vs. Kokoda#l MGIL gases - Kokoda#l gases are generally more mature than Kokoda#5 gases (Fig. 5B). These data suggest charge may have originated in the direction of Kokoda#l and migrated towards Kokoda#5 (i.e. invoking a 'fill-spill' model). Selected mud gas samples from the 'Main Gas Charge' depth interval in Kokoda#5 (n=9, 6,710-8,676' MD) and Kokoda#l (n=6, 6,832-7,600' MD) revealed two distinct slopes in constructed carbon isotopic natural gas profiles (Fig. 6A). While one sample set showed the expected slope profiles in which each heavier gas (methane, ethane, propane etc.) also possessed an increasingly heavier carbon isotope value (i.e. less negative), the other sample set revealed an unusual 'flattened' slope pattern. It is unclear whether this is the result of an anomalously heavy carbon isotope signature for propane gases or an anomalously 'light' carbon isotope signature for butane gases? In two gases exhibiting 'flattened profiles' where pentane data are available (6,710' & 7,528' MD), trends would suggest it is the butane data that possesses an anomalously light carbon isotope signature. Lithological variations in alternating source/reservoir intervals may provide insight into accounting for these observations? Regional Gas Correlation - Kokoda#5 mud gases revealed no direct correlation with any typical end-member Shublik, Kingak or HRZ North Slope gas type (Fig. 6B). End-member Kingak-type/Jurassic(?) gases provided the closest match, especially with the deepest gases sampled below 10,000' MD. Cretaceous Gas Correlation - Comparison of Kokoda#5 gases together with end- member HRZ gas types permit some comparisons of slope profiles. Kokoda#5 gases from the 'Main Gas Charge' interval (7,000-8,000' MD) appear to reveal carbon isotope trends more in favor of Cretaceous gases (e.g. similar to HRZ gas types), especially for the heavier 'wetter' gas components (C3+). It is important to note however, that they are significantly different enough to suggest they may possess a second contributor (i.e. mixed gases), or are indeed single-source gases not previously recorded. Jurassic Gas Correlation - Comparison of Kokoda#5 gases together with end-member Kingak gas types permit some comparisons of slope profiles. Kokoda#5 gases from the deeper charge interval (below 9,500' MD) appear to reveal carbon isotope trends more in favor of Jurassic gases (e.g. similar to Kingak gas types), especially for the heavier 'wetter' gas componentsn(C3+ ). 10 Terra Nova Technologies, LLC 2435 N. Central Expressway, Ste. 1200, Richardson, TX 75080, PH: (214) 712-7319, Fax: (214) 712-7301 www.TerraNovaTech.net I . I , I I , I I I - If I I I I It I I Confidential MGIL Analysis of ConocoPhillips Kokoda#5 Interpretation and Conclusions 01-17-06 Mie:rated thermoe:enic e:as chare:e and maturity For sampled mud gases in which isotope values for the methane, ethane and propane gas components are available, approximate gas maturities and bacterial gas contributions can be derived. Figure 7 shows a maturity plot that allows for a qualitative determination of these unknowns. Two isotopic variables (methane and propane) are plotted on the Y- axis, while ethane isotopic values are plotted on the X-axis for the same sample. Two data points will therefore result for each sample plotted, with one data point representing methane against ethane, and the other, propane against ethane (note: only methane and ethane data were available, hence no propane data plotted). For gases with no bacterial contributions, both points plotted should fall on each of the respective two slopes (highlighted in yellow and blue) that represent thermogenic gas maturation profiles (i.e. kinetic isotope effect). Since bacterial gas contributes mostly isotopically light methane, any methane/ethane data point deviating off the methane gas maturation slope (yellow slope) will indicate samples for which a bacterial component is evident. The degree by which the data points moves off the slope, will directly reflect increasing bacterial gas contributions. Figure 7 shows a maturity comparison of Kokoda#5 sampled gases. Note, these maturity estimates may be compromised if the Kokoda#5 sampled gases are in fact mixed gases. It is important to remember that these inferred maturity variations for each respective sample may simply result from changes in the bulk compositional concentrations of the different contributors. In essence, gas mixes may not provide reliable or accurate maturity assessments! Kokoda#S Gas Maturity Charge 1 (5.000' MD) - This gas sample does not plot on the maturity template, suggesting a very low level of maturity. This gas is suggested to be originally derived from an immature source rock at less than. 0.50 Ro maturity equivalent. Ethane isotopic data appears to be compromised by the addition/input of isotopically light biogenic gas. Gas Charges 2 (6.600-6.900' MD) & 4 (8.209-8.800' MD) - These gas samples originate directly above and below the 'Main Gas Charge'. These gases are suggested to be originally derived near peak oil generation from a source rock at approx. 0.75 Ro maturity equivalent. Isotopic and gas compositional data suggest these gases are likely to have been originally associated with oil. It is interesting to note the shallower interval (Gas Charge 2) appears more mature than the deeper 'Main Gas Charge' (Gas Charge 3). 'Main Gas Charge' 3A-C3 0.000-8.000' MD) - These gases are suggested to be originally derived near peak oil generation from a source rock at approx. 0.65- 0.70 Ro maturity equivalent. Isotopic and gas compositional data suggest these gases are likely to have been originally associated with oil. 11 Terra Nova Technologies, LLC 2435 N. Central Expressway, Ste. 1200, Richardson, TX 75080, PH: (214) 712-7319, Fax: (214) 712-7301 www.TerraNovaTech.net I I I I I I I I , , , , t , , , , , - Confidential MGIL Analysis of ConocoPhiIlips Kokoda#5 Interpretation and Conclusions 01-17-06 Kokoda#5 9.500' MD - gas is suggested to be originally derived just beyond peak oil generation from a source rock at approx. 0.95 Ro maturity equivalent. Isotopic and gas compositional data suggest these gases are likely to have been originally associated with oil. Gas Charge 5 (9.930-10.420' MD) & 6 00.550-11.070' MD) -These gases are suggested to be originally derived in the late oil window from a source rock at approx. 1.05-1.15 Ro maturity equivalent. Isotopic and gas compositional data suggest these gases are likely to have been originally associated with oil, recognizing the source rock for these gases has since moved through the oil window and is presently gas-prone. Biogenic gas contributions to Kokoda#5 MGIL sampled gases are also evident and range between 15% and 50%. The biogenic component to these gases may result from in-situ gas absorption into undersaturated migrating thermogenic gas/oil, or could indicate some degree of bacterial activity (i.e. limited biodegradation). Charl!Îne: Historv The Kokoda#5 well reveals at least four distinct charge events, the 'Main Gas Charge' occurring between 7,000-8,000' MD and reflecting a significant HRZ-type/Cretaceous(?) contributor or single-sourced gas not previously reported. Of particular interest, numerous major seals were identified that appear to control and constrain the hydrocarbon petroleum system in this well. Migrated gas charging can be observed to occur both above and below the major geologic seals identified (Figure 2). Gases below 5,700' MD have been identified as predominantly HRZ-type/Cretaceous (?) (between 0.65 to 0.75 Ro eqv.) migrated gas. The deeper gases below 9,500' MD have been identified as predominantly Kingak-type/Jurassic (?) (between 1.05 to 1.15 Ro eqv.) migrated gas. There also exists a shallower charge mainly restricted to a 1,000-3,000' MD interval. Insufficient gas concentrations of higher gas homologs (i.e. ethane, propane etc.) from the shallower gas charge prohibited extended isotopic analysis of these components. 12 Terra Nova Technologies, LLC 2435 N. Central Expressway, Ste. 1200, Richardson, TX 75080, PH: (214) 712-7319, Fax: (214) 712-7301 www.TerraNovaTech.net , , I , , , , , I , , , - I - I , - I Confidential MOIL Analysis of ConocoPhillips Kokoda#5 Interpretation and Conclusions 01-17-06 Acknowledl!Jl1.ents Greg Wilson and Albert Holba (ConocoPhillips, Alaska) were responsible for commissioning the study and providing helpful assistance in the interpretation of the geological environment through which this well was drilled. The author would like to thank Greg and Albert for their confidence and support in utilizing the MGIL technique. References Ellis, L. (2005) MGIL Analysis of the ConocoPhillips Kokoda#1 Well, North Slope, Alaska. Terra Nova Technologies, June 2005. Ellis, L. (2004) Mud Gas Isotope Analysis of the ConocoPhillips Spark#4 Well, North Slope, Alaska. Terra Nova Technologies, November 2004. Ellis, L. (2004) Mud Gas Isotope Analysis of the ConocoPhillips Carbon#1 Well, North Slope, Alaska. Terra Nova Technologies, November 2004. Ellis, L. (2004) Mud Gas Isotope Analysis of the ConocoPhillips Scout#1 Well, North Slope, Alaska. Terra Nova Technologies, November 2004. Ellis, L. (2004) MGIL maximizes value of mud logging. Special Report: Drilling Technology, American Oil & Gas Reporter, April, 127-131. Ellis, L., Brown, A., Schoell, M and Uchytil, S. (2003) Mud gas isotope logging (MGIL) assists in oil and gas drilling operations. Oil & Gas Journal, May 26. Ellis, L. (2003) Mud Gas Isotope Analysis of the ConocoPhillips Grizzly#1 Well, North Slope, Alaska. Terra Nova Technologies, April 2003. Ellis, L. (2003) Mud Gas Isotope Analysis of the ConocoPhillips Heavenly#1 Well, North Slope, Alaska. Terra Nova Technologies, April 2003. Ellis, L. (2002) Mud Gas Isotope Analysis of the ConocoPhillips Kokoda#5 Well, North Slope, Alaska. Terra Nova Technologies, November 2002. Ellis, L. (2002) Mud Gas Isotope Analysis of the ConocoPhillips Mitre#1 Well, North Slope, Alaska. Terra Nova Technologies, November 2002. Ellis, L. (2002) Mud Gas Isotope Analysis of the Phillips Meltwater 2P-415 Well, North Slope, Alaska. Terra Nova Technologies, July 2002. Ellis, L. (2001) Mud Gas Isotope Analysis of the Nigliq#lA Well, North Slope, Alaska. Terra Nova Technologies, December 2001. 13 Terra Nova Technologies, LLC 2435 N. Central Expressway, Ste. 1200, Richardson, TX 75080, PH: (214) 712-7319, Fax: (214) 712-7301 www.TerraNovaTech.net I I I , I I I I , I I I I I I I Confidential MGIL Analysis of ConocoPhillips Kokoda#5 Interpretation and Conclusions 01-17-06 Ellis, L. (2001) Mud Gas Isotope Analysis of the Rendezvous#2, Lookout#1 and Mooses Tooth C Wells, North Slope, Alaska. Terra Nova Technologies, November 2001. Ellis, L. (2001) Mud Gas Isotope Analysis of the Nanuq#3, Nigliq#1 and Nigliq#IA Wells, North Slope, Alaska. Terra Nova Technologies, October 2001. I - Gas Correlations Ellis, L. (2001) Mud Gas Isotope Analysis of the Atlas#1 and Atlas#IA Wells, North Slope, Alaska. Terra Nova Technologies, July 2001. Ellis, L. (2001) Mud Gas Isotope Analysis of the Nanuk#2 Well, North Slope, Alaska. Terra Nova Technologies, May 2001. Ellis, L. (2001) Mud Gas Isotope Analysis of the Phillips Clover A Well, North Slope, Alaska. Terra Nova Technologies, January 2001. Ellis, L. (2000) Geochemical Assessment of the Sources of North Slope Gas Seeps, Alaska. Terra Nova Technologies, December 2000. Ellis, L. (2000) Mud Gas Isotope Analysis of the Meltwater North#l, #2 and #2A Wells, North Slope, Alaska. Terra Nova Technologies, November 2000. Ellis, L. (2000) Mud Gas Isotope Analysis of the Phillips Spark#1 and Rendezvous#1 Wells, North Slope, Alaska. Terra Nova Technologies, September 2000. Ellis, L. (2000) Mud Gas Isotope Analysis of the West Gwyder#1 Well, North Slope, Alaska. Terra Nova Technologies, July 2000. Berner, D., von Breymann, M.T., Faber, E. and Bertrand, Ph. (1992) Gas Geochemistry of ODP sites 767 and 768, Celebes and Sulu Seas. In Bacterial Gas (ed. R. ViaIly). Editions Technip, Paris pp. 147-156. -- - ~ 14 Terra Nova Technologies, LLC 2435 N. Central Expressway, Ste. 1200, Richardson, TX 75080, PH: (214) 712-7319, Fax: (214) 712-7301 www.TerraNovaTech.net , , , , I , , It I It I I I I I I I 500 J 1000 1500 2000 2500 IJJ !).) () 3000 cã" a 3500 c: ::;¡ Q. 4000 4500 ,-.... 5000 Q ~ 5500 er-- 6000 t:: .........." £ 6500 ~ ~ Q 8500 9000 9500 10000 10500 11000 0.00 0.15 0.20 0.25 0.05 0.10 EthanelMethane (C2/Cl) Figure 1. Variations of ethane/methane ratio with depth. Bacterial gas is characterized by lower ethane/methane ratios (C2/Cl values typically <0.01) whereas thermogenic gas is characterized by higher ethane/methane ratios (C2/Cl values typically >0.10). , , I , I I , ,,-.... , Q ~ <II'> I 4: '-' £ I ~ Q# Q , I I J I J I I I 500 1000 1500 2000 2500 3000 5000 5500 6000 6500 8500 9000 9500 10000 I'///////~ Seal -65 -63 -61 -59 -57 -55 -53 -51 -49 -47 -45 -43 13C1 per mil Figure 2. Plot of interpolated 13C methane isotopic signature with depth. Significant isotopic deviations from background indicate potential migrated thermogenic gas/oil charging. Identification of seals is also important in establishing potential migration pathways and compartmentalization. Reservoir sands within identified particular regional seals are likely to contain hydrocarbons of the same type and maturity. Main Charge 7,000-8,000' MD - A number of potential communication barrierslbaffles and sealing lithologies appear to be present in this depth interval at approximate depths 7,200-300', 7,400" 7,548' and 7,650' MD (see Fig 4.). , , , I I , ~ , ~ ~ '" ~ I '-" ;3 Q.q I ~ ~ , I I J , I I I MGlL (13C1) MGIL (%HC) 8 ComDartmentalization 1000-3500 ':::'::G) . 0 !Þ 0 3D. -. n ~. 0 cS~B -. C ::;, ::;, m ñ' 4500-5700 -1:1) - õ' ::;, g /5900-6300 / m /6600-6900 I 18209-8800 I [8900-9600 Figure 3. Plot of % Cl to C6 hydrocarbons and 13C methane isotopic profile measured from sample bags. Comparison of these plot types allows reservoirs charged with migrated thermogenic gas to be identified even against an absence of a significant gas show. Plot represents interpolated logs taken from a background-sampling interval of approximately every 100' and a reservoir sampling interval of approximately every 5-20'. I , I , I I ,u~ ~ I I I I I I I I I o o .,.... 10000 Q3000 00 1500 2500 o 2000 Methane Mixing Lines ComDartments (HC Communicatina Zones) o Cb 1000 - 3500 CHARGE 1 4500 - 5700 5900 - 6300 6600 - 6900 CHARGE 2 00 6300 6400~ 6600~ 6 00 6500 Yi0790940 ': 8209 - 8800 CHARGE 4 8900 - 9600 9930 - 10420 CHARGE 5 10550 - 11070 CHARGE 6 Seals or Poor Communicatina Zones 10420 3500 - 4500 (Seal) 5700 (Seal) 6400 - 6500 (Seal) 6900 -7000 (Seal) o 7200 - 7300 (Seal?) 7400 (Baffle/Barrier) 7548 (Baffle/Barrier) 7650 (Seal?) 7900 - 8209 (Seal) 8800 (Seal) 9600-9800 (Seal) 10420 (Seal) d) 6750 6740 9600 6800 Notes Seal = No significant HC communication o Barrier = Restricted HC communication CO -64 -44 -40 -60 -56 -52 -48 t3Ct per mil Figure 4. Plot of methane % vs. del13C of methane for Kokoda#5 samples. On these plots, connected straight or sloped lines represent 'mixing lines', with 13 distinct mixing lines observed between depths 1,000 - 11,070' MD (Note. this assumes no significant changes in drilling conditions at the time of sampling). The depth range of each line is considered to reflect or suggest good hydrocarbon communication. Charge Zone = shows sampling depths suggesting presence of migrated hydrocarbons. Data shoes hydrocarbons get isotopically heavier and 'drier' (i.e. greater methane composition) with depth. Main charged zone reveals the presence of multiple communication barriers. ~~~~~~~~~~~~~~~~~~~ C5 C4 C3 I I I C2 I C1 I -24 -29 ¡,., ~ -44 Kokoda#5 (A) AU MGll Gases -34 -39 ¡,., ~ -44 -@- Kokoda#5 2000' MD -<>- Kokoda#5 5000' MD -Ir- Kokoda#5 6710' MD -+- Kokoda#5 6750' MD -T- Kokoda#5 7131' MD -f- Kokoda#5 7528' MD -J<- Kokoda#5 7588' MD -iJ- Kokoda#5 7700' MD -&- Kokoda#57800' MD -&- Kokoda#5 8400' MO - Kokoda#5 8676' MD -@- Kokoda#5 9500' MD -@- Kokoda#5 10036' MD -k- Kokoda#510810' MD -{J- Kokoda#510940' MD -49 -54 -59 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1.0 1/Carbon number Figure 5. Characterization of mud gas isotopes recorded from Kokoda#5. C5 C4 C3 I I I C2 I C1 I -24 -29 Kokoda#5 (8) -34 Kokoda#1 2000' MD Kokoda#1 4903' MD Kokoda#1 6832' MD Kokoda#1 6866' MD Kokoda#1 7240' MD + Kokoda#1 7450' MD Kokoda#1 7540' MD Kokoda#1 7800' MD -+- Kokoda#5 2000' MD -II- Kokoda#5 5000' MD -Ir- Kokoda#5 6710' MD -+- Kokoda#5 6750' MD -49 -T- Kokoda#5 7131' MD -f- Kokoda#5 7528' MD -J<- Kokoda#5 7588' MD -iJ- Kokoda#5 7700' MD -&- Kokoda#5 7800' MD -54 -@- Kokoda#5 8400' MD - Kokoda#5 8676' MD -@- Kokoda#5 9500' MD -+- Kokoda#5 10036' MD -+- Kokoda#5 10810' MD -{J- Kokoda#5 10840' MD -59 0.2 -39 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1 1/Carbon number (A) Fifteen selected mud gas samples collected over four depth intervals between 2000-10940' MD showed significant variability in constructed carbon isotopic natural gas profiles. Examination of the isotopic trends suggested four broad profiles/data indicative of four charge events occurring at depthls 2000',5000',6710-8676' and 9500-10940' MD. Gases collected from the latter two 'deeper' sampled depth intervals revealed additional subtle differences in 'parallel' slope characteristics that apart from maturity variations, also suggests separate charge and lithological/reservoir influences (see Fig. 6A). (B) Kokoda#l gases are generally more mature than Kokoda#5 gases. These data suggest charge may have originated in the direction of Kokoda#l and migrated towards Kokoda#5 (i.e. invoking a 'fill-spill' model). Terra Nova Technologies WI .. WI WI .. ... .. .. .. .. ... .. .. .. .. .. ... C5 C4 C3 C2 C5 C4 C3 C2 I I I I I I I I -28 -25 Kokoda#5 -29 (8) ys. Main North Slope Kokoda#5 -27 Gas Types -30 (A) Ys. Kokoda#1 -29 (Expanded from Fig 58) -31 -31 ¡,.. ¡,.. -33 (D -32 (D c. c. -35 -33 -37 -- Kokodatl5 2000' MD Kokodatl5 5000' MD -34 Kokodatl5 6710' MD Kokodatl5 6750' MD -39 - Kokodatl5 7131' MD -t-- Kokodatl5 7528' MD -- Kokodat15 7588' MD ---a- Kokodatl5 7700' MD -35 - Kokodatl57800' MD Kokoda#1 7240' MD -41 -- Kokoda#5 8400' MD - Kokoda#5 8676' MD Kokoda#1 7450' MD - Kokoda#5 9500' MD Kokoda#1 7540' MD Kokoda#510036' MD Kokoda#1 7600' MD Kokodatl5 10810' MD Kokoda#5 10940' MD -36 -43 0.2 0.3 0.4 0.5 0.2 0.3 0.4 0.5 1/Carbon number 1/Carbon number Figure 6. Characterization of mud gas isotopes recorded from Kokoda#5 to Kokoda#l and a selected range of relevant North Slope natural gases. (A) Selected mud gas samples from the 'main charge' depth intervals in Kokoda#5 (n=9, 6710-8676' MD) and Kokoda#l (n=6, 6832-7600' MD) revealed two distinct slopes in constructed carbon isotopic natural gas profiles. While one sample set showed the expected slope profiles in which each heavier gas (methane, ethane, propane etc.) also possessed an increasingly heavier carbon isotope value (i.e. less negative), the other sample set revealed an unusual 'flattened' slope pattern. It is unclear whether this is the result of an anomalously heavy carbon isotope signature for propane gases or an anomalously 'light' carbon isotope signature for butane gases? In two gases exhibiting 'flattened profiles' where pentane data are available (6,710' & 7,528' MD), trends would suggest it is the butane data that possesses an anomalously light carbon isotope signature. Lithological variations in alternating source/reservoir intervals may provide insight in accounting for these observations? (B) Kokoda#5 mud gases revealed no direct correlation with any typical end-member Shublik, .Kingak or HRZ North Slope gas type. End-member .Kingak-type/Jurassic(?) gases provided the closest match, especially with the deepest gases sampled below 10000' MD. Terra Nova Technologies .................................... ... 11III Genetic Characterization of Kokoda#5 Hydrocarbon Formation (mg/g TOC) :> o 100 200 300 -70 --. 1 a... ~ ~ '--' ~ =: ~ -5 ~ ~ U ~ 'I""Î ~ """' - ~ ~ -60 C2+% -50 -40 -30 -20 --. 1 a... ~ ð -70 ~ =: ~ -5 ~ -60 ~ U ~ 'I""Î -35 -25 -20 -30 -45 -40 o ... Associated -30 -20 -20 Terra Nova Technologies Figure 7. Maturity comparison of Kokoda#5 sampled gases. Note, these maturity estimates may be compromised if the Kokoda#5 sampled gases are in fact mixed gases. It is important to remember that these inferred maturity variations for each respective sample may simply result from changes in the bulk compositional concentrations of the different contributors. In essence, gas mixes may not provide reliable or accurate maturity assessments! Sballow Gas (5000' MD) - This gas sample does not plot on the maturity template, suggesting a very low level of maturity. This gas is suggested to be originally derived from an immature source rock at less than. 0.50 Ro maturity equivalent. Ethane isotopic data appears to be compromised by the addition/input of isotopically light biogeuic gas. Gas Charges 2 (6600-6900' MD) & 4 (8209-8800' MD) - These gas samples originate directly above and below the 'main gas charge 3'. These gases are suggested to be originally derived near peak oil generation from a source rock at approx. 0.75 Ro maturity equivalent. Isotopic and gas compositional data suggest these gases are likely to have been originally associated with oil. It is interesting to note the shallower interval (Gas Charge 2) appears more mature than the deeper 'Main Gas charge' (Gas Charge 3). 'Main Gas Charge' 3A-C3 (7000-8000' MD) - These gases are suggested to be originally derived near peak oil generation from a source rock at approx. 0.65-0.70 Ro maturity equivalent. Isotopic and gas compositional data suggest these gases are likely to have been originally associated with oil. Kokoda#5 9500' MD - gas is suggested to be originally derived just beyond peak oil generation from a source rock at approx. 0.95 Ro maturity equivalent. Isotopic and gas compositional data suggest these gases are likely to have been originally associated with oil. Gas Charge 5 (9930-10420' MD) & 6 (10550-11070' MD) -These gases are suggested to be originally derived in the late oil window from a source rock at approx. 1.05-1.15 Ro maturity equivalent. Isotopic and gas compositional data suggest these gases are likely to have been originally associated with oil, recognizing the source rock for these gases has now moved through the oil window. Biogeuic gas contributions to Kokoda#5 MGIL sampled gases are also evident and range between 15% and 50%. The biogeuic component to these gases may result from in-situ gas absorption into undersaturated migrating thermogeuic gasloil, or could indicate some degree of bacterial activity (i.e. limited biodegradation). ~~~~~~~~~~~~~~~~~~~ as isoto e data for Kokoda#5 well, North Slo e (Alaska). Gas Composition Data Dryness Wetness %Cl %C2 %C3 %IC4 %NC4 %IC5 %NCS %C6+ %Cl fCn %C2ICn 13¡C4ö13nC4 ö13nCS 500 3 0.06 0.06 0.001 99.0 0.0 1000 20 0.38 0.38 100.0 0.0 -60.4 1500 55 1.29 1.29 0.005 99.6 0.4 -49.8 2000 36 0.67 0.66 0.005 99.3 0.7 -47.6 2500 22 0.38 0.38 0.001 0.001 99.6 0.3 -50.0 3000 25 0.65 0.65 0.001 0.000 99.8 0.2 -54.5 3500 40 0.78 0.77 0.005 0.001 0.003 99.0 0.6 -57.4 4000 46 0.97 0.96 0.009 0.003 0.001 0.001 0.001 98.6 0.9 -57.9 4500 31 0.57 0.56 0.006 0.002 0.001 98.4 1.1 -57.5 4600 31 0.58 0.57 0.005 0.001 0.001 98.8 0.8 -57.8 4700 31 0.66 0.65 0.005 0.001 0.001 98.9 0.8 -58.1 4800 36 0.80 0.80 0.006 0.002 0.001 0.001 98.9 0.8 -58.3 4900 38 0.78 0.77 0.007 0.002 0.001 0.001 98.6 0.9 -58.4 5000 45 1.01 1.00 0.010 0.003 0.001 0.001 0.001 98.5 0.9 -58.5 5100 35 0.68 0.67 0.007 0.003 0.001 0.001 98.3 1.1 -58.4 5200 28 0.51 0.50 0.006 0.002 0.001 0.001 0.001 97.9 1.2 -58.1 5400 22 0.45 0.44 0.007 0.003 0.001 0.001 0.001 97.4 1.5 -57.4 5500 22 0.43 0.42 0.007 0.003 0.001 0.001 0.001 97.3 1.6 -57.0 5600 24 0.48 0.46 0.008 0.003 0.001 0.001 0.001 97.1 1.7 -56.8 5700 23 0.46 0.44 0.008 0.003 0.001 0.001 0.001 96.9 1.8 -56.5 5800 16 0.32 0.30 0.007 0.003 0.001 0.001 0.001 96.1 2.2 -57.1 5900 24 0.38 0.37 0.009 0.003 0.001 0.001 0.001 96.2 2.4 -57.1 6000 18 0.32 0.30 0.009 0.003 0.001 0.001 0.001 95.3 2.8 -56.7 6100 15 0.23 0.22 0.007 0.003 0.001 0.001 0.001 94.7 3.1 -55.9 6300 32 0.60 0.56 0.024 0.009 0.002 0.001 0.001 93.9 4.0 -54.8 6400 17 0.37 0.34 0.014 0.006 0.002 0.001 0.001 93.7 3.7 -56.1 6500 10 0.22 0.20 0.011 0.006 0.001 0.001 0.001 90.7 5.2 -53.8 6600 16 0.30 0.27 0.018 0.010 0.001 0.002 0.001 89.7 5.8 -54.6 6682 98 1.85 1.51 0.153 0.126 0.018 0.030 0.006 0.005 0.004 81.5 8.3 -54.3 6700 234 4.18 3.28 0.384 0.335 0.050 0.084 0.018 0.016 0.012 78.5 9.2 -54.5 6710 273 5.37 4.23 0.491 0.424 0.063 0.106 0.022 0.020 0.014 78.8 9.1 -54.0 -32.1 -31.0 -29.9 6720 236 3.93 3.13 0.344 0.297 0.045 0.075 0.016 0.015 0.011 79.6 8.7 -54.1 6730 176 3.00 2.28 0.288 0.276 0.043 0.074 0.016 0.015 0.012 75.9 9.6 -53.9 6740 150 2.46 1.76 0.252 0.273 0.046 0.079 0.018 0.016 0.013 71.7 10.3 -54.1 6750 180 3.18 2.35 0.316 0.322 0.053 0.089 0.020 0.018 0.014 73.9 9.9 -54.0 -30.6 -29.6 6760 85 6800 39 0.50 0.33 0.047 0.068 0.014 0.027 0.008 0.007 0.008 64.5 9.4 6900 29 0.41 0.31 0.029 0.033 0.007 0.015 0.004 0.004 0.006 76.1 7.1 7000 15 0.18 0.14 0.014 0.012 0.003 0.005 0.002 0.002 0.003 78.1 7.4 7100 17 0.28 0.24 0.020 0.015 0.003 0.005 0.001 0.001 0.003 83.1 7.2 ~~~~~~~~~~~~~~~~~~~ Table 1 b. MGIL composition and as isoto e data for Kokoda#5 well, North Slope (Alaska). Depth Total Gas Total HC Gas Composition Data Dryness Wetness Gas Isotope Data (ft) (Rig, units) (Lab, vol% %C1 %C2 %C3 %IC4 %NC4 %IC5 %NC5 %C6+ %C1/Cn %C2/Cn Õ13C1 õ13iC4õ13nC4 õ13nC5 7131 121 2.44 1.99 0.201 0.148 0.031 0.042 0.013 0.009 0.009 81.5 8.2 -53.0 -32.9 -33.2 -30.7 7132 78 1.49 1.26 0.106 0.075 0.016 0.021 0.006 0.004 0.005 84.4 7.1 -52.9 7180 59 0.95 0.73 0.084 0.076 0.018 0.024 0.008 0.005 0.006 76.8 8.8 -52.3 7200 47 0.74 0.55 0.067 0.067 0.016 0.024 0.008 0.006 0.007 73.9 9.0 -52.3 7300 42 0.65 0.49 0.059 0.054 0.011 0.021 0.006 0.005 0.007 75.0 9.0 -51.9 7372 102 2.06 1.76 0.150 0.094 0.014 0.028 0.007 0.006 0.005 85.3 7.3 -52.2 7400 47 0.84 0.67 0.073 0.057 0.010 0.021 0.005 0.005 0.006 79.1 8.6 -51.5 7470 100 1.89 1.56 0.162 0.104 0.014 0.030 0.007 0.007 0.007 82.5 8.6 -52.1 7500 230 4.42 3.63 0.424 0.250 0.027 0.059 0.011 0.010 0.008 82.1 9.6 -51.6 7528 492 11.60 9.79 1.030 0.562 0.055 0.119 0.019 0.019 0.010 84.4 8.9 -51.3 -32.2 -31.7 -30.5 7548 406 9.34 7.62 0.925 0.552 0.057 0.126 0.022 0.021 0.014 81.6 9.9 -51.0 7573 509 15.72 12.80 1.580 0.935 0.093 0.214 0.036 0.038 0.025 81.4 10.1 -51.3 ¡ 7588 580 19.85 16.59 1.830 1.010 0.097 0.222 0.036 0.039 0.023 83.6 9.2 -51.2 -31.9 -31.5 -30.6 7613 618 24.94 21.14 2.160 1.170 0.108 0.252 0.040 0.043 0.027 84.8 8.7 -51.1 7650 310 5.48 4.05 0.649 0.495 0.059 0.147 0.028 0.031 0.024 73.9 11.8 -51.2 7700 362 8.50 6.70 0.875 0.584 0.067 0.175 0.032 0.036 0.027 78.9 10.3 -51.3 -31.9 -31.3 -29.5 7750 284 5.45 4.29 0.515 0.387 0.050 0.130 0.026 0.029 0.023 78.7 9.5 -51.5 7800 229 3.94 2.93 0.411 0.345 0.047 0.126 0.026 0.030 0.026 74.3 10.4 -51.5 -32.1 -32.1 7850 189 7900 164 2.65 1.90 0.267 0.264 0.041 0.105 0.023 0.027 0.026 71.6 10.1 -51.8 8000 180 2.99 2.21 0.290 0.274 0.044 0.101 0.023 0.026 0.026 73.8 9.7 -51.4 8100 33 0.56 0.41 0.055 0.051 0.010 0.020 0.006 0.007 0.010 71.9 9.7 -50.5 8209 53 0.87 0.64 0.089 0.082 0.015 0.025 0.007 0.007 0.009 73.1 10.3 -50.7 8300 70 1.16 0.89 0.117 0.096 0.017 0.025 0.006 0.005 0.006 76.7 10.1 -50.5 8400' 80 1.42 1.11 0.142 0.107 0.018 0.028 0.007 0.006 0.007 77.9 10.0 -51.1 -31.0 -30.7 8500 0 1.11 0.86 0.114 0.082 0.013 0.022 0.005 0.005 0.006 77.8 10.3 -50.5 8600 104 2.00 1.57 0.215 0.138 0.020 0.035 0.008 0.007 0.008 78.4 10.7 -50.7 8676 285 5.13 4.06 0.567 0.336 0.045 0.078 0.018 0.015 0.013 79.1 11.0 -50.9 -31.2 -29.5 -28.6 8700 129 2.44 1.82 0.294 0.205 0.030 0.054 0.Q13 0.012 0.011 74.6 12.1 -50.4 8800 72 1.09 0.77 0.132 0.108 0.018 0.034 0.009 0.008 0.009 70.9 12.1 -49.8 8900 72 1.23 0.91 0.142 0.102 0.017 0.032 0.009 0.008 0.010 74.0 11.6 -50.1 8996 100 1.67 1.24 0.205 0.131 0.020 0.039 0.011 0.010 0.011 74.4 12.3 -50.2 9200 109 1.67 1.24 0.221 0.128 0.019 0.034 0.009 0.007 0.007 74.4 13.3 -49.5 9300 97 1.62 1.19 0.220 0.127 0.019 0.037 0.011 0.009 0.011 73.3 13.5 -49.2 9398 105 1.75 1.26 0.249 0.142 0.022 0.041 0.013 0.010 0.012 72.1 14.2 -49.1 9500 110 1.87 1.35 0.259 0.145 0.024 0.045 0.015 0.013 0.017 72.3 13.9 -49.2 -30.1 -26.4 -25.9 9600 68 1.12 0.76 0.166 0.102 0.019 0.034 0.013 0.010 0.015 68.0 14.8 -48.7 9700 89 1.51 1.07 0.223 0.121 0.021 0.036 0.014 0.010 0.015 70.9 14.8 -48.4 9800 69 1.10 0.77 0.159 0.095 0.018 0.030 0.012 0.008 0.012 69.8 14.4 -47.9 9930 104 1.88 1.36 0.273 0.136 0.024 0.038 0.016 0.011 0.018 72.5 14.6 -48.2 . Data may be suspect ~~~~~~~~~~~~~~~~~~~ Table 1 c. MGIL composition and as isoto a data for Kokoda#5 wall, North Slope (Alaska). Depth Total Gas Total HC Gas Composition Data Dryness Wetness Gas Isotope Data (ft) (Rig, units) (Lab, vol% %C1 %C2 %C3 %IC4 %NC4 %IC5 %NC5 %C6+ %C1/Cn %C2/Cn õ'3C1 i õ'3iC4õ'3nC4õ13nCS 9954 206 4.01 3.34 0.571 0.035 0.021 0.014 0.027 83.3 14.2 -48.1 10036 470 13.34 11.53 1.680 0.064 0.030 0.017 0.019 86.4 12.6 -47.9 -30.5 -26.0 -25.7 10160· 178 2.99 2.53 0.392 0.028 0.017 0.009 0.013 84.6 13.1 -44.2 -29.3 -24.4 10290 100 1.76 1.48 0.226 0.021 0.013 0.007 0.010 84.3 12.9 -46.6 10420 86 1.21 0.94 0.213 0.026 0.015 0.008 0.Q10 77.5 17.6 -46.6 10550 70 1.24 1.08 0.131 0.010 0.008 0.004 0.011 86.8 10.5 -46.2 10680 119 2.50 2.22 0.239 0.016 0.008 0.004 0.008 0.004 0.001 88.8 9.6 -44.4 10810· 144 3.10 2.75 0.295 0.026 0.013 0.006 0.011 0.002 0.001 88.6 9.5 -44.0 -30.4 -25.3 10940 253 5.82 5.36 0.376 0.033 0.021 0.011 0.017 0.002 0.001 92.1 6.5 -42.7 I -29.9 -25.4 11070· 188 4.27 3.95 0.283 0.016 0.007 0.004 0.006 0.003 0.002 92.5 6.6 -43.6 -28.7 -24.2 . Data may be suspect I I " I I I I I I -. I I I I I I I ,. I ~ If.lr~ ~øI-M Biostratigraphic Synthesis of the ConocoPhillips Kokoda 5 Well (6,760 - 11,055/70 ft MD) NPR-A, North Slope, Alaska I>ecenœber,2005 the irf group, inc. consulting paleontologists 6721 Round Tree I>rive Anchorage, AK 99507 907-346-4090 anchorage - houston - dallas - toronto - halifax I I " I I I I I I -. I I I I I I I " I 1 Biostratigraphic Synthesis for the ConocoPhillips Alaska Kokoda 5 Well (6,760.0 ft - 11,05570 ft MD) NPR-A, North Slope, Alaska Robert L. Ram David K. Goodman the irf group, inc. December, 200S Synthesis Sixteen cuttings and sidewal1 core samples from the ConocoPhillips Alaska Kokoda 5 well, NPR-A, Alaska North Slope, were examined for organic-walled microfossils to develop a chronostratigraphic framework for the interval of interest between 6,760 ft and 11,055/70 ft md (Figure 1). The samples contain a moderately diverse population of organic-walled microfossils; preservation is good to very good. The interval examined ranges in age from Albian to questionable Triassic. Age determination should be considered tentative in light of the very limited number of samples available for analysis; a geologically meaningful biostratigraphic profile could therefore not be constructed and any interpretations presented herein are presented with that caveat. As a consequence, most of the age picks discussed below occur within the sample gaps (see Figure 1), and none of the Alpine interval log markers (Alpine A, C, D) could be identified with confidence. The uppermost sample (sidewall core at 6,670 ft) can be dated as only undifferentiated Cretaceous. The interval between 6,900 ft and 7,720 ft is dated as Albian to ?early Albian based on the recovered microfossil content; five samples are included in this interval, including three sidewall cores. The ?early Albian interval (7,480-7,720 ft) may be older but it lacks any microfossils that would unequivocally indicate an older age. The interval between 8,430 ft and 8,460 ft (represented by two samples) is difficult to date precisely and is interpreted as Valanginian to Kimmeridgian; if present, the top of Alpine D would be located in the unsampled interval between 7,720 ft and 8,340 ft, but this cannot be determined paleontologically because there are no samples. The interval between 8,640 ft and 9,450 ft (3 samples, the lower of which is separated by 660 ft of measured depth from the others) is Kimmeridgian; the top of Alpine C may occur within the sample gap 8,460-8,640 ft. The interval between 9,840 ft and 10,200 ft is Oxfordian. The two lowermost samples do not contain sufficient microfossils to date them unequivocally; the upper of these two samples (10,830/45 ft) is interpreted as undifferentiated Jurassic, while the lower one is interpreted as questionable Triassic. Both of these determinations are based on single, marginally useful samples. I I " I I I I I I -. I I I I I I I ,. I 2 The biostratigraphic profile constructed for the interval is non-contiguous because of the extremely wide sample spacing provided for analysis. Figure 1-3 illustrate the results of this analysis plotted against measured depth. The sample gaps are indicated with a hatchured pattern in these diagrams, and their near ubiquitous presence indicates the marginal results derived from this type of sample program. All samples contain abundant numbers of undifferentiated bisaccate gymnosperm pollen, some proportion of which in the lower part of the examined section may represent specimens caved from overlying strata. The degree of contamination of samples from caving is not determinable, owing significantly to the unknown nature of the strata in the numerous unsampled intervals. Given that the well is seriously deviated from vertical, the true vertical relationship of the data presented here must be interpreted in light of the well geometry. Stratigraphic Summary Cretaceous (undifferentiat~d} Deptþ.: 6,760 ft (l sidewall core sample). Comments: The single sample from this depth contains an assemblage consisting entirely of long-ranging taxa having little definitive stratigraphic value. The underlying strata are clearly Albian in age, and therefore this sample is likely to represent Albian, or possibly Cenomanian, deposition. Albian Œm:II Cretaceous) Depth: 6,900-7,440 ft (2 samples). .lw:kx Iiwi: The two samples from this interval are clearly Albian in age, based in particular on the presence of the uncommon but highly distinctive dinoflagellate cyst species Pseudoceratium polymorphum. Comments: The overall assemblages are a mixture of marine and terrestrial forms, with minor reworking of Triassic and Mississippian taxa. I I " I I I I I I -. I I I I I I I t' I 3 ?earlI Alþian (Earl.! Cretaceous) De,pth: 7,480-7,720 ft (3 samples). Comments: The uppermost occurrence of the dinoflagellate Gardodinium trabeculosum at 7,480/90 ft is also characteristic of the lower portion of Albian strata across much of the NPRA region and western portions of the Central North Slope. The overall assemblages are a mixture of marine and terrestrial forms, with minor reworking of Triassic and Mississippian taxa. Valan&inian 12 Kimmerid¡ian (Early Cretaceous to Late Jurassic) Depth: 8,430- 8,460 ft (2 samples). Index Taxa: The samples contain such clearly Valanginian taxa as the spore species Concavissimisporites variverrucatus, C. punctatus, Aequitriradites verrucosus and Foraminisporis wonthaggiensis, along with the Late Jurassic (Kimmeridgian) dinoflagellate cyst species Tubotuberella rhombiformis and low frequencies of Chytroeisphaeridia chytroeideslhyalinea (which becomes much more common in underlying clearly Jurassic strata). The latter two species may therefore represent reworked occurrences, however it is not possible to determine this unequivocally due to the large sample gaps above and below the samples, and a relatively wide age interval is assigned to the section. Comptents: The two samples from this narrow interval contain a highly diverse and abundant population of terrestrial and marine forms of a somewhat problematical chronostratigraphic signature.. A transitional Jurassic/Cretaceous interval similar in palynological signature to this has been noted in many wells in the NPRA region. It probably records a regressive episode in which the rich Oxfordian Jurassic dinocyst populations normally seen diminish relative to terrestrial long-ranging Jurassic-Cretaceous taxa. Note that an unsampled gap of more than 600' overlies the interval. The top of Alpine D unit, if present in the well, would most likely be located in the unsampled interval between 7,720 ft and 8,340 ft, but this cannot be determined paleontologically because there are no samples. I I " I I I I I I IJI I I I I I I I " I 4 J{immeridaian (Late Jurassic) Depth: 8,640 to 9,450 ft (3 samples, including a 660 ft sample gap within the interval). Comments: The three samples comprising this interval are clearly Late Jurassic in age, containing such dinocyst taxa as Paragonyaulacysta osmingtonensis, Tubotuberella lurida, Atopodinium prostratum (?reworked), and the informally named Chytroeisphaeridia "verrucosa." It is considered Kimmeridgian largely owing to the absence of clearly older Oxfordian species. If preserved in this well, the top of Alpine C may occur within the sample gap between 8,460 ft and 8,640 ft. Late O~ordian (L@te Jurassic) Depth: 9,840 ft to 10,200 ft (3 samples). Im'kx Iiw!: The highly distinctive Oxfordian dinoflagellate assemblage is present in this interval, including such key forms as Nannoceratopsis pellucida, Stephanelytron redcliffense and Pareodinia sp. E of Wiggins 1975. The Alpine A log marker should occur within the sample gap between 8,640 ft and 9,840 ft based on these palenotological criteria. 1.Jurassit (undifferentiated) Depth: 10,830/45 ft (1 cuttings sample). Iwkx Taxa: This single sample contains a problematic assemblage including a specimen questionably assigned to Mancodinium semitabulatum, a frequently-seen Early Jurassic dinoflagellate species, along with a single indeterminate taeniate pollen grain of Late Triassic type. The Jurassic form may be caved, and again there is a significant (630 ft) unsampled gap above, rendering determination of a boundary conjectural. I I I' I I I I I I '- I I I I I I I I' I 5 ?Triassic D~pth: 11,055170 ft (1 cuttings sample). Comments: The lowermost sample withîn the interval examined is tentatively considered to be Triassic mainly on the basis of a notable diminution in overall palynological recovery, which is a frequent characteristic of Triassic strata of the Sag River and older units. No clearly distinctive age-diagnostic forms were observed, however. Display Panels Biostratigraphic results for the section are illustrated in the following display panels: Figure 1. Schematic well summary with selected assemblage parameters and species distribution curves. Figure 2. Microfossil assemblage parameters. Figure 3. Quantitative species distribution curves. Figure 4. Interval range chart for in situ organic-walled microfossil species. Figure 5. Preliminary correlation of Lower Cretaceous - Upper Jurassic rocks in Kokoda 5, North Inigok 5 and Ikpikpuk wells. Figure 6. Ikpikpuk 1 interval range chart. Figure 7. North Inigok 1 quantitative range chart. Analytical Parameters Each of the samples was evaluated in terms of a quantitative census analysis of the organic-walled microfossils. Quantitative census data increase the "dimensionality" of the final data set and allow a wide range of numerical and statistical analyses to be performed on the data set, in contrast to either "presence-absence" or "semi-quantitative" (also known as abundance estimates), for which further statistical analyses are either not possible, or produce invalid or misleading results. A sample set of approximately 250 I I I' I I I I I I ,. I I I I I I I ,. I 6 identifiable specimens was counted for each sample wherever possible; additional species not encountered in the initial 250 grain count, but identified during subsequent examination of the microscope slides, were added to the final counts, thereby affecting the number of specimens and increasing the counts to more than 300 in most of the samples. A complete listing of all 148 species identified in the cored interval is given in Appendix 1. Appendix 2 provides a census count for each sample examined in this study, while Appendix 3 lists all range events (tops, bases) for the well in descending stratigraphic succession. Primary data include the quantitative and stratigraphic distribution of the microfossils. A suite of microfossil assemblage parameters, or summary tracks, are also included in this report, and they are illustrated in Figure 2. These derivative tracks are used to enhance the primary data and to summarize the geological and biological history of the well section in terms that are more useful than simple range data alone. These tracks can be used to make more detailed interpretations of depositional system architecture, identify possible stratal discontinuities, and to characterize stratigraphic intervals using biological content. The summary tracks recorded for the Mitre 1 section include: · Total Microfossil Count (all microfossils counted in sample) · Total Marine Abundance · Total Nonmarine Abundance · Total Reworked Abundance · Marine Percentage Abundance · Nonmarine Percentage Abundance · Marine Species Richness (number of species) · Marine Shannon-Weaver Richness Ratio · Nonmarine Species Richness (number of species) · Nonmarine Shannon-Weaver Richness Ratio · Total Undifferentiated Bisaccate Pollen · Total Nonmarine Non-bisaccate Pollen · Total Freshwater Algae · Total Acritarchs · Total Dinoflagellates · Reworked Paleozoic Abundance · Reworked Triassic Abundance · Reworked Older Jurassic Abundance Recommendations for Future Work The sample program provided for Kokoda 5 biostratigraphy was marginal, and very close to useless. We are unable to. date stratigraphic intervals in a reasonable manner with this type of sample program because a continuous profile is necessary to determine caving I I " I I I I I I ,. I I I I I I I t' I 7 effects and to recover as complete a microfossil assemblage for an interval as is possible. As in every other stratigraphic discipline, increasingly detailed sampling protocols result in an increased potential for more highly refined stratigraphic interpretation, with the increased application of 3D seismic as a preferred data collection procedure over 2D in recent years. The same is true for biostratigraphy. A more comprehensive and contiguous sample program is required to develop a geologically meaningful interpretive result, and we strongly recommend that more closely spaced samples are utilized for future studies. During the past 5 years, we have developed a very detailed biostratigraphic framework for this interval on the North Slope, but it cannot be applied effectively with such sparsely-distributed sample material from a study well. There is tremendous potential for very precise biostratigraphic modeling in this interval on the North Slope at the present time, but this simply cannot be achieved without the commitment of ConocoPhillips geoscientists and management to provide the type of sample set needed to achieve the desired results. Development of a detailed regional stratigraphic framework is dependent on effective integration of biological data sets with other regional data including well logs, depositional sequence models, lithostratigraphic data, and reflection seismic records. Stratigraphic interpretation is an iterative process which results in an improved and more constrained understanding of individual data sets when these data are included as an integral element of the process, and not treated as isolated components. The most effective manner in which to facilitate these results is inclusion of a biostratigrapher in future group work sessions dealing with the temporal and spatial distribution of these rocks. The iIf group maintains a confidentiality agreement with ConocoPhillips Alaska as a component of our consulting contract, and we respect the highly sensitive nature of the exploration and development plans of our clients. Data Archive (CD) All hardcopy components of this report are included as digital files on the attached CD. The files are platform-independent files: WORD (.doc), EXCEL (.xls), or PORTABLE DOCUMENT FORMAT (.pdt). The CD files include: KokSRept.doc - Report Text KokSApp1.doc - Appendix 1 KokSApp2.doc - Appendix 2 Kok5App3.doc - Appendix 3 KokSData.xls - Occurrence Data KokSSums.xls - Assemblage Statistics KokSFig1.pdf - Figure 1 KokSFig2.pdf - Figure 2 KokSFig3.pdf - Figure 3 KokSFig4.pdf - Figure 4 I I " I I I I I I re I I I I I I I " I 8 KokSFig5.pdf - Figure 5 KokSFig6.pdf - Figure 6 KokSFig7.pdf - Figure 7 Availability The hi group is available to discuss any aspect of the chronostratigraphic interpretation for the Kokoda 5 well. We are also available to conduct further statistical and biofacies analytical studies for depositional system and sequence architecture delineation, and to plan and develop future stratigraphic studies, regional calibration wells, and more geographically comprehensive correlation frameworks designed to address the requirements of expanded exploration and development efforts. David K. Goodman Robert L. Ravn I I " I I I I I I -. I I I I I I I it I ConocoPhillips Kokoda 5 Appendix 1 Species List I I (' I I I I I I -- I I I I I I I I' I 1 ConocoPhiUips Alaska Kokoda 5 Appendix 1: Species List (148 species recovered) Marine Microfossils Acritarchs Cometodinium whitei "Ieiosphere - indel, small" Micrhystridium sp. - indet. Pterospermella sp. - indet. "Veryhachium sp. - large, triangular" Dinoflagellates Apteodinium sp. - indet. Ascostomocystis gigantea Atopodinium cf. haromense Atopodinium prostratum Batioladinium jaegeri Batioladinium micropodum - thin form Canningia? sp. -indet. Cassiculosphaeridia spp. - indet. Cassiculosphaeridia? cf. magna "Cassiculosphaeridia? sp. 1 - small, thin" CWamydophorella sp. - indet. "Chytroeisphaeridia ""verrucosa" "" Chytroeisphaeridia chytroeides/hyalina Circulodinium distinctum group Circulodinium hirtellum group "Circulodinium? sp. - indet., nontabular reticulum" Circulodinium? spp. - indet. Cribroperidinium edwardsii Cribroperidinium spp. - indet. "elongate precingular, thickened cingular region" Gardodinium trabeculosum Gochteodinia villosa Gonyaulacysta fastigiata Gonyaulacysta helicoidea group Gonyaulacysta spp. - indet. Heslertonia heslertonensis I I I' I I I I I I -- I I I I I I I ~ I 2 Hystricbodinium voigtii Impletosphaeridium? spp. - indet. Leptodinium cf. delicatum Leptodinium? sp. - indet. Lithodinia jurassica Lithodinia spp. - indet. Mancodinium semitabulatum (?) Microdinium opacum Nannoceratopsis pellucida Oligosphaeridium complex - thin form Oligosphaeridium poculum Omatidinium amphiacanthum PaIaeoperidinium cretaceum Paragonyaulacysta osmingtonensis Pareodinia sp. E of Wiggins 1975 "peridinioid autophragm - indet., smaIl, pale" Pseudoceratium polymorphum Pterodinium aIiferum Pterodinium cingulatm Pterodinium? sp. - indet. Scriniodinium? sp. - indet. Sentusidinium? spp. - indet. Sirmiodinium grossii Spiniferites spp. - indet. Stephanelytron redcliffense Tanyosphaeridium sp. - indet. Tenua bystrix Trichodinium?: sp. - indet. Tubotuberella lurida Tubotuberella rbombiformis VaIensiella ovula WaIlodinium cylindricum Terrestrial Microfossils Spores Aequitriradites verrucosus . Annulispora spp. - indet. Antulsporites clavus Calamospora tener Callialasporites dampieri Callialasporites turbatus cf. Crassitudisporites sp. - indet. I I I' I I I I I I Ie I I I I I I I ,. I 3 cf. Lophotriletes sp. - indet. Chasmatosporites sp. - indet. Cicatricosisporites aralicus/exilioides Cicatricosisporites australiensis Cicatricosisporites spp. - indet. Concavissimisporites punctatus Concavissimisporites variverrucatus Concentrisporites angulosus Deltoidospora mesozoica Deltoidospora spp. - indet. Dictyophyllidites? sp. - indet. Discisporites? sp. - indet. Foraminisporis wonthaggiensis Foveosporites spp. - indet. "Gleicheniidites sp. - indet., fairly large, thick zonae" Ischyosporites sp. - indet. Kraeuselisporites? spp. - indet. Laevigatosporites belfordii Laevigatosporites sp. - indet. Leptolepidites verrucatus Leptolepidites? sp. - indet. Lycopodiacidites canaliculatus Pilosisporites trichopapillosus Polycingulatisporites spp. - indet. Retitriletes singhii Retitriletes spp. - indet. Sestrosporites pseudoalveolatus Stereisporites sp. - indet. "trilete indet., granulose, thickened rim" Trilites spp. - indet. "Trilobosporites sp. - indet., very large" "Tuberositriletes sp. - indet., thick, very coarse" Tuberositriletes? sp. - indet. Pollen bisaccate gymnosperm pollen - indet. Cerebropollenites macroverrucosus "Corollina sp. - indet., large" Corollina torosa Exesipollenites tumulus Laricoidites magnus Osmundacidites wellmanii Perinopollenites elatoides Podocarpidites spp. - indet. I I ,. I I I I I I Ie I I I I I I I f' I 4 Pristinuspollenites cf. microsaccus sensu Singh 1964 "taeniate pollen - indet., vestigial sacci" Taxodiaceaepollenites hiatus Tricolpites crassimurus Tsugaepollenites sp. - indet. Miscellaneous Freshwater Algae Lecaniella sp. - indet. Palambages sp. - indet. Reworked Kekituk Cingulizonates bialatus Cingulizonates sp. - indet. Cingulizonates sp. - indet. Convolutispora spp. - indet. Corbulispora cancellata Corbulispora sp. - indet. Crassispora sp. - indet. Densosporites spp. - indet. Densosporites subcrenatus Densosporites variomarginatus Diatomozonotriletes saetosus Knoxisporites sp. - indet. Labiadensites anulatus Labiadensites cf. fimbriatus Lophozonotriletes spp. ~ indet. Murospora aurita Murospora spp. - indet. Platyptera incisotriloba "Punctatisporites sp. - indet., large, dark" "Reticulatisporites sp. - indet., large, thick" Retusotriletes cf. golatensis Spelaeotriletes cf. triangulus Spelaeotriletes sp. - indet. Vallatisporites sp. - indet. "Verrucosisporites sp. - indet., large" I I I' I I I I I I III I I I I I I I ,. I 5 Reworked Lower Mesozoic Limbosporites lundbladii Striatoabietites rhaeticus taeniate bisaccate pollen ~ indet. Reworked Devonian Retispora lepidophyta I ~ I I I I I I II I I I I I I I I' I ConocoPhillips Kokoda 5 Appendix 2 Sample Census I I ~ I I I I I I It I I I I I I I " I 1 ConocoPhillips Kokota 5 Appendix 2: Sample Census Data Sample 6760 bisaccate gymnosperm pollen - indet Deltoidospora spp. - indet. Osmundacidites wellmanii Retitriletes spp. - indet. Oligosphaeridium complex - thin form Dictyophyllidites? sp. - indet. Palaeoperidinium cretaceum "Circulodinium? sp. - indet., nontabular reticulum" Trilites spp. - indet. Laricoidites magnus Discisporites? sp. - indet. Densosporites spp. - indet. Taxa= 12 116 2 1 2 2 1 I 1 1 1 1 2 Total count:: 131 Sample 6900 bisaccate gymnosperm pollen - indet. Deltoidospora spp. - indet Osmundacidites wellmanii Retitriletes spp. - indet. Dictyophyllidites? sp. - indet. Palaeoperidinium cretaceum "Circulodinium? sp. - indet., nontabular reticulum" Trilites spp. - indet. Densosporites spp. - indet. Cicatricosisporites spp. - indet. Impletosphaeridium? spp. - indet. Spiniferites spp. - ¡ndet Pseudoceratium polymorphum Circulodinium hirtellum group Laevigatosporites sp. - indet. cf. Crassitudisporites sp. - indet. "elongate precingular, thickened cingular region" taeniate bisaccate pollen - ¡ndet Vallatisporites sp. - indet. Taxa= 19 115 12 1 1 1 1 3 1 2 1 1 1 1 1 1 1 1 1 1 Total count:: 147 I I' ,. I I I I I I -. I I I I I I I " I 2 Sample 7410-7440 bisaccate gymnosperm pollen - indel. Deltoidospora spp. - indet. Osmundacidites wellmanii Retitriletes spp. - indel. Oligosphaeridium complex - thin form Palaeoperidinium cretaceum Densosporites spp. - indel. Pseudoceratium polymorphum Circulodinium hirtellum group taeniate bisaccate pollen - indel. Polycingulatisporites spp. - indel. Cribroperidinium spp. - indel. Circulodinium? spp. - indel. "Ieiosphere - indel., small" Tenua hystrix Cassiculosphaeridia spp. - indel. Cribroperidinium edwardsii Pterodinium? sp. - indel. Foveosporites spp. - indel. Tsugaepollenites sp. - indel. Circulodinium distinctum group Apteodinium sp. - indel. Batioladinium micropodum - thin form Limbosporites lundbladii Taxa= 24 160 9 3 1 3 2 1 1 1 1 1 2 2 2 2 1 1 1 1 1 1 1 1 1 Total count: 200 Sample 7480-7490 bisaccate gymnosperm pollen - indel. Deltoidospora spp. - indet. Osmundacidites wellmanii Retitriletes spp. - indel. Oligosphaeridium complex - thin form Impletosphaeridium? spp. - indet. Circulodinium hirtellum group Circulodinium? spp. - indel. Cribroperidinium edwardsii Foveosporites spp. - indel. Tsugaepollenites sp. - indel. Podocarpidites spp. - indel. Gardodinium trabeculosum Lycopodiacidites canaliculatus Stereisporites sp. - indet. Oligosphaeridium poculum Palambages sp. - indel. "peridinioid autophragm - indel., small, pale" 99 8 6g2 1 2 1 2 2 2 1 1 1 1 1 1 1 1 I I ,. I I I I I I -. I I I I I I I ,. I 3 Cingulizonates sp. - indet. Taxa= 19 1 Total count:: 134 Sample 7640 bisaccate gymnosperm pollen - indet. Osmundacidites wellmanii Oligosphaeridium complex - thin form Dictyophyllidites? sp. - indet. Palaeoperidinium cretaceum Densosporites spp. - indet. Impletosphaeridium? spp. - indet. Pseudoceratium polymorphum Cribroperidinium spp. - indet. Circulodinium? spp. - indet. "leiosphere - indet., small" Cribroperidinium edwardsii Pterodinium? sp. - indet. Annulispora spp. - indet. Taxodiaceaepollenites hiatus Tricolpites crassimurus ChIamydophorella sp. - indet. Pterodinium cingulatm Taxa= 18 54 2 2 1 1 1 1 1 2 1 16 1 1 1 1 1 1 1 Total count:: 89 Sample 7720 bisaccate gymnosperm pollen - indet. Deltoidospora spp. - indet. Osmundacidites wellmanii Retitriletes spp. - indet. Oligosphaeridium complex - thin form Densosporites spp. - indet. Impletosphaeridium? spp. - indet. Spiniferites spp. - indet. Circulodinium? spp. - indet. "leiosphere - indet., small" Tenua hystrix Cassiculosphaeridia spp. - indet. Gardodinium trabeculosum Cicatricosisporites australiensis Leptodinium cf. delicatum Pterodinium aliferum Batioladinium jaegeri Canningia? sp. -indet. Microdinium opacum "Cassiculosphaeridia? sp. 1 - small, thin" Taxa= 20 43 1 2 1 11 1 3 1 1 10 2 1 2 1 4 2 1 1 1 1 Total count:: 90 I I " I I I I I I ,. I I I I I I I ,. I 4 Sample 8340-8370 bisaccate gymnosperm pollen - indel Deltoidospora spp. - indet. Osmundacidites wellmanii Retitriletes spp. - indet. Oligosphaeridium complex - thin form Densosporites spp. - indet. Cicatricosisporites spp. - indet. Cribroperidinium spp. - indet. Podocarpidites spp. - indet. Cerebropollenites macroverrucosus Chytroeisphaeridia chytroeideslhyalina Sentusidinium? spp. - indet. Callialasporites dampieri Tubotuberella rhombiformis Perinopollenites elatoides Leptolepidites verrucatus Concavissimisporites punctatus Pristinuspollenites cf. microsaccus sensu Singh 1964 Chasmatosporites sp. - indet. Ischyosporites sp. - indet. Concavissimisporites variverrucatus Aequitriradites verrucosus Tanyosphaeridium sp. - indet. Cometodinium whitei Deltoidospora mesozoica Laevigatosporites belfordii Foraminisporis wonthaggiensis "Tuberositriletes sp. - indet., thick, very coarse" Corollina torosa Cicatricosisporites aralicus/exilioides Retitriletes singhii Sestrosporites pseudoalveolatus Atopodinium cf. haromense Trichodinium?: sp. - indet. Ascostomocystis gigantea Omatidinium amphiacanthum Heslertonia heslertonensis Lophozonotriletes spp. - indel Spelaeotriletes sp. - indet. Densosporites variomarginatus Cingulizonates sp. - indet. Retusotriletes cf. golatensis Retispora lepidophyta Taxa= 43 137 8 5 1 5 1 1 1 1 2 1 25 2 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Total count:: 220 I I , I I I I I I -. I I I I I I I " I 5 Sample 8430-8460 bisaccate gymnosperm pollen - indet. Deltoidospora spp. - indet. Osmundacidites wellmanii Retitriletes spp. - indet. Oligosphaeridium complex - thin form Densosporites spp. - indet. Cicatricosisporites spp. - indet. Podocarpidites spp. - indet. Cicatricosisporites australiensis Cerebropollenites macroverrucosus Chytroeisphaeridia chytroeides/hyalina Sentusidinium? spp. - indet. Callialasporites dampieri Tubotuberella rhombiformis Perinopollenites elatoides Concavissimisporites punctatus Pristinuspollenites cf. microsaccus sensu Singh 1964 Chasmatosporites sp. - indet. Ischyosporites sp. - indet. Concavissimisporites variverrucatus Aequitriradites verrucosus Tanyosphaeridium sp. - indet. Cometodinium whitei Densosporites variomarginatus Gonyaulacysta spp. - indet. Gochteodinia villosa Pareodinia sp. E of Wiggins 1975 Exesipollenites tumulus Hystrichodinium voigtii Pterospermella sp. - indet. Gonyaulacysta fastigiata Antulsporites clavus Leptodinium? sp. - indet. "Punctatisporites sp. - indet., large, dark" Taxa= 34 152 10 2 1 4 1 1 1 1 1 1 11 1 3 2 1 1 1 1 1 1 1 1 1 2 1 1 1 1 1 1 1 1 1 Total count:: 212 Sample 8640-8670 bisaccate gymnosperm pollen - indet. Deltoidospora spp. - indet. Osmundacidites wellmanii Densosporites spp. - indet. Cicatricosisporites spp. - indet. Annulispora spp. - indet. Cerebropollenites macroverrucosus Chytroeisphaeridia chytroeides/hyalina 105 7 5 8 1 1 1 14 I I " I I I I I I ,. I I I I I I I {I I 6 Sentusidinium? spp. - indet. Callialasporites dampieri Tubotuberella rhombifonnis Concavissimisporites punctatus Pristinuspollenites cf. microsaccus sensu Singh 1964 Chasmatosporites sp. - indet. Retispora lepidophyta Lithodinia jurassica Tubotuberella lurida Gonyaulacysta helicoidea group Atopodinium prostratum "Chytroeisphaeridia ""veuucosa""" Paragonyaulacysta osmingtonensis Pilosisporites trichopapillosus Tuberositriletes? sp. - indet. Calamospora tener Scriniodinium? sp. - indet. Micrhystridium sp. - indet. Murospora spp. - indet. "Reticulatisporites sp. - indet., large, thick" Platyptera incisotriloba Labiadensites anulatus Taxa= 30 7 1 1 1 1 1 1 1 24 4 1 1 6 1 1 1 1 1 1 1 1 1 Total count:: 201 Sample 8730-8760 bisaccate gymnosperm pollen - indet. Deltoidospora spp. - indet. Retitriletes spp. - indet. Densosporites spp. - indet. Cerebropollenites macroveuucosus Chytroeisphaeridia chytroeides/hyalina Sentusidinium? spp. - indel. Tubotuberella rhombifonnis Lophozonotriletes spp. - indet. Retispora lepidophyta Tubotuberella lurida Gonyaulacysta helicoidea group Murospora spp. - indet. Lithodinia spp. - indet. Concentrisporites angulosus "Gleicheniidites sp. - indet., fairly large, thick zonae" cf. Lophotriletes sp. - indet. Kraeuselisporites? spp. - indet. Convolutispora spp. - indel. Cingulizonates bialatus Labiadensites cf. fimbriatus 87 24 3 45 7 5 1 1 1 2 4 2 1 1 2 1 1 3 3 2 1 I I ,. I I I I I I ~ I I I I I I I t' I 7 Knoxisporites sp. - indet. Diatomozonotriletes saetosus "Verrucosisporites sp. ~ indet., large" Taxa= 24 1 1 1 Total count=: 200 Sample 9420-9450 bisaccate gymnospenn pollen ~ indet. Deltoidospora spp. - indet. Retitriletes spp. - indet. Densosporites spp. - indet. taeniate bisaccate pollen - indet. Podocarpidites spp. - indet. Cerebropollenites macroverrucosus Chytroeisphaeridia chytroeides/hyalina Sentusidinium? spp. - indet. Callialasporites dampieri Tubotuberella rhombiformis Retispora lepidophyta Pareodinia sp. E of Wiggins 1975 Tubotuberella lurida Atopodinium prostratum Concentrisporites angulosus Valensiella ovula Sirmiodinium grossii "Trilobosporites sp. - indet., very large" Striatoabietites rhaeticus Murospora aurita Taxa= 21 129 12 1 3 1 1 17 16 4 1 1 2 2 3 1 1 2 1 1 1 1 Total count=: 201 Sample 9840-9870 bisaccate gymnospenn pollen - indet. Deltoidospora spp. - indet. Osmundacidites wellmanii Densosporites spp. - indet. Polycingulatisporites spp. - indet. Cerebropollenites macroverrucosus Chytroeisphaeridia chytroeides/hyalina Sentusidinium? spp. - indet. Perinopollenites elatoides Leptolepidites verrucatus Lophozonotriletes spp. - indet. Spelaeotriletes sp. - indet. Gonyaulacysta spp. - indet. Pareodinia sp. E of Wiggins 1975 Lithodinia jurassica Tubotuberella lurida 58 2 1 5 1 20 35 3 1 1 1 1 2 1 1 11 I I " I I I I I I ,. I I I I I I I t' I 8 Gonyaulacysta helicoidea group Atopodinium prostratum "Chytroeisphaeridia ""verrucosa""It Lithodinia spp. - indet Valensiella ovula Nannoceratopsis pellucida Cassiculosphaeridia? cf. magna Leptolepidites? sp. - indet. Lecaniella sp. - indet. Stephanelytron redcliffense Spelaeotriletes cf. triangulus Crassispora sp. - indet. Corbulispora sp. - indet. Densosporites subcrenatus Taxa= 30 1 2 2 4 38 5 4 2 1 1 1 1 1 1 Total count: 208 Sample 10050-10080 bisaccate gymnosperm pollen - indet. Deltoidospora spp. - indet. Osmundacidites wellmanii Densosporites spp. - indel. Podocarpidites spp. - indet. Cerebropollenites macroverrucosus Chytroeisphaeridia chytroeides/hyalina Sentusidinium? spp. - indet. Tubotuberella rhombiformis Gochteodinia villosa Pareodinia sp. E of Wiggins 1975 Exesipollenites tumulus Tubotuberella lurida "Chytroeisphaeridia ""verrucosa" " " Paragonyaulacysta osmingtonensis Valensiella ovula Nannoceratopsis pellucida "Corollina sp. - indet., large" "Veryhachium sp. - large, triangular" Taxa= 19 66 2 2 1 1 8 13 1 1 1 1 1 3 2 1 1 1 2 1 Total count: 109 Sample 10170-10200 bisaccate gymnosperm pollen - indet. Deltoidospora spp. - indet. Densosporites spp. - indet. Cerebropollenites macroverrucosus Chytroeisphaeridia chytroeideslhyalina Sentusidinium? spp. - indet. Tubotuberella rhombiformis 114 4 1 19 28 2 1 I I I' I I I I I I ,. I I I I I I I t' I 9 Pareodinia sp. E of Wiggins 1975 Tubotuberella lurida "Chytroeisphaeridia ""verrucosa "II" Paragonyaulacysta osmingtonensis Valensiella ovula Sirmiodinium grossii Cassiculosphaeridia? cf. magna Wallodinium cylindricum Taxa= 15 1 2 1 1 3 1 1 1 Total count= 180 Sample 10830-10845 bisaccate gymnosperm pollen - indel. Deltoidospora spp. - indel. Osmundacidites wellmanii Densosporites spp. - indel. Cerebropollenites macroverrucosus Chytroeisphaeridia chytroeideslhyalina Sentusidinium? spp. - indel. Callialasporites dampieri Tubotuberella rhombiformis Gonyaulacysta spp. - indel. Gochteodinia villosa Lithodinia jurassica Tubotuberella lurida Gonyaulacysta helicoidea group Atopodinium prostratum "Chytroeisphaeridia ""verrucosa "" I' V alensiella ovula Nannoceratopsis pellucida Cassiculosphaeridia? cf. magna Spelaeotriletes cf. triangulus Callialasporites turbatus "trilete indel., granulose, thickened rim" Mancodinium semitabulatum (?) "taeniate pollen - indel., vestigial sacci" Corbulispora cancellata Taxa= 25 122 7 1 3 16 25 4 1 5 2 1 1 2 1 1 1 1 1 2 2 1 1 1 1 1 Total count= 204 I I " I I I I I I Ie I I I I I I I ,. I 10 Sample 11055-11070 bisaccate gymnosperm pollen - indet Deltoidospora spp. - ¡ndet. Cerebropollenites macroverrucosus Chytroeisphaeridia chytroeides/hyalina Sentusidinium? spp. - indet. Lophozonotriletes spp. - indet. Gonyaulacysta spp. - indel. Lithodinia jurassica Taxa=8 22 1 2 3 1 1 1 1 Total count=: 32 I I " I I I I I I Ie I I I I I I I ~ I ConocoPhillips Kokoda 5 Appendix 3 Range Events I I " I I I I I I ,. I I I I I I I " I 1 ConocoPhillips Kokota 5 Appendix 3: Range Events IW LAD: Last Occurrence Datum (range top) FAD: First Occurrence Datum (range base) Range Event Depth (ft) bisaccate gymnosperm pollen - indet. [LAD] "Circulodinium? sp. - indet., nontabular reticulum [LAD]" Deltoidospora spp. - indet. [LAD] Densosporites spp. - indet. [LAD] Dictyophyllidites? sp. - indet. [LAD] Discisporites? sp. - indet. [FAD] Discisporites? sp. - indet. [LAD] Laricoidites magnus [FAD] Laricoidites magnus [LAD] Oligosphaeridium complex - thin form [LAD] Osmundacidites wellmanii [LAD] Palaeoperidinium cretaceum [LAD] Retitriletes spp. - indet. [LAD] Trilites spp. - indet. [LAD] cf. Crassitudisporites sp. - indet. [FAD] cf. Crassitudisporites sp. - indet. [LAD] Cicatricosisporites spp. - indet. [LAD] Circulodinium hirtellum group [LAD] "Circulodinium? sp. - indet., nontabular reticulum [FAD]" "elongate precingular, thickened cingular region [FAD]" "elongate precingular, thickened cingular region [LAD]" Impletosphaeridium? spp. - indet. [LAD] Laevigatosporites sp. - indet. [FAD] Laevigatosporites sp. - indet. [LAD] Pseudoceratium polymorphum [LAD] Spiniferites spp. - indet. [LAD] taeniate bisaccate pollen - indet. [LAD] Trilites spp. - indet. [FAD] Vallatisporites sp. - indet. [FAD] Vallatisporites sp. - indet. [LAD] Apteodinium sp. - indet. [FAD] 6760 6760 6760 6760 6760 6760 6760 6760 6760 6760 6760 6760 6760 6760 6900 6900 6900 6900 6900 6900 6900 6900 6900 6900 6900 6900 6900 6900 6900 6900 7410 I I I' I I I I I I Ie I I I I I I I t' I 2 Range Event Depth (ft) Apteodinium sp. - indet [LAD] Batioladinium micropodum - thin fonn [FAD] Batioladinium micropodum - thin fonn [LAD] Cassiculosphaeridia spp. - indet. [LAD] Circulodinium distinctum group [FAD] Circulodinium distinctum group [LAD] Circulodinium? spp. - indet. [LAD] Cribroperidinium edwardsii [LAD] Cribroperidinium spp. - indet. [LAD] Foveosporites spp. - indet. [LAD] "leiosphere - indet., small [LAD]" Limbosporites lundbladii [FAD] Limbosporites lundbladii [LAD] Polycingulatisporites spp. - indet. [LAD] Pterodinium? sp. - indel. [LAD] Tenua hystrix [LAD] Tsugaepollenites sp. - indel. [LAD] Cingulizonates sp. - indet. [FAD] Cingulizonates sp. - indet. [LAD] Circulodinium hirtellum group [FAD] Foveosporites spp. - indet. [FAD] Gardodinium trabeculosum [LAD] Lycopodiacidites canaliculatus [FAD] Lycopodiacidites canaliculatus [LAD] Oligosphaeridium poculum [FAD] Oligosphaeridium poculum [LAD] Palambages sp. - indel. [FAD] Palambages sp. - indet [LAD] "peridinioid autophragm - indet., small, pale [FAD]" "peridinioid autophragm - indel., small, pale [LAD]" Podocarpidites spp. - indet. [LAD] Stereisporites sp. - indet. [FAD] Stereisporites sp. - indet. [LAD] Tsugaepollenites sp. - indet [FAD] Annulispora spp. - indel. [LAD] Chlamydophorella sp. - indel. [FAD] Chlamydophorella sp. - indet. [LAD] Cribroperidinium edwardsii [FAD] Dictyophyllidites? sp. - indet. [FAD] Palaeoperidinium cretaceum [FAD] Pseudoceratium polymorphum [FAD] Pterodinium cingulatm [FAD] Pterodinium cingulatm [LAD] Pterodinium? sp. - indet. [FAD] 7410 7410 7410 7410 7410 7410 7410 7410 7410 7410 7410 7410 7410 7410 7410 7410 7410 7480 7480 7480 7480 7480 7480 7480 7480 7480 7480 7480 7480 7480 7480 7480 7480 7480 7640 7640 7640 7640 7640 7640 7640 7640 7640 7640 I I " I I I I I I Ie I I I I I I I i' I 3 Range Event Depth (ft) Taxodiaceaepollenites hiatus [FAD] Taxodiaceaepollenites hiatus [LAD] Tricolpites crassimurus [FAD] Tricolpites crassimurus [LAD] Batioladinium jaegeri [FAD] Batioladinium jaegeri [LAD] Canningia? sp. -indet. [FAD] Canningia? sp. -indet. [LAD] Cassiculosphaeridia spp. - indet. [FAD] "Cassiculosphaeridia? sp. 1 - small, thin [FAD]" "Cassiculosphaeridia? sp. 1 - small, thin [LAD]" Cicatricosisporites australiensis [LAD] Circulodinium? spp. - indet. [FAD] Gardodinium trabeculosum [FAD] Impletosphaeridium? spp. - indet. [FAD] "leiosphere - indet., small [FAD]" Leptodinium cf. delicatum [FAD] Leptodinium cf. delicatum [LAD] Microdinium opacum [FAD] Microdinium opacum [LAD] Pterodinium aliferum [FAD] Pterodini urn aliferum [LAD] Spiniferites spp. - indet. [FAD] Tenua hystrix [FAD] Aequitriradites verrucosus [LAD] Ascostomocystis gigantea [FAD] Ascostomocystis gigantea [LAD] Atopodinium cf. haromense [FAD] Atopodinium cf. haromense [LAD] Callialasporites dampieri [LAD] Cerebropollenites macroverrucosus [LAD] Chasmatosporites sp. - indet. [LAD] Chytroeisphaeridia chytroeideslhyalina [LAD] Cicatricosisporites aralicus/exilioides [FAD] Cicatricosisporites aralicus/exilioides [LAD] Cingulizonates sp. - indet. [FAD] Cingulizonates sp. - indet. [LAD] Cometodinium whitei [LAD] Concavissimisporites punctatus [LAD] Concavissimisporites variverrucatus [LAD] Corollina torosa [FAD] Corollina torosa [LAD] Cribroperidinium spp. - indet. [FAD] Deltoidospora mesozoica [FAD] 7640 7640 7640 7640 7720 7720 7720 7720 7720 7720 7720 7720 7720 7720 7720 7720 7720 7720 7720 7720 7720 7720 7720 7720 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 I I " I I I I I I -. I I I I I I I ,. I Range Event Deltoidospora mesozoica [LAD] Densosporites variomarginatus [LAD] Foraminisporis wonthaggiensis [FAD] Foraminisporis wonthaggiensis [LAD] Heslertonia heslertonensis [FAD] Heslertonia heslertonensis [LAD] Ischyosporites sp. - indet [LAD] Laevigatosporites belfordii [FAD] Laevigatosporites belfordii [LAD] Leptolepidites verrucatus [LAD] Lophozonotriletes spp. - indet. [LAD] Omatidinium amphiacanthum [FAD] Omatidinium amphiacanthum [LAD] Perinopollenites elatoides [LAD] Pristinuspollenites cf. microsaccus sensu Singh 1964 [LAD] Retispora lepidophyta [LAD] Retitriletes singhii [FAD] Retitriletes singhii [LAD] Retusotriletes cf. golatensis [FAD] Retusotriletes cf. golatensis [LAD] Sentusidinium? spp. - indet. [LAD] Sestrosporites pseudoalveolatus [FAD] Sestrosporites pseudoalveolatus [LAD] Spelaeotriletes sp. - indet. [LAD] Tanyosphaeridium sp. - indet. [LAD] Trichodinium?: sp. - indet. [FAD] Trichodinium?: sp. - indet. [LAD} "Tuberositriletes sp. - indet., thick, very coarse [FAD]" "Tuberositriletes sp. - indet., thick, very coarse [LAD}" Tubotuberella rhombiformis [LAD] Aequitriradites verrucosus [FAD] Antulsporites clavus [FAD] Antulsporites clavus [LAD] Cicatricosisporites australiensis [FAD] Cometodinium whitei [FAD] Concavissimisporites variverrucatus [FAD] Densosporites variomarginatus [FAD] Exesipollenites tumulus [LAD] Gochteodinia villosa [LAD] Gonyaulacysta fastigiata [FAD] Gonyaulacysta fastigiata [LAD] Gonyaulacysta spp. - indet. [LAD] Hystrichodinium voigtii [FAD] Hystrichodinium voigtii [LAD] 4 Depth (ft) 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8340 8430 8430 8430 8430 8430 8430 8430 8430 8430 8430 8430 8430 8430 8430 I I ,. I I I I I I III I I I I I I I (' I Range Event Ischyosporites sp. - indet [FAD] Leptodinium? sp. - indet. [FAD] Leptodinium? sp. - indet. [LAD] Oligosphaeridium complex - thin form [FAD] Pareodinia sp. E of Wiggins 1975 [LAD] Pterospermella sp. - indet. [FAD] Pterospermella sp. - indet. [LAD] "Punctatisporites sp. - indet., large, dark [FAD]" "Punctatisporites sp. - indet., large, dark [LAD]" Tanyosphaeridium sp. - indet. [FAD] Annulispora spp. - indet. . [FAD] Atopodinium prostratum [LAD] Calamospora tener [FAD] Calamospora tener [LAD] Chasmatosporites sp. - indet. [FAD] "Chytroeisphaeridia ""verrucosa"" [LAD]" Cicatricosisporites spp. - indet. [FAD] Concavissimisporites punctatus [FAD] Gonyaulacysta helicoidea group [LAD] Labiadensites anulatus [FAD] Labiadensites anulatus [LAD] Lithodinia jurassica [LAD] Micrhystridium sp. - indet. [FAD] Micrhystridium sp. - indet. [LAD] Murospora spp. - indet. [LAD] Paragonyaulacysta osmingtonensis [LAD] Pilosisporites trichopapillosus [FAD] Pilosisporites trichopapillosus [LAD] Platyptera incisotriloba [FAD] Platyptera incisotriloba [LAD] Pristinuspollenites cf. microsaccus sensu Singh 1964 [FAD] "Reticulatisporites sp. - indet., large, thick [FAD]" "Reticulatisporites sp. - indet., large, thick [LAD]" Scriniodinium? sp. - indet. [FAD] Scriniodinium? sp. - indet [LAD] Tuberositriletes? sp. - indet. [FAD] Tuberositriletes? sp. - indet. [LAD] Tubotuberella lurida [LAD] cf. Lophotriletes sp. - indet. [FAD] cf. Lophotriletes sp. - indet. [LAD] Cingulizonates bialatus [FAD] Cingulizonates bialatus [LAD] Concentrisporites angulosus [LAD] Convolutispora spp. - indet. [FAD] 5 Depth (ft) 8430 8430 8430 8430 8430 8430 8430 8430 8430 8430 8640 8640 8640 8640 8640 8640 8640 8640 8640 8640 8640 8640 8640 8640 8640 8640 8640 8640 8640 8640 8640 8640 8640 8640 8640 8640 8640 8640 8730 8730 8730 8730 8730 8730 I I I' I I I I I I Fe I I I I I I I t' I Range Event Convolutispora spp. - indet. [LAD] Diatomozonotriletes saetosus [FAD] Diatomozonotriletes saetosus [LAD] "Gleicheniidites sp. - indet., fairly large, thick zonae [FAD]" "Gleicheniidites sp. - indet., fairly large, thick zonae [LAD]" Knoxisporites sp. - indet. [FAD] Knoxisporites sp. - indet. [LAD] Kraeuselisporites? spp. - indet. [FAD] Kraeuselisporites? spp. - indel [LAD] Labiadensites cf. fimbriatus [FAD] Labiadensites cf. fimbriatus [LAD] Lithodinia spp. - indet. [LAD] Murospora spp. - indet. [FAD] "Verrucosisporites sp. - indet., large [FAD]" "Verrucosisporites sp. - indet., large [LAD]" Concentrisporites angulosus [FAD] Murospora aurita [FAD] Murospora aurita [LAD] Retispora lepidophyta [FAD] Retitriletes spp. - indet. [FAD] Sirmiodinium grossii [LAD] Striatoabietites rhaeticus [FAD] Striatoabietites rhaeticus [LAD] taeniate bisaccate pollen - indet. [FAD] . "Trilobosporites sp. - indet., very large [FAD]" "Trilobosporites sp. - indet., very large [LAD]" Valensiella ovula [LAD] Cassiculosphaeridia? cf. magna [LAD] Corbulispora sp. - indet. [FAD] Corbulispora sp. - indet. [LAD] Crassispora sp. - indet. [FAD] Crassispora sp. - indel [LAD] Densosporites subcrenatus [FAD] Densosporites subcrenatus [LAD] Lecaniella sp. - indet. [FAD] Lecaniella sp. - indet. [LAD] Leptolepidites verrucatus [FAD] Leptolepidites? sp. - indel [FAD] Leptolepidites? sp. - indet. [LAD] Lithodinia spp. - indel [FAD] Nannoceratopsis pellucida [LAD] Perinopollenites elatoides [FAD] Polycingulatisporites spp. - indel (FAD] Spelaeotriletes cf. triangulus [LAD] 6 Depth (ft) 8730 8730 8730 8730 8730 8730 8730 8730 8730 8730 8730 8730 8730 8730 8730 9420 9420 9420 9420 9420 9420 9420 9420 9420 9420 9420 9420 9840 9840 9840 9840 9840 9840 9840 9840 9840 9840 9840 9840 9840 9840 9840 9840 9840 I I ,. I I I I I I lit I I I I I I I ,. I 7 Range Event Spelaeotriletes sp. - indel. [FAD] Stephanelytron redcliffense [FAD] Stephanelytron redcliffense [LAD] "Corollina sp. - indet., large [FAD]" "Corollina sp. - indet., large [LAD]" Exesipollenites tumulus [FAD] Podocarpidites spp. - indet. [FAD] "Veryhachium sp. -large, triangular [FAD]" "Veryhachium sp. - large, triangular [LAD]" Paragonyaulacysta osmingtonensis [FAD] Pareodinia sp. E of Wiggins 1975 [FAD] Sirmiodinium grossii [FAD] Wallodinium cylindricum [FAD] Wallodinium cylindricum [LAD] Atopodinium prostratum [FAD] Callialasporites dampieri [FAD] Callialasporites turbatus [FAD] Callialasporites turbatus [LAD] Cassiculosphaeridia? cf. magna [FAD] "Chytroeisphaeridia ""verrucosa"" [FAD]" Corbulispora cancellata [FAD] Corbulispora cancellata [LAD] Densosporites spp. - indet. [FAD] Gochteodinia villosa [FAD] Gonyaulacysta helicoidea group [FAD] Mancodinium semitabulatum (?) [FAD] Mancodinium semitabulatum (?) [LAD] Nannoceratopsis pellucida [FAD] Osmundacidites wellmanii [FAD] Spelaeotriletes cf. triangulus [FAD] "taeniate pollen - indet., vestigial sacci [FAD]" "taeniate pollen - indet., vestigial sacci [LAD]" "trilete indet., granulose, thickened rim [FAD]" "trilete indet., granulose, thickened rim [LAD]" Tubotuberella lurida [FAD] Tubotuberella rhombiformis [FAD] Valensiella ovula [FAD] bisaccate gymnosperm pollen - indet. [FAD] Cerebropollenites macroverrucosus [FAD] Chytroeisphaeridia chytroeides/hyalina [FAD] Deltoidospora spp. - indet. [FAD] Gonyaulacysta spp. - indet. [FAD] Lithodinia jurassica [FAD] Lophozonotriletes spp. - indel. [FAD] Sentusidinium? spp. - indet. [FAD] Depth (ft) 9840 9840 9840 10050 10050 10050 10050 10050 10050 10170 10170 10170 10170 10170 10830 10830 10830 10830 10830 10830 10830 10830 10830 10830 10830 10830 10830 10830 10830 10830 10830 10830 10830 10830 10830 10830 10830 11055 11 055 11055 11055 11055 11055 11055 11055 I I I' I I I I I I -. I I I I I I I " I ConocoPhillips Kokoda 5 Graphics Panels
