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
204-177
· . 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. ~O W- - ! '7 q Well History File Identifier Organizing (done) o Two-sided 11111111111 ""1111 o Rescan Needed 1111111111111111111 R~CAN v1" Color Items: o Greyscale Items: DIGITAL DATA ~skettes, No. ;¡ o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: o Other:: BY: ~ Date II' '-f f oC;; 151 VV1R Project Proofing 1111111111111111111 BY: C Maria ,) Date 11 ('4-Ié)~ I x 30 = 30 Date: ~ 1(/ Lf !ð0 151 vvtP 5CO MP Scanning Preparation BY: C- Maria ) + a. '6 = TOTAL PAGES (Count does not include cover sheet) 151 Production Scanning Stage 1 Page Count from Scanned File: 5 q (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES C-:-Mada) Date I ( t ¡ Iff Db Stage 1 If NO in stage 1, page(s) discrepancies were found: 11111111111I11 11111 BY: 151 NO vvtP YES NO BY: Maria Date: 151 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 111111111111111111I BY: Maria Date: 151 Comments about this file: Quality Checked 11I1111111111111111 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALASKA SAND GAS CONSERVATION COMMISSI110 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well j- Plug Perforations fl Stimulate SG!r Other Pull Tubing Perforate New Pool Waiver r Alter Casing r g � 9 � r � Time Extension Change Approved Rogram I Operat. Shutdown r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development " Exploratory r ` 204 3. Address: 6. API Number: Stratigraphic r Service J`- r 50- 103- 20496 -60 ©Q P. O. Box 100360, Anchorage, Alaska 99510 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 380075 r 3' 8' 7 A1 2 ..... , CD2 - 09L1 9. Field /Pool(s): Colville River Field / Alpine Oil Pool " 10. Present Well Condition Summary: Total Depth measured 16094 feet Plugs (measured) None true vertical 7197 feet Junk (measured) None Effective Depth measured 16094 feet Packer (measured) 12035 true vertical 7197 feet (true vertucal) 6994 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 3348 9.625" 3385 2380 PRODUCTION 12583 7" 12617 7172 Perforation depth: Measured depth: open hole completion 12617' - 16094' 1 ° 16 True Vertical Depth: 7172'-7197' 0 Caoisiton �,as C °i ` g ` Tubing (size, grade, MD, and TVD) 3.5, L -80, 12102 MD, 7024 TVD t1sr•"d & veel e Packers & SSSV (type, MD, and ND) PACKER - BAKER SAB -3 PACKER @ 12035 MD and 6994 ND SSSV - CAMCO TRM -4E SSSV @ 2282 MD and 1796 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 12167'- 16409' Treatment descriptions including volumes used and final pressure: see attached summary 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 129 1092 704 -- 247 Subsequent to operation 94 1205 1027 -- 265 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development 17 , Service r Stratigraphic r 15. Well Status after work: Oil pi — Gas r WDSPL r Daily Report of Well Operations XXX GSTOR E WINJ r WAG r GINJ r SUSP r SPLUG E 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Tim Schneider @ 265 -6859 Printed Name Tim Schneider Title Wells Engineer Signature / D . r 6 / Phone: 265 -6859 Date RSDMS SEP 14 2011 1'Z3•`/ Form 10 -404 Revised 10/2010 of � Submit Original Only �6 ! Scale Inhibition Treatment CO2 -09 and CD2 -09L1 8/30/2011: Initial pressure TBG /IA/OA- 500/1500/600; facility pumped 50 bbls SW preflush; LRS pumped 2.4 bbls WAW5206 (94 gal) at 0.4 bpm and facility pumped 21 bbls SW, 700/1500/600; LRS pumped 22.3 bbls SCW3001WC (935 gals) at 0.4 bpm and facility pumped 126 bbls of SW, 900/1350/550; LRS pumped 2.4 bbls WAW5206 (94 gal) at 0.3 bpm and facility pumped 21 bbls SW, 1000/1350/550; facility pumped 1201 bbls of SW over - displacement. Y • WNS • CD2 -09L1 Conoc P t lj Well Attributes Max Angle & MD TD Aia .a. Inc fir` ' k W Ilbore APVUWI Field Name Well Status Intl ( °) IMD (ftKB) Act Btm (ftKB) Cds+ocsi*ttlhpa _ 501032049660 ALPINE PROD 9170 14,83770 16,094.0 " Cammant H2S (ppm) Annotation E w� conig CD ? -09L1.7/732pn 8 R547 AM SS �, � I Dale Last WO' �_ d Date 1 KB - Grtl (ft) Rig Release Date 4 17 9/12/2004 Schemepc new 1 - Annotation (Depth (IIKB) End Date Mn tabon Last Mod .. End Date Last Tag: _ Rev Reason_ GLV C/O ninam 7/23/2011 Casin Strings Casing Description Strang 0 String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) . Sg Wt... String I String Top Thrd OPEN HOLE L1 6 1'8 15 833.0 I 16,094.0 I trin ... - HANGER, 33 . M1 -£ N otes: General & Safety . End Date Annotation 9/122004 NOTE: MULTI - LATERAL WELL' THIS VIEW LAl ERAL L) 9/12/2004 NOTE: TREE: FMC 1 -1/16" SD TREE CAP CONNECTION: 7" OTIS .. r CONDUCTOR, .__ 37.114 4 . 1 41.' SAFETY VLV, 2282 t1 El SURFACE, L j 37 -3,385 GAS LIFT, 5,019 GAS LIFT. -.- " " -: 9,615 GAS LIFT, 11,866 SLEEVE, 11,951 I Ti.' PACKER. 12,035 ■ NIPPLE, 12,090— 'AL',+. WLEG, 12,102 Mandrel (ftK �e Top (/ VD)th Top I Make Model OD Sery Type Type Latch G. TRO Run -- Port , (psi) Run Date Com... 1 5,019.0 3,394.4 55.25 CAMCO KBUG 1 GAS LIFT DMV BK -S 0.000 0.0 9/112004 2 9,615.0 5,704.0 55.98 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,838.0 7/19/2011 3 11,863.6 6,908.7 59.03 CAMCO KBUG 1 GAS LIFT OV BK 0.188 0.0 7212011 PRODUCTION, 34- 12,617 WINDOW L1,_ _ i 15,629 - 15.834 OPEN HOLE 11, a 15,833 - 16,094 4.6 TO (CD2-0911), 16,094 ) ° OPEN HOLE, _ .. to 12,617- 16,409 3 • STATE OF ALASKA • ~~! Y ALASKA OIL AND GAS CONSERVATION COMMISSION i~~Y ~A~ ~ n~l, REPORT OF SUNDRY WELL OPERATIONSAi9S4, ~;, ~. „_ ~, ~- 1. operations Performed: Abandon ^ Repair Well ^ Plug Pertorations ^ ~,ti ula Other ~fi1iS • Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ -- Ti1ne Extension f ~~~DU~ < Waiver ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ ~~ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ Exploratory ^ 204-177 / 3. Address: Stratigraphic ^ ,Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20496-60 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 36.T, 53' AMSL CD2-09L1 ' 8. Property Designation: 10. Field/Pool(s): ADL 380075, 387212 Colville River Field /Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 16094' feet true vertical 7197' • feet Plugs (measured) Effective Depth measured 16094' feet Junk (measured) true vertical 7197 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 114' 16" 114' 114' SURFACE 3332' 9-5/8" 3385' 2380' PRODUCTION 12564' 7" 12617' 7172' Perforation depth: Measured depth: open hole completion from 12617'-16094' true vertical depth: 7172'-7197' r~t~ yF; ~S~~~?~ ,~~.'~~ ~~ ~' ~tJt% ~Y Tubing (size, grade, and measured depth) 3.5", L-80, 12102' MD. Packers &SSSV (type & measured depth) Baker sA6-3 pkr @ 12035' Camco SSSV @ 2282' 12. Stimulation or cement squeeze summary: Intervals treated (measured) pumped 88.5 bbl scale squeeze Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 389 1644 239 -- 254 Subsequent to operation 295 1590 229 -- 248 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: OilO Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: none contact Tim Schn ider @ 265-6859 Printed Name Tim ei r „ Title Alpine Staff Engineer Signature / Phone: 265-6859 .Date ~ ~f `v J Pre ar b Shar n Allsu Drake 263-4612 Form 10-404 Revised 04/20 ~{ !~ Submit Original Only , OC€ ConocoPhiili~s Ahskt~l. Vno. MANGER. 33 CONDUCTOR. 114 SSSV, 2.282 SURFACE, 3,385 GAS LIFT, GAS LIFT, 9,615 GAS LIFT 11,86 SLEEVE,- 11,961 PACKER, 12,035 NIPPLE. 12,090 - WLEG. '.2,102 ~ROOUCnoN. 2,61] '~i WINix>W t'. ~ ~., i 6.tl34 f`: OPEN HOLE, -~ 16,409 \ ~ TD (CD2-09), _ _ , 16,409 WNS • Nellbore APVU WI Field Name Well Status I 501032049660 ALPINE (PROD ment H25 (ppm) Annotation End Date Date TRDP I ( ( ( Last WO: 4nnota[ion (Depth (ftKe) (End Data (Annotation Last Taa: Rev Reason: GLV C/O HOLE L1 NOTE: MULTI-LATERAL WELL: THIS VIEW LATERAL L7 NOTE: TREE: FMC 1-1/16" SD TREE CAP CONNECTION: 7" OTIS CD2-09L1 Date WSR -Well Service Report Well Service Report Page 1 of 1 Well Job Scope CPAI Rep CD2-09 Scale Inhibition Shirtliffe, Ryan Date Daily Work Unit Number 4/24/2009 32 Initial & T/I/A Initial - 350/925/450 Final Fietd: ALPINE Final - 0/900/500 Pressures: 2~1 hr. Pump an Aqueous squeeze into well. Squeeze a total of 88.5 bbls at 2.4 bpm and Summary 450 psi. Job pumped as planned. Operations flushed well with manifold. STARTTIME OPERATION 03:00 PM Rig in and pressure test lines to 2000psi. 03:18 PM Pump 8 bbls SW+5206 at 2 bpm and 550 psi, 65.8 bbls SW+3001 at 2.4 bpm and 5C psi, followed by 14.7 bbls SW+5206 at 2.1 bpm and 400 psi. 04:12 PM Rig out eq uipment. Operations to flush and freeze protect well from manifold. .Fluid Type To Well From Well Non- recoverable Note SEAWATER, SCW- 66 3001 WC DIESEL 30 SEAWATER, WAW- 23 5206 http://akapps.conocophillips.net/alaskawelleventquery/worklog.aspx?ID=ADC073... 5/15/2009 • • ~.~;~ y;# ,~~ MICROFILMED. 03/01/2008 DO NOT-PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc · tþ;} J';~) WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 16,2006 RE: MWD Formation Evaluation Logs: CD2-06, CD2-07 _PB1_PB2, CD2-09 _PB1_ L1. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 CD2-06: UJ:Q. 80"3 - I sO¡ # IL/39':f Digital Log Images: 50-103-20470-00 CD2-07 PB1 PB2: U I ~ 003 -1~1- t% 'f-1?/iL{ - - Digital Log Images: 50-103-20472-00,70,71 1 CD Rom 1 CD Rom CD2-09 PB1 L1: - - Digital Log Images: 50-103-20496-00,70,60 1 CD Rom dC>'-! -I gDr # ILI'3q~- 9- ()LÆ (' l-=1- '+ ."1: l...t3D¡G:, SCA1NNED FEB 0 1 2007 (L b~ ~èD~ DATA SUBMITTAL COMPLIANCE REPORT 9/28/2006 API N2ftlf-1t31[¡~~ c( Permit to Drill 2041770 Well Name/No. COLVILLE RIV UNIT CD2-09L 1 Operator CONOCOPHILLIPS ALASKA INC MD 16094"""" TVD 7197 / Completion Date 9/11/2004 ~ Completion Status 1-01L Current Status 1-01L UIC N -~-,- REQUIRED INFORMATION D¡"cao",' so".,@ -~ -".~_.~ Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GRlRes Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Electr Data Digital Dataset Log Log Run Interval OHI t~~:~t Number Name Scale Media No Start Stop CH Received Comments 12824 Gamma Ray r", ~.....:Hv~ ~L¡"'JV-Þ1r 3362 16031 Open 11/9/2004 GRlEWR4/ABI/ROP/PWD/ I DSN/12824 12824 LIS Verification 3362 16031 Open 11/9/2004 GRlEWR4/ABIIROP/PWD/ I DSN 12824 SØ' D Asc I Directional Survey 15791 16094 Open 11/15/2004 IIFR ! ~ \ Directional Survey 15791 16094 Open 11/15/2004 IIFR I !¿ i D Asc Directional Survey 15791 16094 Open 11/15/2004 MWD I 4 Directional Survey 15791 16094 Open 11/15/2004 MWD I ¿ C Lis 13646 Induction/Resistivity 114 16094 Open 2/22/2006 ROP DGR EWR plus I I Graphics I I Well Cores/Samples Information: Sample Set Number Comments Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ~ Analysis ~ Received? Daily History Received? @N (VN Formation Tops Comments: . . Permit to Drill 2041770 MD 16094 TVD Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 9/28/2006 Well NamelNo. COLVILLE RIV UNIT CD2-09L 1 Operator CONOCOPHILLlPS ALASKA INC 7197 ¡;:'"" D,t. 9/'1/20<>1 Completion Status 1-01L API No. 50-103-20496-60-00 Date: Current Status 1-01L UIC N ') D¿)~" . . . . WELL LOG TRANSMITTAL ÞÜ4-\ÎÎ To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 ]'3 LP 4-& RE: MWD Formation Evaluation Logs CD2-09 L1, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 CD2-09 Ll: LAS Data & Digital Log Images: 50-103-20496-60 1 CD Rom ~~ :II ~ ~Ic{p . . ;{oo/ -/7 7 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Wannan 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 November 1, 2004 RE: MWD Formation Evaluation Logs: CD2-09 Ll, AK-MW-3231702 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry-Sun, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-103-20496-60. ¿ )~V~ / ðf~¡·f/~ I rf~( 1a. Well Status: Oil 0 r WELL COMPL~~~IL~~ ~¡¿~:~~~~~~~'~~R~Ä~6t~b Gas U Plugged D Abandoned U Suspended D WAG D A!a~iffiWèiIÖ1~ß 20AAC 25.105 20AAC 25.110 Developmefit"~';"?t" Exploratory D No. of Completions _ Other Service D Stratigraphic Test D 12. Permit to Drill Number: :6INJ D WINJ D 2. Operator Name: ~ ConocoPhillips Alaska, Inc. 3. Address: WDSPL D 1827' FNL, 713' FWL, Sec. 27, T12N, R4E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 371690 y- TPI: x- 365214 y- Total Depth: x- 363566' y- 18. Directional Survey: Yes 0 NoU Zone- 4 Zone-4 Zone- 4 5. Date Comp., Susp., d ~.df or Aband.: September .~ 2004 6. Date Spudded: !.¥~ 71 ¡:..éäl AU~4 _..61> 7. Date TD Reãched: It· (.t.>'f September 8, 2004 ' 8. KB Elevation (It): 36.7' RKB /52.6' AMSL 9. Plug Back Depth (MD + TVD): 16094' MD / 7197' rvD 10. Total Depth (MD + TVD): , 16094' MD / 7197' TVD ~ P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Surface: 1656' FNL, 1552' FEL, Sec. 2, T11 N, R4E, UM At Top Productive Horizon: Total Depth: 21. Logs Run: GR/Res 22. CASING SIZE 16" 9.625" 7" 351' FSL, 2412' FWL, Sec. 27, T12N, R4E, UM WT. PER FT. 62.5# 36# 26# GRADE H-40 J-55 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM Surface 114' Surface 114' Surface 3385' Surface 2380' Surface 12617' Surface 7172' 5974702 I 5982103 5985235 ' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): open hole completion from 12617' - 16094' MD 26. Date First Production October 12, 2004 Hours Tested 10/13/2004 Flow Tubing press. 259 psi 27. 5-3/4 hours Casing Pressure 1064 Production for Test Period --:> Calculated 24-Hour Rate -:> 11. Depth where SSSV set: SSSV @ 2282' 19. Water Depth, if Offshore: N/A feet MSL /,/¡¿)/lU'<9cd HOLE SIZE 42" 12.25" 8.5" 24. SIZE 3.5" 204-1771 13. API Number: 50-103-20496-60 14. Well Name and Number: CD2-09L 1 15. Field/Pool(s): Colville River Field Alpine Oil Pool 16. Property Designation: ALK 380075,387212 17. Land Use Permit: ADL nla 20. Thickness of Permafrost: 1795' MD 13/'69S//j'Jl) "s')) ~//:5:7t/JJ ///'OYr' CEMENTING RECORD AMOUNT PULLED 13 cu yds Portland III 501 sx AS Lite, 241 sx Class G 167 sx Class G TUBING RECORD DEPTH SET (MD) 12102' PACKER SET 12035' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED nla 25. o WATER-BBL o 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". Form 1 0-407 Revised 12/2003 PRODUCTION TEST Method of Operation (Flowing, gas lilt, etc.) Gas Lift Oil - Production shared with CD2-09 OIL-BBL GAS-MCF WATER-BBL 688 631 OIL-BBL GAS-MCF 2540 2072 CORE DATA NONE - - - - ,. - ~ ~ CONTINUED ON REVERSE AL CHOKE SIZE IGAS-OIL RATIO 816 82% OIL GRAVITY - API (corr) nla (py .RB[IASBfL tIW u 2 ?IW1I 28. GEOLOGIC MARKERS. 29. . 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". CD2-09L 1 Seabee Form. Nanushak Gamma Ray Shale Kalubìk Kuparuk Formation Miluveach Top Alpine D Top Alpine C Base Alpine C TO 3446' 5902' 11696' 12123' 12229' 12370' 12478' 12557' 14022' 16094' 2412' 3851' 6821' 7034' 7076' 7125' 7152' 7164' 7173' 7197' OCT 2 6 2004 N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 p~nted Name .L} L ~ Signature /'...J""-"'L \IV\.... Title: Phone Alpine Drilling Team Leader u¡<) - t, I L 0 Date (C) ( 'L rj( O<f- Sharon Allsup-Drake @ 263-4612 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". ¡C'¡\\A' L I,JIÌ\, ' Form 10-407 Revised 12/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-09 CD2-09 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 8/22/2004 Rig Release: 9/12/2004 Rig Number: Spud Date: 8/23/2004 End: Group: 8/22/2004 12:00 - 16:00 4.00 MOVE MOVE MOVE Moved rig to CD2-09 from CD2-05. 16:00 - 17:00 1.00 MOVE RURD MOVE Connected service lines. 17:00 - 19:00 2.00 MOVE RURD MOVE NIU riser and took on spud mud. 19:00 - 20:00 1.00 DRILL PULD SURFAC Brought BHA to rig floor, CIO jars wi HWDP. (Accepted rig @ 1900 hrs) 20:00 - 22:30 2.50 DRILL PULD SURFAC P/U BHA, adjust motor and orient. Plugged in MWD. 22:30 - 23:00 0.50 DRILL SFTY SURFAC Filled stack and checked for leàks. Held PJSM. 23:00 - 23:30 0.50 DRILL PULD SURFAC Orient UBHO, M/U NM flex collars, pressured up and tested mud lines to 3500 psi. 23:30 - 00:00 0.50 DRILL DRLG SURFAC Drilled from 114'-130'. TVD=130' ART=0.3 AST=O ADT=0.3 PUW/SOW/ROT=85K all @ 130' 8/23/2004 00:00 - 00:15 0.25 DRILL PULD SURFAC Change out drilling jars 00:15 - 12:00 11.75 DRILL DRLG SURFAC Drill 12 1/4" hole f/130' to 1258' MD 1182' TVD ADT - 6.76 hrs. = ART - 1.63 hrs AST - 5.13 hrs. WOB 20/30 k RPM 50 GPM 550 @ 1880 psi String wt. PU 120 SO 115 Rot 118 Torque onloff btm - 7000/6500 ft./lbs. 12:00 - 00:00 12.00 DRILL DRLG SURFAC Drill 12 1/4" hole fl 1258' to 2620'. TVD=1973' ART=4.73 AST=2.11 ADT =6.84 WOB 15/25 k RPM 40/60 GPM 650 @ 2550 psi POW=125K SOW=112K ROT=120K TQ on/off=8K/7K all @ 2620'. 8/24/2004 00:00 - 09:00 9.00 DRILL DRLG SURFAC Drill 12 1/4" hole fl 2620' to 3396' MD 2385' TVD ADT - 6.79 hrs. = ART - 5.97 hrs AST - 0.82 hrs. WOB 20/35 k RPM 50 GPM 630 @ 2550 psi String wt. PU 140 SO 118 Rot 128 Torque on/off btm - 800017000 ft./lbs. 09:00 - 10:15 1.25 DRILL CIRC SURFAC Circ 2 X BU @ 650 gpm /2450 psi / 60 rpm Stood back 2 stands while circulating to 3205' Flow check well, static. 10:15 - 10:45 0.50 DRILL WIPR SURFAC Break out tight tool joint and lay down single. 10:45 - 12:30 1.75 DRILL WIPR SURFAC Backream from 3205' to 2275' - 550 gpm /1870 psi / 60 rpm 12:30 - 13:00 0.50 DRILL CIRC SURFAC Backream from 2275' to 2180' - reduced pumps to 340 gpm I 975 psi / 60 rpm due to heavy cuttings on shakers causing mud losses across shakers. 13:00 - 15:00 2.00 DRILL WIPR SURFAC Backream from 2180' to 1419' - 550 gpm /1680 psi /60 rpm Reduced pump rate to 460 gpm from 1419' to 970'. Flow check well, static. 15:00 - 16:15 1.25 DRILL WIPR SURFAC RIH - precautionary ream from 3323' to 3396'. 16:15 - 17:30 1.25 DRILL CIRC SURFAC Circ and condition mud - 650 gpm / 2600 psi I 60 rpm Pumped 35 bbls high vis sweep and circ hole clean. 17:30 - 19:00 1.50 DRILL TRIP SURFAC Flow check (static) POOH on TT f/ 3396' to 1510' - swabbing 19:00 - 19:30 0.50 DRILL TRIP SURFAC Std back 2 stds DP while circulating btms up - 400 gpm @ 1150 psi wi 60 rpm - flow check (static) 19:30 - 20:00 0.50 DRILL TRIP SURFAC Continue to POOH on TT fl 1330' to 880' - pulled 20 k over & swabbing 20:00 - 20:30 0.50 DRILL TRIP SURFAC POOH wi pump f/ 880' to 700' - 400 gpm @ 1000 psi w/ 40 rpm - flow check (static) 20:30 - 00:00 3.50 DRILL TRIP SURFAC Continue to POOH on TT f/700 - SB HWDP & NM flex DC's - Break bit & LD BHA . note - tight spot @ 360' to 350' - pulled 50 k over 8/25/2004 00:00 - 01 :30 1.50 CASE RURD SURFAC RU to run 9 5/8" casing - Held PJSM 01 :30 - 05:00 3.50 CASE RUNC SURFAC Run 9 5/8" 36# J-55 BTC casing as follows: FS(Ray Oil tools Silver bullet) - 2 jts, casing - FC (Weatherford) 2 jts casing (first 4 connections made up w/ BakerLoc - fill pipe & check floats) Worked past tight spot @ 360' - Run casing to 1720', returns diminishing. Printed: 9/22/2004 11 :20:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-09 CD2-09 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 8/22/2004 Rig Release: 9/12/2004 Rig Number: Spud Date: 8/23/2004 End: Group: 8/25/2004 05:00 - 05:30 0.50 CASE CIRC SURFAC CBU - 4 bpm /300 psi initial- 220 psi FCP. Large amount of sand and clay across shakers. 05:30 - 07:30 2.00 CASE RUNC SURFAC Continue running casing f/1720' to 3345' (80 jts. total) - PU hanger & landing jt. . land casing on landing ring w/ shoe @ 3385' & FC @ 3294' PU wt. 160 SO wt. 125 07:30 - 08:00 0.50 CEMENT PULD SURFAC LD fill-up tool, blow down Top Drive, MU cement head and lines. 08:00 - 09:45 1.75 CEMENTCIRC SURFAC Established circ - 4 bpm /380 psi - stage pumps up to 7.5 bpm - circulate and condition mud for cementing. Reciprocated pipe 30' with full returns throughout. PUW 160K SOW 125K Held pre-job safety rneeting for cement opts. 09:45 -11:15 1.50 CEMENT PUMP SURFAC Cemented 9-5/8" casing as follows: Pumped 40 bbls Biozan water wI nut plug for marker - Pressure test lines to 2700 psi - Dropped btm plug - Mixed & pumped 50 bbls MudPushXL 10.5 ppg - 6.0 BPM @ 200 psi - Mix & pump lead slurry ( ASL) @ 10.7 ppg -7.5 BPM @ 280 psi max - Observed nut plug marker @ shakers w/386 bbls lead pumped - pumped down tub (397 bbls total pumped) - switch to tail slurry (G w/ .30% 0065, .20% 0046, 1 % S002) @ 15.8 ppg. 5.6 BPM @ 235 psi max. 11:15-12:00 0.75 CEMENTDISP SURFAC Dropped top plug wI 20 bbls water f/ Dowell - Switch to rig pumps & displace w/9.6 ppg mud @ 8 BPM / 450 to 760 psi - slowed pump to 4.0 BPM @ 2280 stks - Bumped plug @ 2360 stks (2348 projected) FCP 550 psi. - Bumped plugs to 1200 psi - CIP @ 1155 hrs. Check floats - floats held. Had 165 bbls cement returns to surface - with full returns throughout job 12:00 - 12:45 0.75 CASE DEQT SURFAC RU and test casing to 2510 psi, bled to 2420 psi in 30 min. 12:45 - 13:30 0.75 CASE RURD SURFAC RD cement head and casing equipment - LD landing joint. 13:30 - 15:00 1.50 DRILL PULD SURFAC NO flowline, riser and FMC speed adaptor. 15:00 - 18:30 3.50 WELCTL NUND SURFAC NU FMC wellhead - NU BOPE 18:30 - 23:00 4.50 WELCTL BOPE SURFAC PJSM - RU & Test BOPE - Hydril to 250 psi & 3500 psi - pipe rams,blind rams, choke & kill line valves, choke manifold valves, TD IBOP valves, floor TIW & dart valves to 250 psi & 5000 psi - performed accumulator closure test - wittnessing of test waived by Lou Grimaldi AOGCC 23:00 - 00:00 1.00 DRILL OTHR SURFAC Pull test plug - set wear bushing - PU drilling bails & DP elevators 8/26/2004 00:00 - 04:00 4.00 DRILL PULD SURFAC RIH, picking up 4" drill pipe to 3050'. POH, stood back 32 stands drill pipe. 04:00 - 04:45 0.75 DRILL PULD SURFAC PU Geospan skid, spot on rig floor and hook up mud lines. 04:45 - 06:30 1.75 DRILL PULD SURFAC MU BHA #2: PDC - Geo-Pilot - Flex jt - IBS - LWD /IBS / HCIM / TM Initialise tools. 06:30 - 07:30 1.00 DRILL PULD SURFAC MU float sub - flex collars - IBS - HWDP - PU new jars Change running tools to 4". 07:30 - 10:30 3.00 DRILL PULD SURFAC RIH - picked up 78 joints of 4" drill pipe to 1786. Shallow te$t LWD - RIH to 3024' 10:30 - 12:00 1.50 RIGMNT RSRV SURFAC Slip and cut drilling line - Service Top Drive and Drawworks. 12:00 - 15:00 3.00 CEMENT DSHO SURFAC Wash down and tagged wiper plugs @ 3292'. Drill out plugs, FC, cement, FS. Cleaned out rathole to 3396' and drilled 20' of new hole to 3416'. 550 gpm I 2360 psi / 90 rpm 15:00·15:30 0.50 DRILL CIRC SURFAC Change over to 9.6 ppg LSND mud - 650 gpm /2950 psi /90 rpm 15:30 - 16:15 0.75 CEMENT FIT SURFAC Pull up to 3374' - RU and perform PIT - Established LO @ 17.8 ppg EMW. 16:15 - 00:00 7.75 DRILL DRLG INTRM1 Drill 8 1/2" hole w/ GeoPilot f/ 3416' to 4540' MD - 3097' TVD - ADT - Printed: 9/22/2004 11 :20:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-09 CD2-09 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 8/22/2004 Rig Release: 9/12/2004 Rig Number: Spud Date: 8/23/2004 End: Group: 8/26/2004 16:15 - 00:00 7.75 DRILL DRLG INTRM1 4.6 Hrs. WOB 8/15 k RPM 90/150 GPM 630 @ 2380 psi String wt. PU 155 SO 105 Rot 120 Torque on/off btm. - 9500/8000 ftJlbs. ECD - 10.4 to 11.2 8/27/2004 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Drill 8 1/2" hole w/ GeoPilot f/4540' to 6078' MD - 3938' TVD - ADT 7.5 hrs. WOB 10/25 RPM 90/170 GPM 670 @ 3600 psi String wt. PU 175 SO 115 Rot 135 Torque on/off btm. - 10,500/10,000 ftJlbs. ECD - 11.4 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drill 8 1/2" hole w/ GoePilot f/6078' to 7606' MD - 4705' TVD - ADT - 6 hrs. WOB 10/20 k RPM 170 GPM 670 @ 3750 psi String wt. PU 210 So 112 Rot 145 Torque on/off btm - 12,500/12,000 ftIIbs. ECD - 10.7 8/28/2004 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Drill 8 1/2" hole w/ GeoPilot f/7606' to 9421' MD - 5590' TVD - ADT - 7.9 hrs. WOB 15/20 k RPM 170 GPM 670 @ 3960 psi String wt. PU 255 So 115 Rot 155 Torque on/off btm - 16,000/15,000 ft/lbs. ECD = 10.8 - 10.9 ppg 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drill 8 1/2" hole w/ GeoPilot f/9421' to 11,020' MD - 6477' TVD - ADT - 7.75 hrs. WOB 15/25 k RPM 165 GPM 670 @ 3550 psi String wt. PU 280 So 120 Rot 170 Torque on/off btm. - 18,000/16,000 ECD = 10.7 - 10.8 ppg 8/29/2004 00:00 - 11 :30 11.50 DRILL DRLG INTRM1 Drill 8 1/2" hole wI GeoPilotf/11 ,020' t012,377' MD - 7126' TVD - ADT- 8.02 hrs. WOB 10/20 k RPM 165 GPM 670 @ 4000 psi String wt. PU 240 So 140 Rot 178 Torque onloff btm. - 15,000/14,000 ECD = 10.7 - 10.8 ppg 11 :30 - 13:00 1.50 DRILL CIRC INTRM1 Unable to obtain required build rate with Geo-Pilot. Pumped 40 bbls high vis sweep and circ hole clean 630 gpm / 3880 pai /160 rpm 13:00 - 16:15 3.25 DRILL TRIP INTRM1 Backream from 12,377' to 11 ,616' - 500 gpm / 2730 psi/120 rpm no problems. POOH on trip tank from 11,616' to 10,933', unable to pass 10933' with 45K over. Backream from 10,948' to 10,757' 500 gpm 12750 psi /120 rpm. POOH on trip tank from 10,757' to 9803', 10-20K drag, hole took proper fill. Pump dry job. 16:15 - 20:30 4.25 DRILL TRIP INTRM1 POOH on trip tank from 9803' to 640' - std. back Ghost reamers, HWDP, & jars 20:30 - 23:30 3.00 DRILL PULD INTRM1 Hnadle BHA - Inspect GeoPilot & break off bit while downloading MWD - LD GeoPilot & GP flex w/ OM - Pull & reinstall pulser 23:30 - 23:45 0.25 DRILL PULD INTRM1 LD Geospan skid f/ rig floor 23:45 - 00:00 0.25 DRILL PULD INTRM1 PU 7" mud motor 8/30/2004 00:00 - 01 :30 1.50 DRILL PULD INTRM1 MU BHA #3: PDC - 7" SperryDrill @ 1.5 - OM - IBS - LWD/PWD - IBS - HCIM - TM, Printed: 9/22/2004 11 :20:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-09 CD2-09 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 8/22/2004 Rig Release: 9/12/2004 Rig Number: Spud Date: 8/23/2004 End: Group: 8/30/2004 00:00 - 01 :30 1.50 DRILL PULD INTRM1 Scribe tools. 01 :30 - 05:30 4.00 DRILL TRIP INTRM1 MU nmdc's, shallow test tools - MU remainder of BHA and RIH to 8400', filled pipe every 20 stds. 05:30 - 06:00 0.50 DRILL CIRC INTRM1 Fill pipe - establish circ and stage pumps up to 500 gpm - circ and cond mud - 9.6 ppg in 10.4 ppg out. 06:00 - 08:00 2.00 DRILL TRIP INTRM1 RIH to 12190', no problems. 08:00 - 09:15 1.25 DRILL CIRC INTRM1 Stage pumps up to 550 gpm 1 3800 psi / 80 rpm / ECD - 11.1 ppg Precautionary ream from 12190' to 12377' while CBU - FCRlP 588 gpm /3940 psi 1 80 rpm 1 ECD - 10.5 ppg 09:15 - 11 :30 2.25 DRILL DRLG INTRM1 Drill 8 1/2" hole from 12,377' to 12,472' MD -7151' TVD- ADT = 1.45 hrs. ART - 0.45 hrs. AST - 1.0 hrs. WOB 10/20 k RPM 80 GPM 560 @ 3950 psi String wt. PU 270 So 145 Rot 175 Torque on/off btm. - 15,500/13,000 ECD = 10.7 - 10.8 ppg 11 :30 - 15:00 3.50 DRILL DRLG INTRM1 Drill 8 1/2" hole from 12,472' to 12,629 MD - 7173' TVD - ADT = 1.71 hrs. ART - 0.15 hrs. AST - 1.56 hrs. WOB 10/20 k RPM 80 GPM 560 @ 3970 psi String wt. PU 280 So 145 Rot 175 Torque on/off btm. - 15,500/13,000 ECD = 10.4 ppg 15:00 - 16:15 1.25 DRI LL CIRC INTRM1 Pump high vis sweep and circ hole clean 625 gpm /4020 psi / 80 rpm Final ECD = 10.2 ppg 16:15 -17:45 1.50 DRILL WIPR INTRM1 Backream from 12629' to 11580' - 550 gpm /3210 psi / 80 rpm - no problems. 17:45 - 18:30 0.75 DRILL TRIP INTRM1 Flow check (static) RIH f/11580' to 12530' - hole slick going in 18:30 - 20:45 2.25 DRILL CIRC INTRM1 Wash & ream f/12530' to 12629' - Pump sweep & bump mud wt. to 9.8 ppg for trip - Flow check (static) - Spot lub pill in drill pipe 20:45 - 21 :45 1.00 DRILL TRIP INTRM1 POOH w/ pump spotting lub pill @ 3 bbls/min f/12620' to 11658' - Flow check (static) 21 :45 - 00:00 2.25 DRILL TRIP INTRM1 POOH on IT f/11658' to 9730' - hole taking proper fill - Pumped dry job 8/31/2004 00:00 - 04:30 4.50 DRILL TRIP INTRM1 POOH from 9730' to 621' - hole slick coming out - flow checked @ shoe, static. 04:30 - 05:00 0.50 DRILL TRIP INTRM1 POOH - stand back hwdp & nmdc's - LD jars. 05:00 - 06:30 1.50 DRILL PULD INTRM1 Flush tools - down load LWD - LD TM - HCIM - IBS - LWD/PWD - IBS - OM - motor & bit. 06:30 - 07:00 0.50 DRI LL OTHR INTRM1 Clear tools from rig floor - pull wear bushing. 07:00 - 08:30 1.50 WELCTL OTHR INTRM1 Set test plug - change top pipe rams to 7" - test rams to 250 / 5000 psi. LD test joint and plug. 08:30 - 10:00 1.50 CASE RURD INTRM1 RU to run 7" casing. 10:00 - 10:15 0.25 CASE SFTY INTRM1 Held Pre-job safety and opts meeting with crew. 10:15 - 15:15 5.00 CASE RUNC INTRM1 Run 7" 26# L-80 BTCM as follows: FS - 2 jts. - FC - 135 jts. to 5652' - (Baker Loc 1st four connections - pump through string on jt. #4 to check floats) install straight blade centralizers on first 15 jts. PUW 195K SOW 135K 15:15 - 15:45 0.50 CASE CIRC INTRM1 Establish circ @ 3.7 bpm 1 400 psi - stage pumps up to 7.0 bpm - reciprocate pipe, circ and cond mud - 180 bbls pumped - FCR/P 7.0 bpm 1 590 psi. 15:45 - 18:30 2.75 CASE RUNC INTRM1 Ran 7" casing 74 Jts. to 8800'. 18:30 - 19:15 0.75 CASE CIRC INTRM1 CBU @ 6 BPM 650 PSI. Staged pumps up. 19:15 - 21 :30 2.25 CASE RUNC INTRM1 Ran 7" casing 59 Jts. to 11349'. 21 :30 - 22:30 1.00 CASE CIRC INTRM1 CBU @ 6 BPM 730 PSI. Staged pumps up. Printed: 9/22/2004 11 :20:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-09 CD2-09 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: Rig Release: Rig Number: Spud Date: 8/23/2004 End: Group: 8/22/2004 9/12/2004 8/31/2004 22:30 - 23:30 1.00 CASE RUNC INTRM1 23:30 - 00:00 0.50 CASE OTHR INTRM1 9/1/2004 00:00 - 00:30 0.50 CASE OTHR INTRM1 00:30 - 01 :00 0.50 CASE RUNC INTRM1 01 :00 - 02:00 1.00 CASE CIRC INTRM1 02:00 - 04:30 2.50 CEMENT PUMP INTRM1 04:30 - 05:30 05:30 - 06:30 06:30 - 07:00 07:00 - 08:30 08:30 - 13:00 1.00 CASE MIT 1.00 CASE RURD 0.50 CASE DEQT 1.50 CASE RURD 4.50 WELCTL BOPE INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 13:00 - 13:45 0.75 DRILL PULD INTRM1 13:45 - 17:00 3.25 DRILL PULD INTRM1 17:00 - 21 :00 4.00 DRILL PULD INTRM1 21 :00 - 00:00 3.00 DRILL TRIP INTRM1 9/2/2004 00:00 - 00:30 0.50 DRILL TRIP INTRM1 00:30 - 01 :30 1.00 RIGMNT RSRV INTRM1 01 :30 - 04:00 2.50 CEMENT DSHO INTRM1 04:00 - 05:00 1.00 CEMENTCIRC INTRM1 05:00 - 05:30 0.50 CEMENT LOT INTRM1 05:30 - 07:30 2.00 DRILL DRLH INTRM1 07:30 - 07:45 0.25 DRILL OTHR INTRM1 07:45 - 08:00 0.25 WELCTL OBSV INTRM1 08:00 - 12:00 4.00 DRILL DRLH PROD 12:00 - 00:00 12.00 DRILL DRLH PROD Ran 7" casing 21 Jts. to 12300'. Not getting displaceent on Jt. 292. Worked pipe attempted to Circulated with out success. Laid down Jt. 292. Laid down 1 Joint and attempted to circulate. Pull to 500,000 attempting to come up with out success. Ran 7" casing to 12617' and landed on hanger. Laid down Franks tool and installed cement head. Broke circulation with good returns @ 1.2 BPM and 400 PSI. Staged up to 3 BPM @ 650 PSI in .5 BPM stages. Well Packed off when we reached 3.5 BPM. Cement 7" casing as follows: Pumped 5 bbls CW100 - Test lines to 3700 psi - Pumped 15 bbls Cw100 @ 7.32 ppg 5 bbls/min @ 680 psi - Pumped 30 bbls Mud Push XL 12.5 ppg @ 4.5 bbls/min @ 450 psi - Dropped bottom plug - Mix & pumped 34.5 bbls Class G w/ 0.2% D46, 0.25% 065, 0.40% 0167, .02% XE902 @ 15.8 ppg 4.3 bbls/min @ 350 psi - Dropped top plug w/20 bbls water f/ Dowell - Switched to rig pumps & displaced w/461 bbls 9.8 ppg LSND mud @ 5.5 to 4 bbls/min @ 700 to 1000 psi - bumped plug w/ 1500 psi - CIP @ 0430 hrs. 9/1/2004. Slight returns while pumping job 1% or less- unable to move pipe. Checked floats and tested casing to 3500 PSI for 30 Min. Rigged down cement head and laid down landing joint. Set and tested pack off. Changed out casing bails and changed out 7" rams for VBR's. PJSM - RU & Test BOPE - Hydril to 250 psi & 3500 psi - pipe rams,blind rams, choke & kill line valves, choke manifold valves, TO IBOP valves, floor TIW & dart valves to 250 psi & 5000 psi - performed accumulator closure test - wittnessing of test waived by John Spaulding AOGCC. Pulled test plug and ran wear bushing. Picked up bit and made up BHA. Tested MWD. RIH picking up 129 Jts. DP from pipe shed. RIH to 10900' filling pipe every 2000'. RIH from 10900' to 12300'. Slip and cut drilling line - Service Top Drive Wash down to wiper plugs @ 12528'. Drill plugs, FC, cement, FS, clean out rathole to 12629'. Drill 20' of new hole to 12649'. CBU - 5.0 bpm / 1630 psi / 80 rpm RU and perform PIT - observed leak off @ 11.7 ppg EMW. RD, blow down lines. PJSM. Change well over to 8.3 ppg MOBM 5.5 bpm /1640 psi /80 rpm. Clean shaker pans and possum belly - monitor well - observed slight flow. Shut in well- SIDPP=30 psi SICP = 0 observed pressures for 15 minutes, no change. Drill 6 1/8" horizontal hole from 12,649' to 12,840' MD - 7176' TVD - ADT = 2.25 hrs. ART - 0.7 hrs. AST - 1.55 hrs. WOB 5/12 k RPM 80 GPM 240 @ 2240 psi String wt. PU 245 So 135 Rot 180 Torque on/off btm. - 15,000/15,000 ECD = 9.4 ppg Drill 61/8" horizontal hole from 12,840' to 13,517' MD - 7172' TVD- ADT = 7.92 hrs. ART - 5.76 hrs. AST - 2.16 hrs. WOB 5/10 k RPM 90 GPM 231 @ 2500 psi Printed: 9/22/2004 11 :20:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-09 CD2-09 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 8/22/2004 Rig Release: 9/12/2004 Rig Number: Spud Date: 8/23/2004 End: Group: 9/212004 12:00·00:00 12.00 DRILL DRLH PROD String wt. PU 260 So 130 Rot 175 Torque on/off btm. - 14,000/15,000 ECD = 9.5 ppg 9/3/2004 00:00 - 12:00 12.00 DRILL DRLH PROD Drill 6 1/8" horizontal hole from 13,517' to 13,795 MD -7172' TVD ADT = 6.0 hrs. ART - 1.35 hrs. AST - 4.65 hrs. WOB 5/10 k RPM 90 GPM 231 @ 2500 psi String wt. PU 250 So 130 Rot 180 Torque on/off btm. - 14,000/13,000 ECD = 9.5 ppg 12:00 - 14:15 2.25 DRILL DRLH PROD Drill 6 1/8" horizontal hole from 13,795' to 13,926 MD -7160' TVD ADT = 1.14 hrs. ART - 1.25 hrs. AST - 0.16 hrs. WOB 5/10 k RPM 90 GPM 231 @ 2500 psi String wt. PU 250 So 130 Rot 180 Torque on/off btm. - 14,000/13,000 ECD = 9.5 ppg 14:15 - 15:45 1.50 DRILL CIRC PROD CBU for Geologist - 230 gpm / 2500 psi /90 rpm - Discuss sidetrack options with town Geologist and Drilling Engineer. 15:45 - 16:15 0.50 DRILL TRIP PROD Backream from 13,926' to 13644' - 230 gpm /2500 psi /90 rpm 16:15 - 00:00 7.75 DRILL DRLG PROD Rotary sidetrack well time drilling from 13,695' to 13,735'. TVD 7172'. ADT = 6.92 hrs. ART - 6.92 hrs. AST - 0 hrs. WOB 1/3 k RPM 90 GPM 231 @ 2300 psi String wt. PU 245 So 130 Rot 175 Torque on/off btm. - 15,000/14,000 9/4/2004 00:00 - 12:00 12.00 DRILL DRLH PROD Drill 6 1/8" horizontal hole from 13,735' to 13,930 MD -7171' TVD ADT = 7.31 hrs. ART - 0.33 hrs. AST - 6.98 hrs. WOB 3/8 k RPM 0/90 GPM 231 @ 2450 psi String wt. PU 250 So 130 Rot 175 Torque on/off btm. - 14,000/13,000 ECD = 9.5 ppg 12:00 - 00:00 12.00 DRILL DRLH PROD Drill 6 1/8" horizontal hole from 13,930' to 14,248 MD -7176' TVD ADT = 9 hrs. ART - 6 hrs. AST - 3 hrs. WOB 5/8 k RPM 0/90 GPM 231 @ 2700 psi String wt. PU 265 So 125 Rot 175 Torque on/off btm. - 14,500/13,000 ECD = 9.6 ppg 9/5/2004 00:00 - 12:00 12.00 DRILL DRLH PROD Drill 6 1/8" horizontal hole from 14,248' to 14,535 MD -7177' TVD ADT = 6.68 hrs. ART - 3.54 hrs. AST - 3.14 hrs. WOB 5/10 k RPM 0/90 GPM 231 @ 2650 psi String wt. PU 265 So 130 Rot 175 Torque on/off btm. - 15,000/14,000 ECD = 9.8-9.9 ppg 12:00 - 21:00 9.00 DRILL DRLH PROD Drill 6 1/8" horizontal hole from 14,535' to 14,895 MD -7168' TVD ADT = 7.32 hrs. ART - 2.77 hrs. AST - 4.55 hrs. WOB 5/10 k RPM 0/90 GPM 231 @ 2650 psi String wt. PU 270 So 130 Rot 175 Torque on/off btm. - 15,000/14,000 ECD = 9.8-10.2 ppg 21 :00 - 00:00 3.00 DRILL CIRC PROD Circulate and condition mud (Hole trying to pack off) to lower ECD. Spikes to 11 + PPG. Pumped Hi Vis sweep. 9/6/2004 00:00 - 01 :30 1.50 DRILL CIRC PROD Circ and cond mud - 231 gpm / 2500 psi / 90 rpm ECD= 9.9 - 10.0 ppg. 01 :30 - 12:00 10.50 DRILL DRLH PROD Drill Drill 6 1/8" horiz. hole from 14,895' to 15,262 MD - 7172' TVD Printed: 9/22/2004 11 :20:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-09 CD2-09 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 8/22/2004 Rig Release: 9/12/2004 Rig Number: Spud Date: 8/23/2004 End: Group: 9/6/2004 01 :30 - 12:00 10.50 DRILL DRLH PROD ADT = 6.9 hrs. ART - 4.6 hrs. AST - 2.3 hrs. WOB 5/8 k RPM 0/90 GPM 231 @ 2700 psi String wt. PU 270 So 125 Rot 175 Torque on/off btm. - 16,500/16,000 ECD = 10.0-10.1 ppg 12:00 - 00:00 12.00 DRILL DRLH PROD Drill Drill 6 1/8" horiz. hole from 15,262' to 15,728 MD -7175' TVD ADT = 7.8 hrs. ART - 6.04 hrs. AST - 1.75 hrs. WOB 5/10 k RPM 0/90 GPM 231 @ 2700 psi String wt. PU 290 So 115 Rot 175 Torque on/off btm. - 17,500/17,000 ECD = 10.0-10.3 ppg 9/7/2004 00:00 - 08:15 8.25 DRILL DRLH PROD2 Drill 6 1/8" horiz. hole from 15,728' to 16,119 MD - 7176' TVD ADT = 5.8 hrs. ART - 5.55 hrs. AST - .25 hrs. WOB 6/9 k RPM 0/100 GPM 231 @ 3040 psi String wt. PU 285 So 115 Rot 175 Torque on/off btm. - 17,500/17,500 ECD = 10.0-10.3 ppg 08:15 - 08:45 0.50 DRILL CIRC PROD2 Circulated to get sweep out of hole and lower ECD. 08:45 - 14:00 5.25 DRILL DRLH PROD2 Drill 6 1/8" horiz. hole from 16,119' to 16,404 MD - 7169' TVD ADT = 4.0 hrs. ART - 2.83 hrs. AST - 1.17 hrs. WOB 7/10 k RPM 0/100 GPM 231 @ 2980 psi String wt. PU 290 So 115 Rot 175 Torque on/off btm. - 17,500/17,000 ECD = 10.0-10.3 ppg 14:00 - 15:15 1.25 DRILL CIRC PROD2 Circulated for sample. 15:15 - 15:30 0.25 DRILL DRLH PROD2 Drill 6 1/8" horiz. hole from 16,404' to 16,409 MD - 7169' TVD ADT = .1 hrs. ART - .1 hrs. AST - O. hrs. WOB 7/10 k RPM 90 GPM 231 @ 2980 psi String wt. PU 290 So 115 Rot 175 Torque on/off btm. - 17,500/17,000 ECD = 10.0-10.3 ppg 15:30 - 16:30 1.00 DRILL CIRC PROD2 Circulated wait on orders. / 16:30 - 17:00 0.50 DRILL TRIP PROD2 POOH to 15,883' to side track well. 17:00 - 00:00 7.00 DRILL DRLH PROD2 Sidetrack and time Drill 6 1/8" horiz. hole from 15,833' to 15,850 MD- 7179' TVD ADT = 6.15 hrs. ART - 6.15 hrs. AST - O. hrs. WOB 1/3 k RPM 95 GPM 231 @ 2650 psi String wt. PU 290 So 115 Rot 175 Torque on/off btm. - 17,500/17,000 ECD = 10.0-10.3 ppg 9/8/2004 00:00 - 07:00 7.00 DRILL DRLH PROD3 Sidetrack and time Drill 6 1/8" horiz. hole from 15,850' to 15,862' MD- 7179.31' TVD ADT = 6.78 hrs. ART - 6.78 hrs. AST - O. hrs. WOB 1/3 k RPM 95 GPM 231 @ 2650 psi String wt. PU 275 So 122 Rot 175 Torque on/off btm. - 16,500/15,000 ECD = 10.0-10.2 ppg 07:00 - 11 :15 4.25 DRILL DRLH PROD3 Sidetrack and slide Drill 6 1/8" horiz. hole from 15,862' to 15,876' MD- 7179.86' TVD ADT = 4.12 hrs. ART - 2.77 hrs. AST - 1.35 hrs. WOB 1/3 k RPM 95 GPM 231 @ 2800 psi String wt. PU 275 So 122 Rot 175 Torque on/off btm. - 16,500/15,000 Printed: 9/22/2004 11 :20:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-09 cD2-09 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: Rig Release: Rig Number: 8/22/2004 9/12/2004 Spud Date: 8/23/2004 End: Group: 9/8/2004 07:00-11:15 4.25 DRILL DRLH PROD3 ECD = 10.0-10.3 ppg 11:15 - 16:30 5.25 DRILL DRLH PROD3 Drill 6 1/8" horiz. hole from 15,886' to 16,094 MD - 7196.52' TVD '- ADT = 4.65 hrs. ART - 4.65 hrs. AST - O. hrs. WOB 1/3 k RPM 95 GPM 231 @ 2650 psi String wt. PU 280 So 120 Rot 175 Torque on/off btm. - 16,000/15,500 ECD = 10.0-10.2 ppg 16:30 - 20:30 4.00 DRILL CIRC PROD3 Circulated sweep and raised MW to 8.8 PPG. 3 BU. 20:30 - 00:00 3.50 DRILL TRIP PROD3 POOH with pump @ 3 BPM to 14150'. Hole packed off. Worked pipe and backreamed to 14080'. Hole packed off numerous times in Shale. 9/9/2004 00:00 - 03:45 3.75 DRILL TRIP PROD3 POOH with pump working through tight hole and pack off to 12,588'. Tried to pull without pump, no success, 03:45 - 1 0:30 6.75 DRILL TRIP PROD3 Continued to POOH with pump @ 3 BPM. 10:30 - 11 :45 1.25 DRILL CIRC PROD3 CBU @ 190 GPM to clean up hole. 11:45 -15:00 3.25 DRILL TRIP PROD3 RIH to 12,600' filling pipe every 2000'. 15:00 - 16:45 1.75 DRILL CIRC PROD3 Pumped sweep and circulated out. 16:45 - 00:00 7.25 DRILL TRIP PROD3 POOH with pump @ 3BPM. Checking every 20 stands to see if we can pull without pump. 9/10/2004 00:00 - 06:45 6.75 DRILL TRIP PROD3 POOH with pump @ 3BPM to 1991 '. Checking every 20 stands to see if we can pull without pump. 06:45 - 08:45 2.00 DRILL TRIP PROD3 Continue POOH to 372' on trip tank. 08:45 - 10:45 2.00 DRILL PULD PROD3 Download MWD and laid down BHA. 10:45 - 12:00 1.25 CMPL TN RURD CMPL TN Pulled wear bushing and rigged up to run completion. 12:00 - 21 :00 9.00 CMPL TN RUNT CMPL TN PJSM and ran completion on 314 Jts. 3.5" 9.3# L 80 EUEM tubing to 9820'. 21 :00 - 22:00 1.00 CMPL TN RURD CMPL TN Rigged up and tested SSSV with control line. 22:00 - 00:00 2.00 CMPL TN RUNT CMPL TN Ran completion 3.5" 9.3# L 80 EUEM tubing to 11,550'. 9/11/2004 00:00 - 02:30 2.50 CMPL TN RUNT CMPL TN Finish RIH w/3 1/2" completion equipment. PU 2 jts 41/2" tbg. MU hanger and test control line portto 5000 psi. Land tbg w/ tail at 12,102'. 02:30 - 03:30 1.00 CMPL TN SEOT CMPL TN RILDS. Install TWC. MU LJ. Test hanger seals to 5000 psi. LD LJ. 03:30 - 04:30 1.00 CMPL TN OTHR CMPL TN MU stack washer and flush BOP. 04:30 - 06:30 2.00 CMPL TN NUND CMPL TN Suck out fluid from stack. ND and set back BOP's. Change out saver sub on top drive. 06:30 - 08:00 1.50 CMPL TN NUND CMPL TN NU tree and control line. Test hanger seals to 5000 psi. 08:00 - 09:00 1.00 CMPL TN SEOT CMPL TN RU lubricator. Test lubricator and tree to 5000 psi. Pull TWC. 09:00 - 09:15 0.25 CMPL TN RURD CMPL TN RU completion manifold and lines. 09:15 - 09:30 0.25 CMPL TN SFTY CMPL TN PJSM with all hands on displacing weill to diesel. 09:30 - 12:15 2.75 CMPLTN CIRC CMPL TN Displace well w/25 bbls LVT-200 and 419 bbls diesel while holding appropriate back pressure on annulus. SIP - 690 psi. 12:15 - 13:00 0.75 CMPL TN OBSV CMPL TN Bleed lines. RU lubricator. Drop ball and rod. 13:00 - 14:15 1.25 CMPL TN PCKR CMPL TN PJSM - test lines to 4200 psi - Test tbg to 3700 psi for 30 mins. - bleed tbg to 700 psi - test annulus to 3500 psi for 30 mins. - Bleed off annulus to O. 14:15 - 16:00 1.75 CMPLTN OTHR CMPL TN Flushed and blew down lines. Installed BPV and secured well. 16:00 - 00:00 8.00 DRILL PULD CMPL TN PJSM Laid down flex collars and excess 4" DP from derrick. Cleaning mud pits while laying down pipe. 9/12/2004 00:00 - 00:30 0.50 CMPL TN PULD CMPL TN Finish LD excess 4" DP from derrick. Move 6 3/4" DC's to OS for rig move. 00:30 - 06:00 5.50 CMPL TN OTHR CMPL TN Clean OBM from rig. Finish cleaning pits. Inject all fluids. Freeze protect injection annulus. Released rig at 0600 hrs. Printed: 9/22/2004 11 :20:43 AM . . 13-Nov-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD2-09 L 1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 15,791.60' MD 15,833.00' MD 16,094.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 .. Ij /! J.. Date/r;' IÛtv) l~~,{ Signed - UJi~ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~. ConocoPhillips Alaska, Inc. Alaska North Slope North Slope, Alaska Alpine CD-2 CD2-09L 1 Job No. AKZZ3231702, Surveyed: 8 September, 2004 Survey Report 14 October, 2004 Your Ref: API 501032049660 Surface Coordinates: 5974701.48 N, 371690.14 E (70020' 20.8123" N, 151002' 28.2910" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 974701.48 N, 128309.86 W (Grid) Surface Coordinates relative to Structure: 258.06 N, 31.77 W (True) Kelly Bushing Elevation: 52.86ft above Mean Sea Level Kelly Bushing Elevation: 52.86ft above Project V Reference Kelly Bushing Elevation: 52. 86ft above Structure 0.- -.C... I -........ --.J ~ SpE!ï"ï"Y-SU:1'1 OAtL..L..tNG SSA.Vtc:EõS A Halliburton Company DEFINITIVE . . Survey Ref: svy440 ConocoPhillips Alaska, Inc. Survey Report for Alpine CD-2 - CD2-09L 1 Your Ref: API 501032049660 Job No. AKZZ3231702, Surveyed: 8 September, 2004 Alaska North Slope North Slope, Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (OI100ft) 15791.60 89.050 330.520 7125.24 7178.10 10130.02 N 8154.84 W 5984969.56 N 363709.84 E 13002.19 Tie On Point 15833.00 89.400 330.420 7125.80 7178.66 10166.04 N 8175.25 W 5985005.92 N 363690.05 E 0.879 13043.16 Window Point 15886.25 86.890 330.890 7127.52 7180.38 10212.42 N 8201.33 W 5985052.75 N 363664.77 E 4.795 13095.81 15981.87 85.100 330.830 7134.20 7187.06 10295.74 N 8247.77 W 5985136.84 N 363619.76 E 1.873 13190.12 16050.33 85.090 330.130 7140.05 7192.91 10355.09 N 8281.38 W 5985196.77 N 363587.17 E 1.019 13257.63 . 16094.00 85.090 330.130 7143.79 7196.65 10392.82 N 8303.05 W 5985234.86 N 363566.15 E 0.000 13300.73 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to 52.86' Above MSL. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 322.260° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 16094.00f1., The Bottom Hole Displacement is 13302.31f1., in the Direction of 321.378° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 15791.60 15833.00 16094.00 7178.10 7178.66 7196.65 10130.02 N 10166.04 N 10392.82 N 8154.84 W 8175.25 W 8303.05 W Tie On Point Window Point Projected Survey . 14 October, 2004 - 10:10 Page 2 of 3 DrillQuest 3.03.06.006 Alaska North Slope Survey tool program for CD2-09L 1 From Measured Vertical Depth Depth (ft) (ft) 0.00 529.00 0.00 527.41 14 October, 2004 - 10:10 To Measured Vertical Depth Depth (ft) (ft) 529.00 16094.00 527.41 7196.65 ConocoPhillips Alaska, Inc. Survey Report for Alpine CD-2 - CD2-09L 1 Your Ref: AP/501032049660 Job No. AKZZ3231702, Surveyed: 8 September, 2004 North Slope, Alaska Survey Tool Description CB-SS-Gyro (CD2-09PB1) MWD+IIFR+MS+SAG (CD2-09PB1) . . Page 3 of 3 DrillQuest 3.03.06.006 . . 13-Nov-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD2-09 L 1 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 15,791.60' MD 15,833.00' MD 16,094.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date rc-A]tJ tÀ~1 Signed :iJ Û~( .."",.^ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~ ConocoPhillips Alaska, Inc. Alaska North Slope North Slope, Alaska Alpine CD-2 CD2-09L 1 (mwd) . Job No. AKMW3231702, Surveyed: 8 September, 2004 Survey Report 14 October, 2004 Your Ref: API 501032049660 Surface Coordinates: 5974701.48 N, 371690.14 E (70020' 20.8123" N, 151002' 28.2910" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . ~ D --L ( Surface Coordinates relative to Project H Reference: 974701.48 N, 128309.86 W (Grid) Surface Coordinates relative to Structure: 258.06 N, 31.77 W (True) Ke/fy Bushing Elevation: 52. 86ft above Mean Sea Level Ke/fy Bushing Elevation: 52. 86ft above Project V Reference Ke/fy Bushing Elevation: 52. 86ft above Structure ---.. -J .--J SpE!f"'If"'IY-SUï1 J:1FtILLING SeFtVrc:es A Halliburton Company Survey Ref: svy444 ConocoPhillips Alaska, Inc. Survey Report for Alpine CD-2 - CD2-09L 1 (mwd) Your Ref: API 501032049660 Job No. AKMW3231702, Surveyed: 8 September, 2004 Alaska North Slope North Slope, Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (01100ft) 15791.60 88.830 331.710 7127.71 7180.57 10258.86 N 8009.03 W 5985095.89 N 363857.83 E 13014.83 Tie On Point 15833.00 89.400 330.420 7128.35 7181.21 10295.09 N 8029.06 W 5985132.46 N 363838.43 E 3.406 13055.74 Window Point 15886.25 86.670 331.960 7130.17 7183.03 1 0341 .72 N 8054.70 W 5985179.52 N 363813.59 E 5.885 13108.31 15981.87 84.870 331.840 7137.23 7190.09 10425.83 N 8099.62 W 5985264.39 N 363770.12 E 1.887 13202.32 16050.33 84.870 331 .490 7143.35 7196.21 10485.85 N 8131.98 W 5985324.95 N 363738.79 E 0.509 13269.59 . 16094.00 84.870 331 .490 7147.25 7200.11 10524.07 N 8152.74 W 5985363.52 N 363718.68 E 0.000 13312.52 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to 52.86' Above MSL. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 322.260° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 16094.00ft., The Bottom Hole Displacement is 13312.52ft., in the Direction of 322.236° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 15791.60 15833.00 16094.00 7180.57 7181.21 7200.11 10258.86 N 10295.09 N 10524.07 N 8009.03 W 8029.06 W 8152.74 W Tie On Point Window Point Projected Survey . 14 October, 2004 - 10:08 Page 2 of 3 DrillQuest 3.03.06.006 ConocoPhillips Alaska, Inc. Survey Report for Alpine CD-2 - CD2-09L 1 (mwd) Your Ref: API 501032049660 Job No. AKMW3231702, Surveyed: 8 September, 2004 Alaska North Slope North Slope, Alaska Survey tool program for CD2-09L 1 (mwd) From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 529.00 0.00 529.00 527.41 16094.00 527.41 CB-SS-Gyro (CD2-09PB1 (mwd» 7200.11 MWD Magnetic (CD2-09PB1 (mwd» . . 14 October, 2004 - 10:08 Page 3 of 3 Dri/fQuest 3.03.06.006 . $~!Æ~! ill) . FRANK H. MURKOWSK', GOVERNOR AI4ASIi& OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 C. Alvord Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Colville River CD2-09L 1 ConocoPhillips Alaska, Inc. Permit No: 204-177 Surface Location: 1656' FNL, 1553' FEL, SEC. 2, TIIN, R4E, UM (per original permit) Bottomhole Location: 1815' FNL, 714 FWL, SEC. 27, T12N, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. ; The permit is for a new wellbore segment of existing well CRU CD2-09, Permit No. 204-129, API No. 50-103-20496-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- (pager). . c ely BY ORDER ~IJHE COMMISSION DATED thisWday of September, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. . . Á/¡ - ~ STATE OF ALASKA ALASKA OIL & GAS COMMISSION PERMIT TO DRILL (form 10-404 Permit to drill template) 1 a. Type of Work: Drilll:J Redrill U 11 b. Current Well Class: Re-entry 0 Stratigraphic Test 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: ExploratoryU Development Oill:J Multiple Zone 0 Service 0 Development Gas 0 Single Zone G 5. Bond: l:J Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 CD2-09L1 6. Proposed Depth: 12. Field/Pool(s): MD: 16094' TVD: 7196' Colville River Field 7. Property Designation: / ALK 380075, 387212 P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 1656' FNL, 1553' FEL, Sec. 2, T11 N, R4E, UM (per original perrr Top of Productive Horizon: 347' FSL, 2374' FWL, Sec. 27, T12N, R4E, UM(perorigil Total Depth: 1815' FNL, 714 FWL, Sec. 27, T12N, R4E, UN.. 4b. Location of Well (State Base Plane Coordinates): IPerforation Depth TVD (It): None None Filing Fee 0 BOP SketchU Drilling programl:J Time v. Depth Plot U Shallow Hazard Analysis 0 Property Plat 0 Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program [2] 20 AAC 25.050 requirements [2] 21. Verbai Approval: Commission Representative: ~ Q. 9'YVì~ Date: ~c.p-\- \0 I~ 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact V. JohnsonlZ.Kuenzler @ 265-6081/1308 Printed Name C. Alvord "''1 Title Alpine Drilling Team Leader '-,} J../Î IJ Phone ¿C"S' - (, 979 Date 9/J % 'f r I ~ Preoared bv Zane Kuenzler Surface: x- 371690.14 16. Deviated wells: Kickoff depth: 300 18. Casing Program Size Hole 42" 12.25" 8.5" 6.125" Casing 16" 9.625" 7" 3.5" 19 Total Depth MD (It): Casing Structural Conductor Surface Intermediate Productior, Liner Perforation Depth MD (It): 20. Attachments: Signature 7? y- 5974701.5 Zone- Alpine River Pool 8. Land Use Permit: 13. Approximate Spud Date: 9/9/2004 It. Maximum Hole Angle: 91° N/A 9. Acres in Property: 2560 14. Distance to Nearest Property: 284' FWL, Sec. 27 Weight 62.5# 36# 26# 9.3# Specifications Grade Coupling H-40 Weld J-55 BTC L-80 BTC-M L-80 EUE-M Length 77' 3353' 12630' 12140' 10. KB Elevation 15. Distance to Nearest PRESENT WELL CONDITION SUMMARY Total Depth TVD (It): Plugs (measured) Length Size 4 (Height above GL): 0 feet Well within Pool: CD2-04, 1487 17. Anticipated Pressure (see 20 AAC 25.035) Max. Downhole Pressure: 3238 psig Setting Depth / Max. Surface Pressure: 2523 psig Quantity of Cement c. f. or sacks (including stage data) Top Bottom MD 37' 37' 37' 32' TVD TVD 37' 37' 37' 32' MD 114' 3390' 12667' 12172' 114' 2390' 7172' 7057' 621 sx AS Lite & 230 sx LiteCrete 145 sx 15.8 ppg G Uncemented (To be completed for Redrill and Re-Entry Operations) I Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) Cement Volume MD TVD Commission Use Only Permit to Drill.. I API Number: . I Permit APpr~vZ. al Number: 2Dt/ -- /í/ 50- /ò3 - 2D cjrt··{.;ó Date: 9/,'} /7 Conditions 01 approval: Samples required 0 Yes .8JNO Mud log required gen sullide measures 0 Yes WNO Directional survey required Other: Isee cover letter for other requirements DYes g No ßYes 0 No ~~~Å_ ~\>~5\-~,,\-<r,~Q\~ \~~~~~EIVED ~:~=~:'ON S¡¡;¡¡.l (l2004~1"f(../ A\'-I COMMISSIONER .,F ORIGINAL Aih..iit)i'ar· . . CD2-09 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) .6-1/8" Hole / Horizontal Production Hole Event Risk Level Lost circulation Low / Mitigation Strategy Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. BOPE drills, Keep mud weight above 8.8 ppg. / Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. H2S drills, detection systems, alarms, standard well control practices, mud scavengers Hole swabbing on trips Moderate Abnormal Reservoir Pressure Medium Hydrogen Sulfide gas Low __ ORIGINAL . . Alpine: CD2-09 ,¡ 1. Drill 6-1/8" horizontal section to well TO. (LWD: GR/RES/PWD) ./ 2. Circulate the hole clean and POOH to sidetrack point +1- 15850' MD. 3. Sidetrack well and drop angle to +1- 85° inclination. Drill until the base of the Alpine is shown on LWD logs. 4. Circulate hole clean and pull out of hole. 5. Run 3-W', 9.3 #, L-80 tubing with SSSV, gas lift mandrels, sliding sleeve, landing nipple and production packer. Land hanger. 6. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 7. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 8. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi 130 mins. 9. Shear open sliding sleeve. Displace tubing and annulus to diesel keeping pressure on the system. 10. Set BPV and secure well. Move rig off. ORIGINAL . . Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-10 will be the closest well to CD2-09. Well separation is 9.9 @ 300' MD. Accounting for survey uncertainties, the ellipse-to-ellipse separation is 4.3' @ 300' MD. Drillina Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. ,I Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumpina Operations: Incidental fluids developed from drilling operations on well CD2-09 will be injected into a permitted annulus on CD2 pad or the class 2 disposal well on CD1 pad. The CD2-09 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. Upon completion of CD2-09 form 10-403, Application for Sundry Operations, will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure == (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi == (12.0 ppg) * (0.052) * (2390') + 1,500 psi == 2,990 psi Pore Pressure == 1,081 psi Therefore Differential == 2991 - 1081 == 1910 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2.992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4.599 psi 7,240 psi 6,154 psi ORIGINAL . . CD2-09 DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 %" Section - 6 1 /8" point -12 W' Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 8.1-8.8 ppg /' PV 10 - 25 10-15 YP 20 - 60 15 - 25 25 -30 Funnel Viscosity 100 - 200 Initial Gels 4-8 1 0-1 5 10 minute gels <18 12-20 API Filtrate NC -10 cc / 30 min 4 -12 cc/30 min (drilling) NA HPHT Fluid Loss at 160 12-14 cc/30 min PH 8.5- 9.0 9.0 -10.0 9.0-9.5 KCL 6% Oil/water ratio Approx. 80/20 Production Hole Section : The horizontal production interval will be drilled with a 80/20 oil/water ratio M-I Versa-Pro mineral oil based drill-in fluid. The base fluid will consist of high flash point (>200 F) mineral oil with 25% by weight calcium chloride as the internal phase. Calcium carbonate bridging material will be added to minimize formation damage. / ASIDE: The current prognosis for reservoir pressure @ TO is +/- 2950 psi from offset well data and current reservoir modeling. This correlates to 7.8-ppg equivalent mud weight @ TO. / ORIGINAL . , . . II 2-09L 1 Completion Diagram 16" Conductor to 114' 3-W' x 4-W' cross-over, 2 jts below 4-Y201anger 3-1/2" Cameo TRM-4E SSSV Nipple (2.813" ID) at 1800' TVO=2285' MD -2.813" X-Over -Single 1j.¡"xO.049" sIs control line 9-5/8" 36 ppf J-55 STC Surface Casing @ 3390' MD I 2390' TVD cemented to surface Cameo KBUG GLM (2.867" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch Packer Fluid mix: Diesel in tubing and annulus 3-1/2" 9.3 ppf L-80 IBT Mod. R3 tubing run with Jet Lube Run'n'Seal pipe dope Completion MD TVD Tubing Hanger 32' 32' 4-W' 12.6 #/ft 1ST-Mod Tubing (2) Crossover 3-1/2", 9.3#/ft, 1ST-Mod Tubing Cameo SAL-O SSSV Nipple 2300' 1800' 3-1/2", 9.3#/ft, 1ST-Mod Tubing Cameo KSUG GLM (2.867" 10) 5283' 3400' 3-1/2", 9.3#/ft, IBT-Mod Tubing Cameo KBUG GLM (2.867" 10) 9593' 5700' 3-1/2", 9.3#/ft, 1ST-Mod Tubing Cameo KSUG GLM (2.867" 10) 11940' 6952' 3-1/2" tubing joints (2) Baker 3-1/2" CMPA sliding sleeve 12020' 6991' wi 2.81" X Profile 3-1/2" tubing joint (2) Baker SAB3 Packer 12100' 7027' with millout extension 3-1/2" tubing joints (1) HES "XN" (2.75" 10)- 66.9º inc 12160' 7052' 3-1/2" 10' pup joint WEG 12172' 7057' Cameo KBUG GLM (2.867" 10) at 5700' TVD for E Dummy with 1" BK-2 Latch Cameo KBUG GLM (2.867" 10) 2 joints above sliding sleeve E Dummy with 1" BK-2 Latch Baker 3- %" CMPA sliding sleeve with 2.81 "IXIProfile set 2 joints above SAB3 packer Pinned for 2865 psi annular shear CW 2.81" X Profile Baker SAB 3 Packer at +/- 12100' MD TOC @ +/- 11817' MD / 6887' TVD (Minimum 500' MD above top of Alpine 16094' MDI 7199'TVD ./ 7" 26 ppf L -80 STC Mod Production Casing @ 12667' MO 17172' TVD @ 85.5º ORIGINAL . . PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size (in) 16 9 5/8 Casing Setting Depth MDfTVD(ft) 114/114 3390 I 2390 12667 I 7172 17065 I 7155 Fracture Gradient (Ibs. I gal) 10.9 14.5 16.0 16.0 Pore pressure (psi) 52 1081 3245 3238 ASP Drilling (psi) 53 1563 2523 N/A 7" N/A . NOTE: The Doyon 195000 psi BOP equipment is adequate. Test BOP's to minimum 3500 psi. . ASIDE: The current prognosis for reservoir pressure @ TD is +1- 2950 psi from offset well data and current reservoir modeling. This correlates to 7.8-ppg equivalent mud weight @ TO. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation 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) ASP == [(FG x 0.052) - 0.1]0 Where: ASP == Anticipated Surface pressure in psi FG == Fracture gradient at the casing seat in Ib/gal 0.052 == Conversion from Ib./gal to psi/ft 0.1 == Gas gradient in psi/ft D == true Vertical depth of casing seat in ft RKB OR 2) ASP == FPP - (0.1 x D) Where; FPP == Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP == [(FG x 0.052) - 0.1] D == [(10.9 x 0.052) - 0.1] x 114 == 53 psi OR ASP == FPP - (0.1 x D) == 1081 - (0.1 x 2390) == 842 psi 2. Drilling below surface casing (9 5/8") ASP == [(FG x 0.052) - 0.1] D == [(14.5 x 0.052) - 0.1] x 2390 == 1563 psi OR ASP == FPP - (0.1 x D) == 3245 - (0.1 x 6947') == 2550 psi 3. Drilling below intermediate casing (7") ASP == FPP - (0.1 x D) == 3238 - (0.1 x 7155') == 2523 psi / ORIGIN¡~L RE: PBU H-ll (PTD 1800680) Hi Jim. The H Pad Operator bled H-11's OA to 400 psi, it did not re-pressure. The well was SIan 9/19 to test it's twin (H-32), the OA is currently on a vac. The TxIA comm was fixed by changing out a DGLV. Attached is a TIO plot, let me know if you have any other questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, xl154 Email: NSUADWWellIntegrityEngineer@bp.com -----Original Message----- From: James Regg [mailto:jim regg@admin.state.ak.us] Sent: Monday, September 20, 2004 3:06 PM To: NSU, ADW Well Integrity Engineer Cc: Winton GAubert Subject: PBU H-11 (PTD 1800680) Inspector did SVS tests at H-pad on 9/12/04; reports that H-11 has following pressures: Tbg -- 350 psi IA -- 1450 psi OA -- 1650 psi There was no mention of a waiver posted for the well and I cannot find any record of notice for pressure >1000psi in OA. Also, there was a report of TxIA communication on 1/10/04; I assume OGLV was changed out to remedy that situation as proposed in 1/10/04 email.. What does your recent TIO data show regarding possible IAxOA communication? Thanks. Jim Content-Description: H-ll no Plot 09-21-04.jpg H-ll TIO Plot 09-21-04.jpg Content-Type: image/jpeg Content-Encoding: base64 1 of 1 9/22/2004 2:26 PM CD2-09 L l.xls Steve, See the attached file with the directional surveys for the lateral on CD2-09. Note that the tie on survey for the lateral is at 15791.60 ft MD. Let me know if you have any questions. Vern Johnson «CD2-09 L1.xls» Content-Description: CD2-09 Ll.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 lofl 9/22/20042:12 PM ConocoPhillips Alaska Inc. Colville River Unit Alpine CD2 Plan: CD2-09 Plan: CD2-09 L 1 (Rig Surveys) MD Inc Azim. TVD N/S EIW Y X DLS V.S. Comment (ft) (De) De ) (ft) (ft) (ft) ft (ft) °1100ft (ft) 36.10 0.00 0.00 -15.90 36.10 0.00 N 0.00 E 5974701.48 N 371690.14 E 0.00 0.00 80.00 0.30 170.00 28.00 80.00 0.11 S 0.02 E 5974701.37 N 371690.16 E 0.68 -0.10 170.00 0.30 150.00 118.00 170.00 0.55 S 0.18 E 5974700.93 N 371690.31 E 0.12 -0.54 259.00 1.00 310.00 207.00 259.00 0.25 S 0.30 W 5974701.23 N 371689.84 E 1.45 0.00 350.00 4.00 318.00 297.90 349.90 2.62 N 3.03 W 5974704.15 N 371687.15 E 3.31 3.95 . 439.00 7.00 316.00 386.48 438.48 8.83 N 8.88 W 5974710.46 N 371681.42 E 3.38 12.46 529.00 10.60 324.00 475.41 527.41 19.47 N 17.56 W 5974721.25 N 371672.92 E 4.22 26.20 567.24 11.60 323.62 512.93 564.93 25.41 N 21.90 W 5974727.26 N 371668.68 E 2.62 33.54 656.67 16.58 321.57 599.64 651.64 42.66 N 35.18 W 5974744.73 N 371655.70 E 5.60 55.29 746.27 16.16 320.02 685.61 737.61 62.23 N 51.13 W 5974764.57 N 371640.08 E 0.68 80.54 835.82 18.48 322.98 771.10 823.10 83.11 N 67.69 W 5974785.73 N 371623.89 E 2.77 107.19 925.29 23.00 322.77 854.75 906.75 108.36 N 86.81 W 5974811.31 N 371605.20 E 5.05 138.83 1020.78 27.31 319.52 941.17 993.17 139.90 N 112.33 W 5974843.27 N 371580.23 E 4.74 179.39 1115.55 34.74 315.35 1022.33 1074.33 175.70 N 145.47 W 5974879.63 N 371547.71 E 8.16 228.11 1211.19 39.15 315.78 1098.75 1150.75 216.74 N 185.70 W 5974921.35 N 371508.19 E 4.62 285.37 1306.49 41.39 314.44 1171.46 1223.46 260.37 N 229.18 W 5974965.71 N 371465.47 E 2.52 346.71 1401.74 43.26 318.56 1241.89 1293.89 306.89 N 273.28 W 5975012.98 N 371422.18 E 3.51 410.67 1496.98 47.99 316.67 1308.48 1360.48 357.13 N 319.18 W 5975063.99 N 371377.14 E 5.17 478.63 1592.24 52.04 317.32 1369.68 1421.68 410.50 N 368.95 W 5975118.20 N 371328.30 E 4.28 551 .48 1687.28 54.81 315.81 1426.31 1478.31 465.90 N 421.43 W 5975174.49 N 371276.78 E 3.18 627.63 1781.86 59.23 314.72 1477.78 1529.78 522.24 N 477.27 W 5975231.76 N 371221.92 E 4.77 706.63 1877.51 56.12 315.04 1528.92 1580.92 579.26 N 534.54 W 5975289.75 N 371165.64 E 3.26 787.07 1972.81 55.37 313.85 1582.57 1634.57 634.42 N 590.77 W 5975345.86 N 371110.36 E 1.30 865.42 2068.04 57.62 316.64 1635.14 1687.14 690.81 N 646.65 W 5975403.20 N 371055.46 E 3.40 944.49 2161.14 59.80 317.90 1683.49 1735.49 749.25 N 700.62 W 5975462.55 N 371002.50 E 2.61 1023.92 . 2258.52 6D.43 317.93 1732.01 1784.01 811.91 N 757.21 W 5975526.16 N 370947.00 E 0.65 1108.28 2354.00 58.21 317.96 1780.73 1832.73 872.88 N 812.21 W 5975588.06 N 370893.06 E 2.33 1190.31 2449.49 57.64 317.55 1831.43 1883.43 932.78 N 866.60 W 5975648.87 N 370839.70 E 0.70 1271.14 2544.32 57.26 315.49 1882.46 1934.46 990.78 N 921.60 W 5975707.80 N 370785.70 E 1.87 1350.89 2639.37 56.45 316.60 1934.43 1986.43 1048.06 N 976.84 W 5975766.02 N 370731.46 E 1.30 1430.24 2734.76 57.41 320.21 1986.49 2038.49 1107.84 N 1029.88 W 5975826.69 N 370679.45 E 3.33 1510.11 2829.98 57.68 321.08 2037.59 2089.59 1169.96 N 1080.83 W 5975889.67 N 370629.58 E 0.82 1590.46 2925.19 58.95 317.77 2087.61 2139.61 1231.48 N 1133.53 W 5975952.07 N 370577.94 E 3.25 1671.45 3020.22 58.87 317.43 2136.68 2188.68 1291.57 N 1188.40 W 5976013.09 N 370524.11 E 0.32 1752.73 3115.13 58.94 316.20 2185.70 2237.70 1350.83 N 1244.02 W 5976073.29 N 370469.52 E 1.11 1833.84 3209.87 58.86 316.45 2234.64 2286.64 1409.50 N 1300.04 W 5976132.91 N 370414.51 E 0.24 1914.76 3304.88 57.92 316.53 2284.43 2336.43 1468.19 N 1355.75 W 5976192.53 N 370359.82 E 0.99 1995.49 3347.25 58.00 316.37 2306.91 2358.91 1494.22 N 1380.49 W 5976218.98 N 370335.53 E 0.37 2031.32 9/22/2004 1 of 5 2:16 PM ConocoPhillips Alaska Inc. Colville River Unit Alpine CD2 Plan: CD2-09 Plan: CD2-09 L 1 (Rig Surveys) MD Inc Azim. SSTVD TVD NIS E/W y X DLS V.S. Comment (ft) (Deg) (De) (ft) (ft) ft) ft (ft ft °1100ft (ft) 3386.00 58.00 316.37 2327.45 2379.45 1518.00 N 1403.17 W 5976243.15 N 370313.27 E 0.00 2064.10 3396.00 58.00 316.37 2332.75 2384.75 1524.14 N 1409.02 W 5976249.38 N 370307.52 E 0.00 2072.56 3474.45 56.90 315.34 2374.96 2426.96 1571.59 N 1455.07 W 5976297.61 N 370262.29 E 1.79 2138.48 3569.66 55.93 316.20 2427.62 2479.62 1628.42 N 1510.40 W 5976355.38 N 370207.95 E 1.27 2217.54 3665.56 54.94 315.73 2482.03 2534.03 1685.20 N 1565.29 W 5976413.08 N 370154.04 E 1.11 2296.28 . 3761.12 53.82 316.73 2537.69 2589.69 1741.29 N 1619.03 W 5976470.07 N 370101.28 E 1.45 2373.75 3855.85 52.41 317.36 2594.54 2646.54 1796.74 N 1670.66 W 5976526.40 N 370050.61 E 1.58 2449.39 3951.36 51.62 317.43 2653.32 2705.32 1852.15 N 1721.62 W 5976582.66 N 370000.61 E 0.83 2524.56 4046.84 50.53 318.93 2713.32 2765.32 1907.49 N 1771.15 W 5976638.85 N 369952.03 E 1.67 2598.78 4142.32 49.21 317.81 2774.85 2826.85 1962.06 N 1819.64 W 5976694.23 N 369904.49 E 1.65 2671.74 4237.96 48.83 318.16 2837.57 2889.57 2015.70 N 1867.97 W 5976748.69 N 369857.09 E 0.48 2743.88 4333.40 48.33 318.49 2900.71 2952.71 2069.16 N 1915.55 W 5976802.95 N 369810.43 E 0.59 2815.40 4429.04 47.41 319.66 2964.87 3016.87 2122.75 N 1962.02 W 5976857.31 N 369764.89 E 1.32 2886.31 4524.26 46.83 320.49 3029.67 3081.67 2176.25 N 2006.80 W 5976911.58 N 369721.03 E 0.88 2956.08 4619.66 47.69 320.12 3094.41 3146.41 2230.16 N 2051.55 W 5976966.24 N 369677.22 E 0.95 3026.15 4715.11 49.14 320.57 3157.76 3209.76 2285.13 N 2097.11 W 5977021.97 N 369632.61 E 1.56 3097.54 4810.51 52.09 320.75 3218.29 3270.29 2342.15 N 2143.84 W 5977079.78 N 369586.86 E 3.10 3171.26 4906.01 53.82 322.28 3275.82 3327.82 2401.82 N 2191.27 W 5977140.25 N 369540.47 E 2.22 3247.47 5001.48 54.49 321.43 3331.73 3383.73 2462.68 N 2239.07 W 5977201.91 N 369493.72 E 1.01 3324.83 5096.91 55.58 321.78 3386.42 3438.42 2523.97 N 2287.64 W 5977264.02 N 369446.21 E 1.18 3403.01 5192.57 55.99 322.09 3440.21 3492.21 2586.25 N 2336.41 W 5977327.12 N 369398.52 E 0.51 3482.09 5287.93 59.72 323.73 3490.94 3542.94 2650.66 N 2385.07 W 5977392.35 N 369350.97 E 4.17 3562.73 5383.50 59.93 322.14 3538.98 3590.98 2716.58 N 2434.87 W 5977459.11 N 369302.31 E 1.46 3645.26 5478.90 59.94 322.67 3586.77 3638.77 2782.00 N 2485.24 W 5977525.37 N 369253.07 E 0.48 3727.78 5574.31 59.57 322.84 3634.83 3686.83 2847.61 N 2535.12 W 5977591.82 N 369204.32 E 0.42 3810.13 . 5669.74 59.21 323.68 3683.42 3735.42 2913.43 N 2584.25 W 5977658.46 N 369156.33 E 0.85 3892.15 5765.30 60.58 322.24 3731.36 3783.36 2979.41 N 2634.05 W 5977725.28 N 369107.67 E 1.94 3974.73 5860.70 60.39 316.41 3778.39 3830.39 3042.33 N 2688.12 W 5977789.12 N 369054.69 E 5.32 4057.69 5956.26 60.42 313.12 3825.59 3877.59 3100.84 N 2747.11 W 5977848.62 N 368996.72 E 2.99 4140.37 6051.59 59.71 313.28 3873.16 3925.16 3157.39 N 2807.33 W 5977906.18 N 368937.48 E 0.76 4222.33 6147.38 58.64 313.79 3922.24 3974.24 3214.04 N 2866.96 W 5977963.85 N 368878.83 E 1.21 4304.00 6242.95 58.58 314.42 3972.02 4024.02 3270.82 N 2925.54 W 5978021.62 N 368821.23 E 0.57 4385.09 6338.54 58.54 314.44 4021.88 4073.88 3327.92 N 2983.78 W 5978079.69 N 368763.98 E 0.05 4466.21 6434.18 58.35 315.12 4071.93 4123.93 3385.32 N 3041.63 W 5978138.08 N 368707.13 E 0.64 4547.32 6529.77 60.58 312.29 4120.50 4172.50 3442.18 N 3101.16 W 5978195.94 N 368648.59 E 3.46 4629.08 6625.66 61.49 313.11 4166.94 4218.94 3499.07 N 3162.81 W 5978253.88 N 368587.93 E 1.21 4712.22 6721.08 61.84 314.28 4212.23 4264.23 3557.09 N 3223.53 W 5978312.92 N 368528.21 E 1.14 4795.63 6816.92 61.34 313.97 4257.83 4309.83 3615.78 N 3284.04 W 5978372.63 N 368468.72 E 0.59 4879.43 9/22/2004 20f5 2:16 PM ConocoPhillips Alaska Inc. Colville River Unit Alpine CD2 Plan: CD2-09 Plan: CD2-09 L 1 (Rig Surveys) MD Inc Azim. SSTVD TVD NIS EIW y X DLS V.S. Comment (ft) (De) (Deg) (ft) (ft) ft) (ft (ft) ft °1100ft ft) 6912.30 60.79 314.94 4303.98 4355.98 3674.24 N 3343.62 W 5978432.10 N 368410.15 E 1.06 4962.46 7007.09 60.42 314.76 4350.50 4402.50 3732.49 N 3402.17 W 5978491.33 N 368352.61 E 0.42 5044.66 7102.58 60.49 315.63 4397.59 4449.59 3791.43 N 3460.71 W 5978551.26 N 368295.09 E 0.80 5127.39 7197.94 60.42 315.69 4444.61 4496.61 3850.76 N 3518.70 W 5978611.57 N 368238.14 E 0.09 5210.07 7293.44 60.57 316.41 4491.65 4543.65 3910.60 N 3576.38 W 5978672.38 N 368181.49 E 0.68 5292.95 . 7388.86 60.40 316.47 4538.66 4590.66 3970.77 N 3633.60 W 5978733.52 N 368125.31 E 0.19 5375.79 7484.26 60.15 316.92 4585.96 4637.96 4031.06 N 3690.43 W 5978794.77 N 368069.53 E 0.49 5458.46 7579.82 59.85 316.09 4633.74 4685.74 4091.10 N 3747.39 W 5978855.77 N 368013.61 E 0.82 5541.03 7675.29 60.29 315.80 4681.37 4733.37 4150.56 N 3804.92 W 5978916.20 N 367957.11 E 0.53 5623.52 7768.64 60.76 315.70 4727.31 4779.31 4208.77 N 3861.62 W 5978975.37 N 367901.41 E 0.51 5704.52 7865.43 61.37 317.14 4774.14 4826.14 4270.13 N 3920.01 W 5979037.71 N 367844.09 E 1.45 5789.03 7960.88 61.48 317.70 4819.79 4871.79 4331.85 N 3976.73 W 5979100.39 N 367788.44 E 0.53 5872.74 8056.36 61.27 317.75 4865.53 4917.53 4393.87 N 4033.11 W 5979163.36 N 367733.13 E 0.23 5956.46 8151.76 61.27 318.38 4911.39 4963.39 4456.10 N 4089.01 W 5979226.53 N 367678.31 E 0.58 6040.05 8247.40 60.92 318.50 4957.62 5009.62 4518.74 N 4144.56 W 5979290.11 N 367623.85 E 0.38 6123.72 8342.83 60.85 318.63 5004.05 5056.05 4581.25 N 4199.73 W 5979353.55 N 367569.76 E 0.14 6207.05 8438.66 60.86 318.65 5050.72 5102.72 4644.07 N 4255.04 W 5979417.30 N 367515.54 E 0.02 6290.71 8534.49 61.12 317.92 5097.20 5149.20 4706.63 N 4310.80 W 5979480.80 N 367460.85 E 0.72 6374.46 8629.92 60.65 317.72 5143.63 5195.63 4768.41 N 4366.78 W 5979543.52 N 367405.94 E 0.53 6457.75 8725.41 60.18 317.72 5190.77 5242.77 4829.85 N 4422.65 W 5979605.90 N 367351.14 E 0.49 6540.70 8820.86 60.06 317.69 5238.33 5290.33 4891.07 N 4478.34 W 5979668.06 N 367296.51 E 0.13 6623.37 8916.35 60.30 317.43 5285.81 5337.81 4952.21 N 4534.25 W 5979730.14 N 367241.66 E 0.35 6706.12 9012.14 60.72 316.29 5332.97 5384.97 5013.04 N 4591.26 W 5979791.94 N 367185.70 E 1.13 6789.34 9107.24 59.78 314.98 5380.16 5432.16 5072.07 N 4648.99 W 5979851.94 N 367129.00 E 1.55 6871.62 . 9202.63 59.13 314.83 5428.64 5480.64 5130.06 N 4707.18 W 5979910.92 N 367071.82 E 0.70 6953.40 9298.14 58.14 315.09 5478.35 5530.35 5187.69 N 4764.88 W 5979969.52 N 367015.11 E 1.06 7034.59 9393.85 56.98 316.41 5529.69 5581.69 5245.54 N 4821.25 W 5980028.32 N 366959.75 E 1.68 7115.09 9489.64 56.60 315.75 5582.15 5634.15 5303.27 N 4876.84 W 5980086.99 N 366905.16 E 0.70 7195.01 9585.26 56.24 315.82 5635.04 5687.04 5360.37 N 4932.39 W 5980145.02 N 366850.59 E 0.38 7274.42 9680.77 55.99 315.81 5688.29 5740.29 5417.22 N 4987.66 W 5980202.81 N 366796.32 E 0.26 7353.46 9776.39 56.02 316.20 5741.75 5793.75 5474.26 N 5042.72 W 5980260.78 N 366742.24 E 0.34 7432.50 9872.14 56.16 316.04 5795.17 5847.17 5531.53 N 5097.80 W 5980318.98 N 366688.15 E 0.20 7511.75 9967.52 56.23 316.79 5848.24 5900.24 5588.94 N 5152.44 W 5980377.31 N 366634.51 E 0.66 7590.81 10060.31 56.92 316.65 5899.35 5951.35 5645.32 N 5205.53 W 5980434.59 N 366582.39 E 0.75 7668.10 10158.32 56.87 316.19 5952.88 6004.88 5704.79 N 5262.13 W 5980495.02 N 366526.82 E 0.40 7750.00 10254.15 57.40 316.58 6004.89 6056.89 5763.07 N 5317.65 W 5980554.23 N 366472.31 E 0.65 7830.30 10349.44 57.33 316.96 6056.27 6108.27 5821.54 N 5372.62 W 5980613.62 N 366418.36 E 0.34 7910.38 10444.00 57.29 317.06 6107.35 6159.35 5879.75 N 5426.88 W 5980672.75 N 366365.10 E 0.10 7989.83 9/22/2004 3 of 5 2:16 PM ConocoPhillips Alaska Inc. Colville River Unit Alpine CO2 Plan: CD2-09 Plan: CD2-09 L 1 (Rig Surveys) MD Inc Azim. rvD NIS EIW Y X DLS V.S. Comment ft) De (De) (ft) (ft) (ft) (ft) (ft) 0/100ft ft) 10537.01 57.06 317.38 6157.76 6209.76 5937.12 N 5479.97 W 5980731.01 N 366313.01 E 0.38 8067.87 10635.54 56.44 317.48 6211.79 6263.79 5997.80 N 5535.71 W 5980792.63 N 366258.32 E 0.64 8150.16 10728.65 56.19 318.20 6263.43 6315.43 6055.23 N 5587.71 W 5980850.94 N 366207.31 E 0.70 8227.56 10826.72 56.29 318.14 6317.93 6369.93 6115.98 N 5642.09 W 5980912.61 N 366153.99 E 0.11 8309.03 10922.11 57.36 317.94 6370.12 6422.12 6175.35 N 5695.47 W 5980972.88 N 366101.64 E 1.14 8388.81 . 11017.44 58.56 317.94 6420.70 6472.70 6235.35 N 5749.60 W 5981033.79 N 366048.54 E 1.26 8469.54 11112.80 58.93 318.25 6470.17 6522.17 6296.02 N 5804.05 W 5981095.38 N 365995.14 E 0.48 8551.00 11208.86 59.22 319.15 6519.54 6571.54 6357.92 N 5858.43 W 5981158.20 N 365941.83 E 0.86 8633.36 11303.28 59.00 319.49 6568.02 6620.02 6419.37 N 5911.25 W 5981220.54 N 365890.08 E 0.39 8714.38 11398.73 59.21 319.77 6617.03 6669.03 6481.77 N 5964.30 W 5981283.83 N 365838.11 E 0.33 8796.28 11494.40 59.50 320.39 6665.79 6717.79 6544.90 N 6017.12 W 5981347.85 N 365786.38 E 0.64 8878.58 11589.69 59.44 321.08 . RE: CD2-09 L1 . . Subject: RE: CD2-09 L1 From: "Johnson, Vem" <Vem.Johnson@conocophillips.com> Date: Mon, 13 Sep 2004 08:21:55 -0800 To: Thomas Maunder <tom_ maunder@admin.state.ak.us> Tom, Thanks. The 401 should have been at the AOGCC on Friday afternoon. If it doesn't come across your desk today, let me know and I will track it down on this end. Vern -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, September 13, 2004 8:20 AM To: Johnson, Vern Subject: Re: CD2-09 L1 Vern, This acknowledged receipt of your message. I apologize for not replying on Friday. I confirm we did discuss what had transpired on CD2-09 and the need for a separate permit. Continuing operations was acceptable as allowed by 20 AAC 25.005(a). We look forward to receiving the 401 application. Tom Maunder, PE AOGCC Johnson, Vern wrote: Tom, As discussed yesterday, we have open hole sidetracked the well CD2-09. This is the second open hole sidetrack in this hole section. The first sidetrack was due to drilling out of the pay interval into the upper Alpine D. The abandoned leg is not expected to have a significant contribution to oil production. As discussed, this leg is named CD209PB1. The second sidetrack was for geologic evaluation purposes. The "abandoned" leg from the second sidetrack does have "pay" quality sands, and will be labeled CD2-09, and the sidetracked leg will be labeled CD2-09L1. The 10-401 for CD2-09 will be at your office today. Let me know if you have any questions/concerns. Vern Johnson CPAI Alpine Drilling 907-265-6081 (w) 907-748-3906 (c) 907-265-1515 (fx) «Johnson, Vern.vcf» 1 of 1 9/15/200412:46 PM Re: CD2-09 L 1 . . Subject: Re: CD2-09 L1 From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Mon, 13 Sep 2004 08:20:15 -0800 To: "Johnson, Vem" <Vem.Johnson@conocophillips.com> Verri, This acknowledged receipt of your message. I apologize for not replying on Friday. I confirm we did discuss what had transpired on CD2-09 and the need for a separate permit. Continuinq operations was acceptable as allowed bv 20 AA~ 25.005(a). We look forward to receiving the 401 application. Tom Maunder, PE AOGCC Johnson, Vern wrote: Tom, As discussed yesterday, we have open hole sidetracked the well CD2-09. This is the second open hole sidetrack in this hole section. The first sidetrack was due to drilling out of the pay interval into the upper Alpine D. The abandoned leg is not expected to have a significant contribution to oil production. As discussed, this leg is named CD209PB1. The second sidetrack was for geologic evaluation purposes. The "abandoned" leg from the second sidetrack does have "pay" quality sands, and will be labeled CD2-09, and the sidetracked leg will be labeled CD2-09L1. The 10-401 for CD2-09 will be at your office today. Let me know if you have any questions/concerns. Vern Johnson CPAI Alpine Drilling 907-265-6081 (w) 907-748-3906 (c) 907-265-1515 (fx) «Johnson, Vern.vcf» 1 of 1 9/1312004 8:20 AM t ConocoPhillips Alaska'c. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 . ConocdP'hillips September 9, 2004 Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-09L 1 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for a multilateral leg from the main horizontal on the well we are currently drilling, CD2-09. Production is expected ,/ from the original leg, and the lateral leg. The sidetrack will be performed to gather geologic data and determine the depth base of the Alpine formation. The well will be sidetracked at +/- 15883' MD to +/- 16094'MD. / Please reference the permit to drill for CD2-09 for further details. Note that many of the details in the attached form 10-401 reflect the originally planned depths. Please find attached the information required by 20 ACC 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 ACe 25.005 (a). 2. A proposed drilling program Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACe 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser setup which replaces diverter If you have any questions or require further information, please contact Vern Johnson or Zane Kuenzler at 265-6081 or 265-1308, respectively. Chip Alvord can also be reached by calling 265-6120. ~Y'---::?_ _,,¡¡.loy Vern JOhn~n Ku-enzler Drilling Engineer Attachments RECEIVED SEP 1 0 2004 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL . cc: CD2-09 Well File / Sharon Allsup Drake Chip Alvord Vern Johnson/Zane Kuenzler Cliff Crabtree Steve Moothart/Jeff Yeaton Nancy Lambert Lanston Chin . ATO 1530 ATO 1700 A TO 1702/1704 ATO 1768 A TO 1756/1752 Anadarko - Houston Kuukpik Corporation e-mail : Tommy_Thompson @anadarko.com O~ GI~LAL N ,t . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME (!R¿11 (!j)Z~Ó1L/ PTD# 2DL( --- /77 V-/ Development Service CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL V"/ (If API num ber last two (2) digits are between 60-69) Exploration Stratigraphic ~'CLUE". Tbe permit is for a new w ell bore segment of existing well U~ (!p Z -.D 7 c . Permit No, 2d-1-t'lf'l API No. ço'~ 10 3:.?D'(9t:,-¿Ø Production. sbould continue to be reponed as a function 'of tbe original API number. stated above. BOLE In accordance witb 20 AAC 25.005(1), an records, data and logs acquired for tbe pilot bole must be dearly differentiated In botb name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Tbe permit is approved subject ·to full compliance with 20 AAC 25.0S5~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e:Jception. (Company Name) assumes tbe liability of any protest to tbe spacing .e:Jception tbat may occur. All dry ditcb sample sets submitted to tbe Commission must be in no greater tban 30' sample intervals from below tbe permafrost or from wbere samples are first caught and 10' sample h:iter-vals tbrough target zones. D D Well bore seg Annular Disposal On _ Program DEV OnlOff Shore Name: COLVILLE RIV UNIT CD2-09L 1 GeoArea 890 Unit 50360 Multilater.at weU .segment; fee. waived per 20 AAC25.005(e) Surface loca!ion in APL38Q075;top prod. iotervaland TO jnAQL.3872t2, Wel PEND DEV CohlilleRiller Uoit, Alpine QiI Pool, goyeroed. byGQ 443, !?roposed TD lies about 65Q' from exterior bou!ldary of the. C0443 atfecte~are.a.- 500'.setback_required. Directionalsurvey daJa prOllided via .emaiJ 9/20/200<4; loaded into_ Geofram~ _and plotte~ -'nap, . nitial ClasslType No_ Y~s Y~s Y~s Yes Y~s Yes No_ Y~s Yes Y~s Yes Yes NA NA NA _NA COLVILLE RIVER, ALPINE OIL -120100 NC Field & Pool _vl'~11 Wel h cornmeots)_ (for Con~vGtorset 0_nGD.2-0~, Lateral drilled. C9rnpletely wjtb Alpine reseIYoir. No aquifers perAJO :l8A, çonctusion 3._. _ _ _ . _ Surtace ca_sing seLoo CP2-09.. _ _ _ . . Ann_utar disP9sal plaoned _00 CP2-09. _ Openhote_completion ptaone_d.. _ . _ _ _ . _ No ca_sing inJbis hole section, .. _ _ _ . . _ _ _ _ . . Rig is eqvipped with steelpits. _No reseJllepjtplanoed, Mvltilaterat weUbor_e . to an aPproved annulus or.dispos_at well._ Nearest weUþQre is_GQ2~Q9_within 60!? stack. will be io place. Maximum expected formation pressuœ_8J_EMW. MW planned 8.:1 to 8.8 ppg, PPCo usualJYJests to .5000_ psi MASF' calculate_dat 2523 psi NA _NA NA _NA No_ NA Y~s _NA Yes NA Yes Y~s Yes Yes Yes No. NA only) co_nserva_tion order admilJistratille_ approval Can permit be approved before 15-day wait Well JQcated within area and strata avthorized by_lojeGtioo Order # (put 10# AJI wel)s_ within J l4_mite_area_of revieW ideottfied (For service welJ only) _ _ . Pre-produ_ced iojector; ~vratioRof pre-pro~uction I~ss_ than 3 mOlJths. (for_service wel ACMPF.inding .of ConsisteOGY.has bee.nissued. for tbis pr.oiect C.ooductor stringprQvided _ . .. _ . . _ _ .S.urface _casing protects all known USQWs _ .CMT vot adequate. to circJJlate. on colJd.uctor. _Operator only affected party .Operator bas.appropriate. Qond inJorce Permit cao be issued witbQut .Permit cao be issued witbQut 2 3 4 5 '6 7 8 9 o 11 12 13 14 15 16 17 Company CONOCOPHILLlPS ALASKA Permit fee attache~_ .Lease .number appropriate. . . _ .U.niqµe weU.n.ame.aod oumb~r . WellJQcated ina.d.efine~pool. _ '·'ð' .located proper ~istance. from driJli!lg ulJitb9und_ary. JQcated pr.oper _dista!lce from Qtber wel)s cient acreage.ayailable in.dritliogunit "iated, is. weJlbore platincJu~ed PTD#: 2041770 Administration Date 9/22/2004 Appr SFD & su_rf_ csg .CMT vot adequate. to tie-inJQng .string to.surf csg. .CMT will coyeraJl known .prodµctiye bQrizon.s C_asiog de_sigos ad_eQua.te for C,_T~ B&perroafrost A~equate.tankage.or re_serve pit _ Jf.a_re-drilt has. a to-4.03 fQr abandonme_nt A~equate .wellbore separation_proposed Waste reservoir be~o approved Jfdiverter reqJJired, does JLmeet reguJations. DrilJiog fluid program schematic &_ eq.uip list.adequate BOPEs,_d.o Jhey meet regulation .BOPE.press ra!iog appropriate; test to.(put psig Choke. manifold cQmpJies w/APIRp-53 (May 84) Work will occ.ur withouLoperation.shutdown. _ Js presence oJ H2S gas. prQb_able. . _ Meçbanicalcoodit[on of wells within AOR yerified (For.s.ervjce welJ onJy) in.commelJts) 8 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 Engineering Date 9/15/2004 Appr TEM be. Wi Expected reservoir pressure is] ,8.ppg EMW ba.sed on offsetwell data and.modeljng, drilled with. 80 1-8..8 PP9.mud, Y~s .Yes NA .NA NA. Permit cao be tssu.ed w/o hydr.ogen s.utfide rneasures .Datapr~sented on_ potential Ollerpressvrezones. Setsrnica!lalysjs of shaJlow gas.zoo~s_ _ _ . . .(if oft-s hore) . _ . . . weelsly prpgressrep0fÌs 35 36 37 38 39 Geology Appr SFD _Seabed .conditioo su.rvey CQntact namelphQneJQr Date 911512004 Date ß~ [exploratory .onlYl Public :!fl';OO" '- Date Engineering Commissioner: Date: 4>J- Geologic Commissioner: crl ¿~J4- e Well History File APPENDIX e Information of detailed nature that is not particularly gennane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . . dØf -177 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Oct 29 14:54:27 2004 Reel Header Service name. ........... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/29 Origin.................. .STS Reel Name.. ..... ....... ..UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments........... ." ...STS LIS Writing Library. # /;leg) v¡ Scientific Technical Services Tape Header Service name...... ..... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/29 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.......... ......UNKNOWN Continuation Number.... ..01 Previous Tape Name...... . UNKNOWN Comments........... ......STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Colville River Unit (Alpine) MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA CD2-09 L1 501032049660 ConocoPhillips Alaska, Inc. Sperry-Sun Drilling Services 29-0CT-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0003231702 R. KRELL D. BURLEY MWD RUN 3 MW0003231702 R. KRELL D. BURLEY MWD RUN 4 MW0003231702 M. HANIK D. BURLEY JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 MW0003231702 M. HANIK D. BURLEY MWD RUN 6 MW0003231702 M. HANIK D. LUTRICK # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 2 llN 4E 1656 1552 MSL 0) 52.86 15.90 # WELL CASING RECORD OPEN HOLE CASING DRILLERS . . 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 3385.0 6.125 7.000 12617.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE EXITS FROM THE CD2-09 WELLBORE AT 15833'MD/7179'TVD, VIA AN OPEN-HOLE SIDETRACK. 4. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 5. MWD RUNS 2 - 6 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AND PRESSURE WHILE DRILLING (PWD). RUN 2 INCLUDED GEO-PILOT ROTARY STEERABLE BHA. RUNS 4 - 6 INCLUDED AT-BIT INCLINATION (ABI). 6. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. 7. MWD RUNS 2 - 6 REPRESENT WELL CD2-09 L1 WITH API#: 50-103-20496-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 16094'MD/7198'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name.. .......... .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .....04/10/29 Maximum Physical Record. .65535 File Type........... .....LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR ROP $ . START DEPTH 3354.5 3354.5 3354.5 3354.5 3354.5 3362.5 3396.5 STOP DEPTH 16038.0 16038.0 16038.0 16038.0 16038.0 16031.0 16094.0 . # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 2 3 4 5 6 MERGED MAIN PASS. $ MERGE TOP 3354.5 12377.0 12629.0 13695.5 15833.5 MERGE BASE 12377.0 12629.0 13695.0 15833.0 16094.0 # Data Format Specification Record Data Record Type....... ...........0 Data Specification Block Type.....O Logging Direction...... ...........Down Optical log depth units.......... .Feet Data Reference Point.......... ....Undefined Frame Spacing. ................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT FT/H API OHMM OHMM OHMM OHMM HOUR MWD MWD MWD MWD MWD MWD MWD Min 3354.5 0.09 26.45 0.1 0.45 0.06 0.23 0.14 Max 16094 799.09 362.15 2000 2000 2000 2000 66.49 Mean 9724.25 185.965 102.286 8.06211 8.5226 13.1598 19.6564 1.26441 Nsam 25480 25396 25338 25368 25368 25368 25368 25368 First Reading For Entire File........ ..3354.5 Last Reading For Entire File..... ..... .16094 First Reading 3354.5 3396.5 3362.5 3354.5 3354.5 3354.5 3354.5 3354.5 Last Reading 16094 16094 16031 16038 16038 16038 16038 16038 . File Trailer Service name... ....... ...STSLIB.001 Service Sub Level Name. . . Version Number.... ...... .1.0.0 Date of Generation...... .04/10/29 Maximum Physical Record. .65535 File Type......... ...... .LO Next File Name......... ..STSLIB.002 Physical EOF File Header Service name......... ....STSLIB.002 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation.......04/10/29 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name... ....STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPM RPS RPD FET RPX GR ROP $ 2 . header data for each bit run in separate files. 2 .5000 START DEPTH 3354.5 3354.5 3354.5 3354.5 3354.5 3362.5 3396.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 12334.5 12334.5 12334.5 12334.5 12334.5 12342.5 12377.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS 29 -AUG- 04 Insite 66.37 Memory 12377.0 3396.0 12377.0 46.8 70.6 TOOL NUMBER 124725 121079 8.500 3385.0 . MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction... .......... ....Down Optical log depth units.......... .Feet Data Reference Point...... ........Undefined Frame Spacing.................... .60 .1IN Max frames per record.. ........ ...Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O LSND 9.60 37.0 9.4 200 7.8 . 7.000 3.360 9.000 4.500 68.0 149.0 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3354.5 12377 7865.75 18046 3354.5 12377 ROP MWD020 FT/H 8.79 424.14 235.041 17962 3396.5 12377 GR MWD020 API 40.26 362.15 114.772 17961 3362.5 12342.5 RPX MWD020 OHMM 0.1 2000 5.82783 17961 3354.5 12334.5 RPS MWD020 OHMM 0.45 2000 6.22982 17961 3354.5 12334.5 RPM MWD020 OHMM 0.1 1809.23 6.30263 17961 3354.5 12334.5 RPD MWD020 OHMM 0.27 2000 12.797 17961 3354.5 12334.5 FET MWD020 HOUR 0.14 55.29 0.582847 17961 3354.5 12334.5 First Reading For Entire File......... .3354.5 Last Reading For Entire File......... ..12377 File Trailer Service name........ .....STSLIB.002 Service Sub Level Name. . . Version Number.... ..... ..1.0.0 Date of Generation.... ...04/10/29 . . Maximum Physical Record. .65535 File Type............... .LO Next File Name...... .... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .04/10/29 Maximum Physical Record. .65535 File Type.. ..... ....... ..LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPM RPS RPX FET RPD GR ROP $ 3 header data for each bit run in separate files. 3 .5000 START DEPTH 12335.0 12335.0 12335.0 12335.0 12335.0 12343.0 12377.5 STOP DEPTH 12581.5 12581.5 12581.5 12581.5 12581.5 12589.5 12629.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 30-AUG-04 Insite 66.37 Memory 12629.0 12377.0 12629.0 77.2 83.1 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 124725 121079 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 3385.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) LSND 9.80 39.0 9.5 250 3.8 · MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 1.800 .910 1.900 2.400 7. 153.0 71.0 74.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.... ......... .....0 Data Specification Block Type... ..0 Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units...........Feet Data Reference Point............. .Undefined Frame Spacing...... .......... .... .60 .1IN Max frames per record...... ..... ..Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12335 12629 12482 589 12335 12629 ROP MWD030 FT/H 1. 87 259.52 85.033 504 12377.5 12629 GR MWD030 API 47.82 151. 25 118.046 494 12343 12589.5 RPX MWD030 OHMM 2.59 20.72 5.15376 494 12335 12581.5 RPS MWD030 OHMM 2.66 20.98 5.44273 494 12335 12581.5 RPM MWD030 OHMM 2.77 20.58 6.23075 494 12335 12581.5 RPD MWD030 OHMM 3.26 20.27 6.79808 494 12335 12581.5 FET MWD030 HOUR 0.52 22.91 4.85281 494 12335 12581.5 First Reading For Entire File......... .12335 Last Reading For Entire File.. ...... ...12629 File Trailer Service name..... ....... .STSLIB.003 Service Sub Level Name. . . Version Number..... ......1.0.0 Date of Generation...... .04/10/29 Maximum Physical Record..65535 File Type. ..... ......... .LO Next File Name...... .....STSLIB.004 Physical EOF . File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. ... ..04/10/29 Maximum Physical Record. .65535 File Type.. ..... ....... ..LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 4 . header data for each bit run in separate files. 4 .5000 START DEPTH 12582.0 12582.0 12582.0 12582.0 12582.0 12590.0 12629.5 STOP DEPTH 13695.0 13695.0 13695.0 13695.0 13695.0 13695.0 13695.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: 03-SEP-04 Insite 66.37 Memory 13695.0 12629.0 13695.0 85.2 94.3 TOOL NUMBER 129046 162742 6.125 12617.0 Oil Based 8.50 45.0 .0 42000 3.6 .000 .000 .000 .000 .0 154.4 .0 .0 . . MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point... ...........Undefined Frame Spacing................... ..60 .1IN Max frames per record......... ....Undefined Absent value........ . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12582 13695 13138.5 2227 12582 13695 ROP MWD040 FT/H 0.38 202.53 93.691 2132 12629.5 13695 GR MWD040 API 26.45 123.6 63.013 2211 12590 13695 RPX MWD040 OHMM 1. 62 1591.15 19.6842 2227 12582 13695 RPS MWD040 OHMM 2.19 1675.47 20.4595 2227 12582 13695 RPM MWD040 OHMM 0.06 2000 56.7497 2227 12582 13695 RPD MWD040 OHMM 0.23 2000 61.7314 2227 12582 13695 FET MWD040 HOUR 0.38 66.49 4.12801 2227 12582 13695 First Reading For Entire File..........12582 Last Reading For Entire File......... ..13695 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/10/29 Maximum Physical Record. .65535 File Type............... .LO Next File Name... ....... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......04/10/29 Maximum Physical Record. .65535 . File Type........ ....... .LO Previous File Name.... ...STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPM ROP GR RPS RPD FET RPX $ 5 . header data for each bit run in separate files. 5 .5000 START DEPTH 13695.5 13695.5 13695.5 13695.5 13695.5 13695.5 13695.5 STOP DEPTH 15833.0 15833.0 15833.0 15833.0 15833.0 15833.0 15833.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: 07-SEP-04 Insite 66.37 Memory 15833.0 13695.0 15833.0 86.9 92.1 TOOL NUMBER 129046 162742 6.125 12617.0 Oil Based 8.60 48.0 .0 43750 3.5 .000 .000 .000 .000 .0 172 .4 .0 .0 . . $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction...... ........ ...Down Optical log depth units......... ..Feet Data Reference Point............. . Undefined Frame Spacing...... ..... .... ......60 .1IN Max frames per record... ........ ..Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13695.5 15833 14764.3 4276 13695.5 15833 ROP MWD050 FT/H 0.09 799.09 56.2495 4276 13695.5 15833 GR MWD050 API 27.3 163.2 70.6076 4276 13695.5 15833 RPX MWD050 OHMM 3.01 48.68 11.8457 4276 13695.5 15833 RPS MWD050 OHMM 3.19 99.95 12.4628 4276 13695.5 15833 RPM MWD050 OHMM 3.61 2000 20.6844 4276 13695.5 15833 RPD MWD050 OHMM 5.05 1745.44 29.2451 4276 13695.5 15833 FET MWD050 HOUR 0.61 17.05 2.01851 4276 13695.5 15833 First Reading For Entire File.... ..... .13695.5 Last Reading For Entire File........ ...15833 File Trailer Service name......... ....STSLIB.005 Service Sub Level Name. . . version Number....... ....1.0.0 Date of Generation...... .04/10/29 Maximum Physical Record..65535 File Type... ..... ....... .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name.. .......... .STSLIB.006 Service Sub Level Name... version Number.......... .1.0.0 Date of Generation. ..... .04/10/29 Maximum Physical Record. .65535 File Type............ .,. .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD header dat!l!or each bit run in separate fi4lt. 6 .5000 Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX GR ROP FET $ START DEPTH 15833.5 15833.5 15833.5 15833.5 15833.5 15833.5 15833.5 STOP DEPTH 16038.0 16038.0 16038.0 16038.0 16031. 0 16094.0 16038.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........ ..........0 Data Specification Block Type... ..0 Logging Direction....... ......... . Down Optical log depth units.......... .Feet 08-SEP-04 Insite 66.37 Memory 16094.0 15833.0 16094.0 85.1 86.9 TOOL NUMBER 129046 162742 6.125 12617.0 Oil Based 8.60 48.0 .0 46000 3.3 .000 .000 .000 .000 .0 172.4 .0 .0 . . Data Reference Point..... .........Undefined Frame Spacing................... ..60 .1IN Max frames per record........ .....Undefined Absent value....... . . . . . . . . . . . . . . . -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 15833.5 16094 15963.8 522 15833.5 16094 ROP MWD060 FT/H 0.1 159.04 34.1845 522 15833.5 16094 GR MWD060 API 52.78 101. 44 77.632 396 15833.5 16031 RPX MWD060 OHMM 5.09 11.58 6.85534 410 15833.5 16038 RPS MWD060 OHMM 5.1 10.87 6.74295 410 15833.5 16038 RPM MWD060 OHMM 5.09 10.04 6.65566 410 15833.5 16038 RPD MWD060 OHMM 5.57 9.92 7.09698 410 15833.5 16038 FET MWD060 HOUR 1. 08 31.7 3.37919 410 15833.5 16038 First Reading For Entire File.... ..... .15833.5 Last Reading For Entire File.......... .16094 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.... ...04/10/29 Maximum Physical Record. .65535 File Type... ..... ..... ...LO Next File Name.......... .STSLIB.007 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/29 Origin.................. .STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments.... ..... ....... .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name......... ....LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/29 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number......01 Next Reel Name.......... . UNKNOWN Comments..... .... ...... ..STS LIS Writing Library. Scientific Technical Services . . Physical EOF Physical EOF End Of LIS File
