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205-113
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. ~(~ t7 - ~ ~~ Well History File Identifier Organizing (done) ^ Two-sided III II'III II III II III ^ Rescan Needed III II~IU II II (II111 RE CAN Color Items: ^ Greyscaie items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria ` Project Proofing. BY: Maria Date: Liuuiuuiuiui P P Scanning Preparation ~ x 30 = + ~~ =TOTAL PAGES~i~ (Count does not include cover sheet) ~~ BY: Maria Date: /s/ Production Scanning III II'iliillll IIII~ Stage 1 Page Count from Scanned File: ~ ~ / (count does include~cov/e'r sheet) Page Count Matches Number in Scanning Preparation: ~/ YES NO BY: .Maria Date: f ~~~/o /s/ ~/~ l ~ t ~Y~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II ((I II I ~ N ReScanned II l ll ll ll l l 111 ! 1111 BY: Maria Date: /s/ Comments about this file: Quality Checked III IIII~I~IIII'I III DtGITAt_ DATA Diskettes, No. ~.., ^ Other, No/Type: Date: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: 10!6/2005 Well History File Cover Page.doc STATE OF ALASKA ALASAI L AND GAS CONSERVATION COMMIS• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon J Repair well r Aug Nrforations F Stimulate r Other I✓ Scale Inhibition Pull Tubing P New Pool Waiver Treatment Alter Casing r 9 � Ti Extension j Change Approved Program r 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 f7 Exploratory I-"' 205 - 113 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic " Service E , 50- 103 - 20512 -60 ^ 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25530, 380075, 387212 - CD2 -03L1 9. Field /Pool(s): Colville River Field / Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 15356 feet Plugs (measured) None true vertical 7093 feet Junk (measured) None Effective Depth measured 15356 feet Packer (measured) 11070, 11155, 13072 true vertical 7093 feet (true vertucal) 5994, 6034, 6912 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 3224 9.625 3260 2381 INTERMEDIATE 13740 7 13774 7111 .'"Nt :F p 1 r,! , 4 7 WSJ - RECEIVED Perforation depth: Measured depth: open hole 15045' 15356' JA 2012 True Vertical Depth: 7112' -7093' Alaska Oil & Gas 0003. C0 111SSIOPI Tubing (size, grade, MD, and ND) 3.5, L -80, 13130 MD, 6936 TVD Packers & SSSV (type, MD, and ND) PACKER - WEATHERFORD ER UPPER PACKER @ 11070 MD and 5994 ND PACKER - LOWER WEATHERFORD PACKER @ 11155 MD and 6034 ND PACKER - BAKER PREMIER PACKER @ 13072 MD and 6912 TVD TRDP - CAMCO TRMAXX -5E SSSV @ 2322 MD and 1951 ND 11. Stimulation or cement squeeze summary: Intervals treated (measured): 15045'- 15356' 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 158 1152 332 -- 241 Subsequent to operation 209 1475 624 -- 249 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory ` Development - Service — Stratigraphic r 15. Well Status after work: r' Oil Id Gas r WDSPL r' Daily Report of Well Operations XXX GSTOR I- WINJ E WAG r GINJ I""'" SUSP r SPLUG " 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Dan Kolesar an. 263 -4039 \ Printed Name Dan Koles r Title WNS Production Optimization Engineer Signature Phone: 265 -4039 Date (• 1 ( • t2 • Form 10 -404 Revised 10/2010 iRQD S awl 2 0f2 /- rZ . /L— Submit Original Only l • C D2 -03 Scale Inhibition Treatment 12/6/2011: Initial pressure TBG /IA /OA — 800/1060/525; Facility pumped 50 bbls SW preflush; LRS pumped 1.8 bbls WAW5206 (77 gal) at 0.4 bpm and facility pumped 17 bbls SW, 950/975/500; IRS pumped 18 bbls SCW3001WC (770 gal) at 0.5 bpm and facility pumped 104 bbls of SW, 2750/950/500; IRS pumped 1.8 bbls WAW5206 (77 gal) at 0.5 bpm and facility pumped 17 bbls SW, 2475/940/500; facility pumped 993 bbls of SW over- displacement. I - t WNS CD2 -03L1 ConOCO�l1��Ip5 v ell Attributes ax Angle & MD TD F ' I i' IIIr, Wellbore API/UWI Field Name Well Status Inc! r) MD (ftKB) Act Btm (ftKB) 501032051260 ALPINE PROD 95.85 15210.07 15,356.0 '"' Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: TRDP Last WO: 43.81 7/30/2005 Well ConBq - CO2 -03L1, 9/9/2011 3:53'53 PM Schematic - Actual Annotation Depth (RKB) End Date Annotation Last Mod... End Date Last Tag: Rev Reason: GLV C/O ninam 9/9/2011 Casing Strings 'Casing Description String O... String ID ... Top (RKB) Set Depth (t... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER. 33 ` i► L1 OPEN HOLE 6 1/8 15,045.0 15,662.0 Notes: General & Safety End Date Annotation '. 7/29/2005 NOTE: MULTI - LATERAL OPEN HOLE WELL 12/29/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 MiNINE 11.111. CONDUCTOR, t 37 -114 SAFETY VLV. �o 2,322 SURFACE. J l 36 -3,260 GAS LIFT, 5,675 a la a GAS LIFT, 1 OW 0.238 III II PACKER. 11,070 PATCH, 11,081 III PACKER, 71,155 .' sosorP. a la GAS LIFT, _ 12,896 Lil Itil SLEEVE -C, A , 12,986 .— ,. 1 PACKER — I 13.072 NIPPLE 13118 '. IIII WLEG, 13,130 Mandrel Details Top Depth Top Port (TVD) Ind OD Valve Latch Size TRO Run Stn Top (RKB) 17t1(81 CI Make Model (le) Sery Type Type (in) (psi) Run Date Corn... 1 5,675.0 3,495.5 60.93 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/16/2006 IPERF. - 2 10237.9 5,604.6 62.26 CAMCO KBUG 1 GAS LIFT OV BK 0.188 0.0 8/27/2011 13,720.13.739 -- _ _ 3' 12,896.0 6,837.3 64.24 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 3/17/2010 IPERF, 13.740- 13,759 N NTERM EDIATE, 34-13.774 - TD (CD2- 03L1). 15,356 L1 OPEN HOLE. 13,774-15,662 ` - " 7. OPEN HOLE. — 13,77415,862 " STATE OF ALASKA ~~Y Q ~ Zo~l7 ALAS AND GAS CONSERVATION COMMIS~1 REPORT OF SUNDRY WELL OPERATIONS ' ~-'' Repair well ("" PIugF~rforations "" Stimulate ""'" Others Patch ~ Alter Casing ~"' Pull Tubing Ft'rforate New Pool ~"° Waiver Time Extension ~""" ~ Change Approved Program ~ Operat. Shutdow n F~rforate "' Re-enter Suspended Well ~""""" 2. Operator Name: 4. Current Well Status: ~5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory 205-113 3. Address: ~6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic J-' Service ``` 50-103-20512-60 7. Propert~esignat+pn: ~ 8. Well Name and Number: ADL 25530, 380075, 387212 ~ CD2-03L1 9. Field/Pool(s): Colville River Field / Ipine Oil Pool 10. Present Well Condition Summary: Total Depth measured 15356 feet Plugs (measured) None true vertical 7093 feet Junk (measured) None Effective Depth measured 15356 feet Packer (measured) 11070, 11155, 13072 true vertical 7093 feet (true vertucal) 5994, 6034, 6912 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 3224 9.625 3260 2381 INTERMEDIATE 13737 7 13774 7111 ,, t Perforation depth: Measured depth: open hole completion from 15045'-15356' .r ,~z.~`: ~'e.., ~~~'' -- ~L~~v True Vertical Depth: 7112'-7093' Tubing (size, grade, MD, and TVD) 3.5, L-80, 13130 MD, 6936 TVD Packers &SSSV (type, MD, and TVD) PACKER - WEATHERFORD ER UPPER PACKER @ 11070 MD and 5994 TVD PACKER -LOWER WEATHERFORD PACKER @ 11155 MD and 6034 TVD PACKER -BAKER PREMIER PACKER @ 13072 MD and 6912 TVD TRDP - CAMCO TRMAXX-5E SSSV @ 2322 MD and 1951 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 452 1459 537 -- 258 Subsequent to operation 493 1571 476 -- 260 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory Development Service . Well Status after work: Oil Gas WDSPL ~'""'' Daily Report of Well Operations XXX GSTOR WAG ~""' GASINJ "` WINJ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. sundry Number or N/A if C.O. Exempt: none contact Dan Herrmann ~ 263-4619 Printed Name 'Herr n Title Wells Engineer S~Q'j,~(~ ~ Signature Phone:263-4619 Date Form 10-404 Revised 7/2009 ~ Submit Original Only Y.•% ~~~v CD2-03 Well Events Summary DATE SUMMARY 3/16/10 GAUGED TUBING 2.79" TO 13,1~KB. SET CATCHER @ 13,118' RKB. ~ED OV FROM 12,896' RKB. PULLED GLV FROM 10,237' RKB. IN PROGRESS. 3/17/10 SET DV's @ 10,237' & 12,896' RKB. GOOD TESTS ON VALVES W/ D&D HOLEFINDER. OPENED CMD @ 12,985' RKB. PULLED CATCHER SUB FROM 13,118' RKB. MEASURED BHP @ 'C3,148' RKB: 3739 PSI. IN PROGRESS. 3/18/10 SET HOLE FINDER @ 11,264' SLM (11,300' RKB). LRS PUMPED 375 BBLS INHIBITED BRINE TO IA FOLLOWED BY 50 BBLS DIESEL, CLOSED CMD @ 12986' RKB. JOB COMPLETE MOVE TO CD2-14 3/20/10 ATTEMPTED TO SET PACKER AT 11170'. TOOL STRING SHORTED OUT AFTER CORRELATION PASS. PULLED OUT OF HOLE AND RIGGED- DOWN. WILL SET THE PACKER TOMORROW 3/21/10 SET 3.5" WEATHERFORD ER PACKER AT A DEPTH OF 11170'. CCL TO MID ELEMENT OF PACKER AT 14.75'. CCL STOP DEPTH AT 11155.25' 3/22/10 RAN 3 1/2 ER PACKER TEST TOOL TO LOWER PACKER 2000 PSI COMBO TEST TBG & IA GOOD TEST. IN PROGRESS MOVE TO CD2-34 3/24/1.0 SET 27.13' SNAP LATCH SEAL ASSEMBLY SPACER PIPE IN ER PACKER @ 11166' RKB, SET 28.46' SPACER PIPE & WEATHERFORD ER UPPER PACKER, MIT TUBING TO 3000 PSI GOOD TEST, MIT IA TEST FAILED. RDMO IN PROGRESS 3/31/10 PULLED ER PACKER & SLICK STICK SPACER PIPE, SLICK STICK SPACER PIPE HAS MARKS ON BOTTOM INDICATING STINGER WAS NOT ENGAGING SO TIEBACK, UNABLE TO ENGAGE SO TIE BACK W/TEST TOOL, PULL LOWER 27.13' SNAP LATCH ASSEMBLY, TEST LOWER ER PACKER @ 11166' RKB TO 3000 PSI GOOD TEST. COMPLETE 4/9/10 SET 17.23' LOWER PATCH W/SNAP LATCH IN LOWER ER PACKER @ 11,166' RKB. SET 28.46' SPACER ASSY. AND UPPER ER PACKER. 56.44' FROM PACKER TO PACKER. SET ER TEST TOOL ON CAT SV IN UPPER PACKER @ 11,098' SLM. MIT-T TO 3000 PSI PASSED. MIT-IA TO 3000 PSI PASSED. IN PROGRESS. 4/12/10 PULLED DV FROM 10,237' RKB, AND REPLACED W/ 3/16" OV. PULLED CAT SV & ER TEST TOOL FROM ER PACKER @ 11,089' SLM. COMPLETE. CONDUCTOR, 3]-116 SAFEN VLV, 2.322 SURFACE, 36-3,260 GAS LIFT, 5 6]6 GAS LIFT. 10,238 PACKER, 11.0]0 PATCH, 11,081 PATCH. 11,110 PACKER, 11,155 GAS LIFT, 12 896 SLEEVE C. 12.966 PACKER, 13,0]2 NIPPLE, 13,t 16 WLEG, 13,130 IPE RF, 13,]20-13.]35 Lt OPEN HOLE, 15,045-15.662 OPEN HOLE, 13,]]4-15,662 WNS ,II Attributes CD2-03L1 'ellbore APVU WI 'Field Name Well Status lncl (°) MD (HK8( Act etm (ttK8( 501032051260 ,ALPINE I ( PROD I 95.85 15,21007 75.356.0 merit H2S (ppml Date (Annotation End Date Ke-Grtl (ft) Rig Release Date SSV: TRDP I (Last WO: I 7/30/2005 . End Date nnotation (Depth (ftK6( Annotation Lds[Mod ... End Date ast Tag: ( (Rev Reason: SET PATCH, GLV C(O _ Imosbor 4/1G2010 :asin~ Strings asinq Descr pt~on _ Str nq O.. SUinq ID ... Top (ftK61 Set Depth (f... Set D pth (ND)String W~String String Top Thrd • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION i~~~ Y ~D MAY :~ ~ 2(109 REPORT OF SUNDRY WELL OPERATIO~dS-a O~I,& Gas c®nc_ r.,,mm,n~ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ S}jrf(1t ~ th6~fiGl'~Or ~,~ CL Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ ~~~~~ 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 ^ 205-113 / • 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20512-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 36.T, 53' AMSL CD2-03L1 • 8. Property Designation: 10. FieldlPool(s): ADL 25530,•380075, 387212 ' Colville River Field /Alpine Oil Pool • 11. Present Well Condition Summary: Total Depth measured 15356' feet true vertical 7093' • feet Plugs (measured) Effective Depth measured 15356' feet Junk (measured} true vertical 7093' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 114' 16" 114' 114' SURFACE 3223' 9-5/8" 3260' ~ 2381' PRODUCTION 13737' 7" 13774' 7111' Perforation depth: Measured depth: open hole completion} from 15045'-15356' true vertical depth: 7112'-7093' ~~yyy ,4 P° t ~ ~ ~~~( Tubing (size, grade, and measured depth) 4.5" / 3.5", L-80, 121' ! 13130' MD. Packers &SSSV (type & measured depth). Baker premier pkr @ 13072' Camco SSSV @ 2322' 12. Stimulation or cement squeeze summary: Intervals treated (measured) pumped 75.7 bbl scale squeeze Treatment descriptions including volume s 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 524 1606 281 -- 246 Subsequent to operation 327 1357 287 -- 248 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil 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 Schneider @ 265-6859 Printed Name Tim Sc el r Title Alpine Staff Engineer Signature ~ n Phone: 265-6859 Date '~~~~~~ Pre are b Sha n Allsu -Drake 263-4612 :_.. ~. Jt)N 0 5 X009 ~ ,-~~' ~ Zg Form 10-404 Revised 04/2006 3 ~ ~ ~ ~ ~ (~ ~ ~ ~~ Submit Original Only ,~.f~q~~ TUBING (0-121, OD:4.500, ID:3.958) SURFACE (0-3260, OD:9,625, W 1:36.00 ) TUBING (123-13130, OD 3.500, ID:2.992) 'RODUCTION (0-13774, OD 7,000, W t26.00 ) SLEEVE ;12986-12987, OD:4.260) PACKER ;13072-13073, OD:5.980) NIP ;13118-13119, OD:3.750) W LEG ;13129-13130, OD:4.500) OPEN HOLE CD2-03 ;13774-15682, OD:6.125) OPEN HOLE CD2-03L1 ;15045-15662, OD:6.125 ) L- ` _.- ~ • • Con~c~Phllips Alaska, InC. ALPINE CD2-03L1 WSR -Well Service Report Well Service Report -~ Page 1 of 1 Weil Job Scope CPAI Rep CD2-03 Scale Inhibition Shirtliffe, Ryan Date Daily Work Unit Number 4/23/2009 32 Initial & T/I/A Initial - 300/575/800 Final. Final - 600/575/800 Pressures: Field: ALPINE 2~l hr. Pumped an Aqueous Squeeze into well. Pumped a total of 75.7 bbls of SW at ~2.( Summary bpm and 600 psi. Job pumped as planned STARTTIME OPERATION 04:30 PM Rig in. P-Test lines to 2000 psi. Pump job as planned. 8 bbls SW + 5206 @ 1.6 bpm and 600 psi. Follow with 59.5 05:00 PM bbls SW + SCW3001 Chemical at 2.3 bpm and 600 psi. Finish pumping with 8.2 bb SW + 5206 at 2 bpm and 575 psi. Operations flushed well with SW from manifold. u~:~o rivi trig out eq uipment. Fluid Type To From lYom Note WeIl Well recoverable DIESEL 35 SEAWATER SCW- , 3001 WC 60 SEAWATER, SCW- 4004 16 http://akapps.conocophillips.net/alaskawelleventquery/worklog.aspx?ID=E3 BD561... 5/15/2009 pC. 1 ~~ DATA SUBMITTAL COMPLIANCE REPORT 7/19/2007 Permit to Drill 2051130 Well Name/No. COLVILLE RIV UNIT CD2-03L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20512-60-00 MD 15356 TVD 7093 Completion Date 7/29/2005 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res, SCMT (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 14926 15356 Open 9/7/2005 IIFR ED D Asc Directional Survey 14926 15356 Open 9/7/2005 MWD D Lis 13277 Induction/Resistivity 3232 15292 Open 9/26/2005 GR EWR4 ABI ROP PWD GEOPLOT pt 13277 LIS Verification 3232 15292 Open 9/26/2005 GR EWR4 ABI ROP PWD GEOPLOT D C Lis 13751 Induction/Resistivity 3270 15356 Open 2/22/2006 ROP DGR EWR plus Graphics D C Las 14468 Induction/Resistivity 3224 15356 Open 1/29/2007 LIS Veri, FET, GR, ROP w/Graphics Mell Cores/Samples Information: Name Sample Interval Set Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? / N Chips Received? ~T'IQ'~ Formation Tops ~/ N Analysis ~Hd~' Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 7/19/2007 Permit to Drill 2051130 Well Name/No. COLVILLE RIV UNIT CD2-03L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20512-60-00 MD 15356 ND 7093 Co p etion Date 7/29/2005 Completion Status 1-OIL Current Status 1-OIL UIC N Compliance Reviewed By: Date: ~~ • • 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-O1_PB1_PB2, CD2-03_Ll, CD2-OS_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 CD2-01_PB 1_PB2. 2©Sr- l/ ~ # /.-/orb `~ Digital Log Images: 1 CD Rom 50-103-20514-00,70,71 CD2-03 L1: aOS -Og a ~ 205 -1 !3 Digital Log Images: ~ ~L/L/~~ I ~~/~~ 1 CD Rom 50-103-20512-00,60 CD2-OS_Ll: ~o~._-pct ~ ~ aa~/-~~~ Digital Log Images: ¢ iVy~S ~/'~~~o~ 1 CD Rom 50-103-20495-00,60 I~ • ~ WELL LOG TRANSMITTAL ~~~ <<~ To: State of Alaska February 16, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs CD2-03 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 CD2-03 L1: LAS Data & Digital Log Images: 1 CD Rom 50-103-20512-60 /~' \ ' , ~~ _ ~~V~~ STATE OF ALASKA ~ NOV 2 ~. 2QO5 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPOI~"kl~~~l,G,o; commission 1a. Well Status: Oil 0 Gas Plugged Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: Development Q Expbratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., -Ns~ ~f • ~ /~„ ~, ~ orAband.: July,36, 2005 12. Permit to Drill Number: 205-113 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: ~~ ~ July , 2005 ~ ;(= z!•c~ 13. API Number. 50-103-20512-60 4a. Location of Well (Governmental Section): Surface: 1597' FNL, 1560' FEL, Sec.2, T11 N, R4E, UM 7. Date TD Reached: July 26, 2005 14. Well Name and Number: CD2-03L1 At Top Productive Horizon: 2079' FNL, 1000' FEL, Sec. 27, T12N, R4E, UM 8. KB Elevation (ft): 36.7' RKB, 52' AMSL 15. Field/Pool(s): Colville River Field Total Depth: 635' FNL, 1796' FEL, Sec. 27, T12N, R4E, UM 9. Plug Back Depth (MD + ND): 15356' MD / 7093' TVD Alpine Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 371685 y- 5974761 ~ Zone- 4 10. Total Depth (MD + ND): 15356' MD / 7093' ND ~ 16. Properly Designation: ADL 25530, 3aoo75, 387212 TPI: x- 367128 y- 5984919 Zone- 4 Total Depth: x- 366355 "" - 5986377 ^ Zone- 4 11. Depth where SSSV set: 2322' 17. Land Use Permit: ALK ASRC NPRA02 18. Directional Survey: Yes Q No 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1747' MD 21. Logs Run: ~ ~ ~~- - r ~z°>~ ~~~s ~y~~ ; 7 l z %z GR/Res, SCMT ir.. -. , <3f" 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surf. 114' Surf. 114' 42" Portland Cement 9-5/8" 36# J-55 Surf. 3260' Surf. 2381' 12.25" 519 sx AS Lite, 23o sx Class G 7" 26# L-80 Surf. 13774' Surf. 7111' 8.75" 30 bbls Mudpush XL, 191 sx Class G 23. Perforations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" / 3.5" 121' / 13130' 13072' open hole completion from 15045' - 15356' MD, 7112' - 7093' TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested Production for Test Period -> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". -- - ; ~BDMS AFL NOV 2 $ 200yvoNE ?~`-`~-~r ~ 0 Form 10-407 Revised 1212003 CONTINUED ON REVERSE 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". CD2-03L1 Seabee Form. 3334' 2416' Nanushak 6448' 3864' Gamma Ray Shale 12800' 6795' Kalubik 13299' 6994' Kuparuk Formation 13465' 7039' Miluveach 13643' 7086' Top Alpine D 15198' 7108' Top Alpine C 13699' 7098' Base Alpine C 15198' 7108' N/A TD 15356' 7093' 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 Printed Name G Alvord Title: Alpine Drilling Team Leader //~~ .°~~ I I ~ (J~ ~ u ~ ~ ~ ~ . Signature /. i.°" . ... Phone ~ ~ ~~ Date / ~~ , INSTRUCTIONS Prepared by Sharon Allsup-Drake 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 1 a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12!2003 C7 C©nocoPhillips Alaska Operations Summary Report Legal Well Name: CD2-03 Common Well Name: CD2-03 Event Name: ROT -DRILLING Start: 7/8/2005 Contractor Name: Doyon Drilling Inc Rig Release: 7!30/2005 Rig Name: Doyon 19 Rig Number: Date From - To 'Hours Code Code Phase -_ 7/10/2005 15:00 - 23:00 8.00 MOVE MOVE MOVE 23:00 - 00:00 1.00 DRILL RIRD RIGUP 7/11/2005 00:00 - 01:15 01:15 - 02:45 02:45 - 06:30 1.25 ~ WELCTL NUND RIGUP 1.50 RIGMNT RSRV RIGUP 3.75 DRILL PULD RIGUP 06:30 - 09:00 09:00 - 09:30 09:30 - 10:15 10:15 - 12:00 12:00.- 00:00 ( 12.00 DRILL DRLG SURFAC 7!12/2005 i 00:00 - 03:30 3.50 DRILL DRLG SURFAC 03:30 - 05:45 2.25 DRILL CIRC SURFAC 05:45 - 12:00 ( 6.25 DRILL DRLG SURFAC 12:00 - 00:00 I 12.001 DRILL I DRLG I SURFAC 2.50) DRILL I PULD RIGUP 0.50 DRILL SFTY RIGUP 0.75 DRILL PULD RIGUP 1.751 DRILL I DRLG .SURFAC 7/13/2005 100:00 - 04:30 ! 4.501 DRILL I DRLG I SURFAC 04:30 - 05:15 05:15 - 07:15 07:15 - 08:00 08:00 - 10:00 10:00 - 12:00 12:00 - 13:00 13:00 - 16:00 16:00 - 18:30 18:30 - 20:00 20:00 - 23:15 0.75 DRILL 2.00 DRILL 0.75 DRILL 2.00 DRILL 2.00 DRILL 1.00 i DRILL 3.00 DRILL 2.50 DRILL 1.50 CASE 3.25 CASE CIRC SURFAC WIPR SURFAC CIRC SURFAC WIPR SURFAC WIPR SURFAC CIRC SURFAC TRIP SURFAC PULD SURFAC RURD SURFAC RUNC SURFAC Page 1 of 7 Spud Date: 7/10/2005 End: 7/30/2005 Group: Description of Operations Moved rig from CD2-60 to CD2-03 and rigged up. Picked up riser and nipple up while taking on Spud Mud. Went back on highline power @ 2200 hrs. Rig accepted @ 2300 hrs. Nipple up riser and flowline Slip and cut drilling line -service rig Measure 5" drill pipe -Pick up and stand back 78 jts of drill pipe and 6 jts of hwdp Change out 7.75" drlg jars - MU BHA #1-Bit / 8" SperryDrill @ 1.83 / FS /stab ! xo / DM HOC / HCIM / TM HOC / UBHO Held Pre-Spud meeting with rig team MU 8" nmdc's & jars -fill Conductor and check for leaks -pressure test mud lines to 3500 psi. Spudded well @ 1015 hours Drill 12 1/4" hole from 114' to 167' 400 gpm / 500 psi / 40 rpm PUW 90K SOW 90K ROTWT 90K ADT= 1 hr ART 1.0 AST 0 Run Gyro survey Drill 12 114" hole from 167' to 885' 450 gpm / 910 psi / 40 rpm PUW 110K SOW 110K ROTWT 110K ADT= 6.25 hr ART 1.01 AST 5.24 Run 5 Gyro surveys. Drill 12 1/4" hole from 885' to 1265' TVD 1207' 450 gpm / 1200 psi / 40 rpm PUW 115K SOW 110K ROTWT 112K ADT= 2.05 hr ART 1.05 AST 1 hrs Circulated and consulted with directional drillers and team leader about entering eclipse of CD2-06. Determined OK to drill ahead. Drill 12 1/4" hole from 1265' to 2025' TVD 1787' 550 gpm / 1700 psi / 40 rpm PUW 126K SOW 115K ROTWT 125K ADT= 4 hr ART 2.64 AST 1.37 hrs Drill 12 1/4" hole from 2025' to 2977' TVD 2250' 650 gpm / 2170 psi / 40 rpm PUW 135 K SOW 110 K ROTWT 125K ADT= 8.73 hr ART 7.37 AST 1.36 hrs Drill 12 1 /4" hole from 2977' to 3270' TVD 2385' 650 gpm / 2300 psi / 60 rpm PUW 135K SOW 111 K ROTWT 126K Torque On/Off 9000 / 8000 ADT= 3.54 hr ART 2.31 AST 1.23 hrs Circ hole clean at 650 gpm - 2210 psi - 60 rpms POH w/ pumps from 3270' to 2120' at 550 gpm - 60 rpms. Large amount of clay and thick mud at shakers. CBU to condition mud. POH w! pumps from 2120' to 888' at 480 gpm - 60 rpms. Flow check well. OK. RIH from 888' to 3270'. No hole problems. Circulated hole clean. POOH w pump to 884'. Flow check and POOH on trip tank to 791'. Stood back DC's and laid down BHA. Rigged up to run casing and PJSM. Ran 45 Jts 9 5/8" 36# J-55 BTC casing to 1879'. Printed: 9!19/2005 12:56:37 PM • C ConocoPhillips Alaska Page 2 of 7 Operations Summary Report Legal Well Name: CD2-03 Common Well Name: CD2-03 Event Name: ROT -DRILLING Contractor Name: Doyon Drilling Inc Rig Name: Doyon 19 Date From - To Hours Code Code Phase 7/13/2005 7/14/2005 7/15/2005 23:15 - 00:00 0.75 CASE CIRC -- SURFAC 00:00 - 01:15 1.25, CASE RUNC SURFAC 01:15 - 01:45 0.50' CEMEN RURD SURFAC 01:45 - 03:45 2.00 CEMEN CIRC SURFAC 03:45 - 04:00 0.25 CEMEN~SFTY SURFAC 04:00 - 05:45 1.75 CEMEN PUMP SURFAC 05:45 - 06:30 ~ 0.75 CEMEN7(DISP SURFAC 06:30 - 07:30 1.00 ~ CASE DEOT SURFAC 07:30 - 12:00 4.50 i CASE NUND SURFAC 12:00 - 17:00 i 5.001 WELCTLI BOPE I SURFAC 17:00 - 19:45 2.75 DRILL PULD SURFAC 19:45 - 20:15 0.50 DRILL CIRC SURFAC 20:15 - 21:00 0.75 DRILL TRIP SURFAC 21:00 - 23:30 2.50 DRILL PULD SURFAC 23:30 - 00:00 0.50 DRILL TRIP SURFAC 00:00 - 02:30 2.50 DRILL PULD SURFAC 02:30 - 02:45 0.25 ~ DRILL CIRC SURFAC 02:45 - 03:30 0.75 DRILL TRIP SURFAC 03:30 - 06:45 3.25 DRILL PULD SURFAC 06:45 - 09:30 2.75 DRILL TRIP ~ SURFAC 09:30 - 11:00 1.50 RIGMNT RSRV SURFAC 11:00 - 11:30 , 0.50 CEMEN COUT SURFAC 11:30 - 15:00 3.50 CEMEN DSHO SURFAC 15:00 - 15:15 0.25 DRILL DRLG SURFAC 15:15 - 15:45 0.50 DRILL ~ CIRC SURFAC 15:45 - 16:30 0.75 CEMEN LOT SURFAC 16:30 - 17:00 ~ 0.50 DRILL ~ CIRC INTRM1 17:00 - 00:00 I 7.00 DRILL DRLG INTRM1 7/16/2005 ~ 00:00 - 12:00 12.00 i DRILL DRLG INTRM1 12:00 - 00:00 12.00; DRILL DRLG i INTRM1 Spud Date: 7/10/2005 Start: 7/8/2005 End: 7/30/2005 Rig Release: 7/30/2005 Group: Rig Number: Description of Operations Circulated @ 4 BPM 200 PSI until shakers cleaned up. RIH w/ 9 5/8" csg from 1879' to 3260'. No hole problems. RD Franks fill up tool. RU cement head. Break circ at 1.5 bpm at 230 psi. Slowly increase rate to 7 bpm at 300 psi. Conditon mud for cement. PJSM on cementing csg. Test lines to 2500 psi. Pumped 40 bbls bizan/nut plug spacer and drop bottom plug. Pump 50 bbls 10.5 mud push, 411 bbls 10.7 lead cement and 48 bbls 15.8 tail cement. Dropped top plug. Dowell pumped 20 bbls H2O. Rig displaced with 227 bbls 9.6 mud. Bumped plug. Check floats. OK. RU and test casing to 2500 psi for 30 min. OK. Laid down landing joint. Nippled down riser. Installed FMC speed head. Nippled up BOP. Installed test plug. Test BOPS - Hydril to 250 & 3500 psi -Pipe rams, choke & kill line valves, choke manifold valves, IBOP and floor valves to 250 & 5000 psi -performed accumutator closure test. Witiness of test by AOGCC waived by Lou Gramaldi. Pulled test plug and set wear bushing. Picked up and RIH 96 Jts 5" DP from pipe shed. CBU. POOH and stood back DP. Picked up and RIH 96 Jts 5" DP from pipe shed. POOH and stood back DP. PU and RIH w/ 72 jts 5"DP. Circ 1 DP volume. POH and std back 24 stds DP. MU BHA #2. Upload MWD. RU GeoSpan unit. Shallow test MWD and GeoPilot. Pressure test GeoSpan to 3500 psi. PU and RIH w/ 5" DP to 3103'. Slipped and cut drilling line. Serviced top drive. Washed down and tagged cement @ 3165'. Drilled out FC and shoe track to 3160'. Cleaned out rat hole to 3270'. Drilled 8 3/4" hole from 3270' to 3290' TVD 2395' 650 gpm / 1800 psi / 60 rpm PUW 150 K SOW 110 K ROTWT 130 K Torque On/Off 9000 / 8000 ADT= .18 hrs CBU. Rigged up and did LOT to 16.9 PPG EMW. Changed out to LSND mud system. Drilled 8 3/4" hole from 3290' to 4201' TVD 2828' 650 gpm / 1900 psi / 125 rpm PUW 160 K SOW 110 K ROTWT 132 K Torque On/Off 11000 / 10500 ADT= 6.75 hrs ECD 10.8 Drilled 8 3/4" hole from 4201' to 5959' TVD 3615' 670 gpm / 2570 psi / 160 rpm PUW 160 K SOW 120 K ROTWT 140 K Torque On/Off 11500 ! 10500 ADT= 7.97 hrs ECD 10.9 - 11.6 Drilled 8 3/4" hole from 5959' to 7482' TVD 4346' 670 gpm / 2390 psi / 130 rpm Printed: 9!19/2005 12:56:37 PM • • C©noc©Phiflips Alaska Page 3 of 7 Operations Summary Report Legal Well Name: CD2-03 Common Well Name: CD2-03 Spud Date: 7/10/2005 Event Name: ROT -DRILLING Start: 7/8/2005 End: 7/30/2005 Contractor Name: Doyon Drjlling Inc Rig Release: 7/30/2005 .Group: Rig Name: Doyon 19 Rig Number: Date From - To Hours Code Code Phase ______ 7/16/2005 12:00 - 00:00 12.00 ~ DRILL DRLG INTRM1 7!17/2005 ~ 00:00 -12:00 12.00 ~ DRILL I DRLG ~ INTRMI 12:00 - 00:00 12.00 DRILL DRLG INTRM1 7/18/2005 00:00 - 12:00 12.00 DRILL DRLG INTRM1 12:00 - 00:00 ; 12.001 DRILL I DRLG I INTRM1 7/19/2005 00:00 - 02:00 2.00 DRILL i DRLG INTRMI 02:00 - 03:00 1.00' DRILL CIRC INTRM1 03:00 - 04:45 1.751 DRILL WIPR 1NTRM1 04:45 - 05:30 ~ 0.75 ~ DRILL 'WIPR INTRMI 05:30 - 09:00 3.50 ~ DRILL CIRC INTRM1 09:00-10:30 ' 1.50 DRILL 'TRIP INTRM1 10:30 - 13:30 3.00 I DRILL TRIP INTRM1 13:30 - 17:45 4.25 DRILL TRIP INTRM1 17:45 - 19:30 ~ 1.75 DRILL .TRIP INTRM1 19:30 - 22:30 3.00 DRILL PULD INTRM1 22:30 - 00:00 ; 1.501 CASE I NUND I INTRM1 7/20/2005 1 00:00 - 00:30 0.50 WELCT EORP INTRM1 00:30 - 01:00 0.50 ~ WELCT BOPE INTRM1 01:00 - 01:30 0.50 CASE OTHR INTRMI 01:30 - 02:45 ; 1.25 CASE RURD INTRM1 02:45 - 03:00 ' 0.25 ~ CASE SFTY INTRM1 03:00 - 06:30 3.501 CASE RUNC INTRM1 Description of Operations PUW 185 K SOW 125 K ROTWT 158 K Torque On/Off 15000 / 14000 ADT= 7.12 hrs ECD 10.9 - 11.3 Drilled 8 3/4" hole from 7482' to 9195' ND 5128' 670 gpm / 2500 psi / 170 rpm PUW 220 K SOW 125 K ROTWT 170 K Torque On/Off 16500 / 15500 ADT= 8.08 hrs ECD 10.9 - 11.0 Drilled 8 3/4" hole from 9,195' to 10,977' TVD 5,950' 670 gpm / 2640 psi / 165 rpm PUW 250 K SOW 144 K ROTWT 188 K Torque On/Off 20,000 / 19,000 ADT= 8.22 hrs ECD 10.8 - 11.1 Drilled 8 3/4" hole from 10,977' to 12,622' TVD 6715' 670 gpm / 2700 psi / 165 rpm PUW 275 K SOW 150 K ROTWT 200 K Torque On/Off 22,500 / 22,000 ADT= 7.96 hrs ECD 10.8 - 11.0 Drilled 8 3/4" hole from 12,622' to 13,699' TVD 7092' 620 gpm / 2500 psi / 150 rpm PUW 300 K SOW 150 K ROTWT 208 K Torque On/Off 23,000 / 23,000 ADT= 8.45 hrs ECD 10.8 - 11.0 Drilled 8 3/4" hole from 13,699' to 13,784' TVD 7112' WOB - 13 k RPM 150 GPM 625 @ 2460 psi String wt. PU 296 SO 150 Rot 207 Torque On/Off bmt. - 23,000 ! 22,000 ft/Ibs. ADT= .28 hrs ECD 10.8 - 11.0 ppg Circ hi vis sweep at 625 gpm - 2450 psi - 130 rpms. Check flow. OK. Pump out of hole from 13,784' to 12, 748' at 550 gpm - 1980 psi - 120 rpms. No hole problems. Check flow. OK. RIH from 12,748' to 13,784'. No problems. Circ and condition mud 3X bottoms up at 625 gpm - 2500 psi - 130 rpms. Increase mud wt to 9.8 ppg. Spot 20 bbl wellbore strengthening pill followed by 130 bbl lube pill. Check flow. OK. POH spotting pills from 13,784' to 12,717'. POH on trip tank from 12,717' to 9760' -hole in condition - no tight spots -hole taking poper fill -Flow check (static) Pumped dry job & continue POOH on TT f/ 9760' to 3102' Monitor well (static) Continue to POOH - LD ghost reamers -Stand back HWDP & jars, Std back NM flex DC's Down load MWD -check oil in Geo Pilot -Break bit - LD BHA -clean up rig floor - LD Geo Span Set test plug -change top pipe rams to 7" & chnage saver sub in TD to XT-39 Fiinish change top pipe rams to 7" and Go TD saver sub. Test 7" rams to 250 - 5000 psi. Pull test plug. Install thin wear bushing. RU 7" csg equipment. PJSM on running 7" csg. Run 7" 26# L-80 BTCM csg as follows: FS (Silver bullet) 2 jts: FS - 2 jts.(first 4 connections made up w/ BakerLoc -fill pipe & check floats) 73 jts. to 3258' (77 jts total) Printed: 9/19/2005 12:56:37 PM • • C'onocoPhillips Alaska Page 4 ofi 7 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 7/20/2005 06:30 - 07:00 07:00 - 10:45 CD2-03 CD2-03 Spud Date: 7/10/2005 ROT -DRILLING Start: 7/8/2005 End: 7/30/2005 Doyon Drilling Inc Rig Release: 7/30/2005 Group: Doyon 19 Rig Number: Hours Code Code'. Phase 0.50 CASE CIRC INTRM1 3.75 CASE RUNC INTRM1 10:45 - 12:00 1.25 CASE CIRC INTRM1 12:00 - 16:45 4.75 CASE RUNC INTRM1 16:45 - 18:45 ~ 2.00 CASE ' CIRC INTRMI 18:45 - 20:00 1.25 CASE RUNC INTRM1 20:00 - 20:30 20:30 - 22:00 0.50 CASE OTHR INTRMI 1.50 CEMEN CIRC INTRMI 22:00 - 22:45 0.75 CEMEN1t PUMP INTRM1 y 22:45 - 00:00 1.25 CEMEN DISP INTRM1 7/21/2005 00:00 - 00:30 0.50 1 CEMEN~ DISP INTRM1 00:30 - 02:30 2.00 WAITON CMT INTRM1 02:30 - 03:30 1.00 CASE RURD INTRM1 03:30 - 04:30 1.00 CASE OTHR INTRM1 04:30 - 05:45 1.25 WELCT~ EORP INTRM1 05:45 - 09:30 3.75 WELCT BOPE INTRM1 09:30 - 10:00 0.50 ~ DRILL OTHR INTRM1 10:00 - 16:30 6.50 DRILL PULD INTRM1 16:30 - 17:00 0.50 RIGMNT RSRV INTRM1 17:00 - 17:45 0.75 DRILL PULD INTRM1 17:45 - 18:45 1.00 RIGMNT RGRP INTRM1 18:45 - 20:45 2.00' DRILL PULD INTRM1 20:45 - 00:00 3.25 DRILL ! PULD INTRM1 7/22/2005 ~ 00:00 - 00:30 0.501 DRILL PULD INTRM1 00:30 - 12:00 11.50; DRILL PULD INTRM1 12:00 - 13:00 1.00 DRILL TRIP INTRM1 13:00 - 14:30 1.50 DRILL CIRC INTRM1 14:30 - 16:00 1.50 CASE ~ DEOT INTRMI 16:00 - 18:30 2.50i CEMEN DSHO INTRM1 18:30 - 19:45 ~ 1.25 DRILL DRLH INTRM1 19:45 - 21:00 ; 1.251 DRILL CIRC INTRM1 Description of Operations Circ 1 csg volume at 4 bpm at 275 psi. Continue running 7" 26# L-80 BTCM csg f/ 3258' to 8001' (189 jts. total) Circulate btms up + Stage pumps up to 4 bbls !min - ICP 570 psi - FCP 360 psi Continue running 7" 26# L-80 BTCM csg f/ 8001' to 12,711' (300 jts. total) Circulate btms up + Stage pumps up to 4 bbls/min. -ICP 670 psi -FCP 530 psi Continue running 7" 26# L-80 BTCM csg f/ 12,711' to 13,737' - PU hanger 8 landing jt.- land 7" casing w/shoe @ 13,774' & FC @ 13,684' Hole was in good condition - no tight spots RD casing spider & fill up tool - RU cmt head & lines Circulate & condition mud for cmt job -stage pumps to 5 bbls/min FCP 550 psi -Held pre job for cememting csg Cement 7" csg as follows: Pumped 5 bbls CW-100 -tested lines to 3700 psi -pumped 15 bbls CW-100 @ 3.5 bbls/min @ 400 psi - Pumped 30 bbls MudPush II @ 11.5 ppg - 5.2 bbls/min @ 500 psi - Dropped btm plug - Mixed & pumped 41 bbls tail slurry @ 15.8 ppg - 5.4 bbls/min @ 400 psi -dropped top plug w/ 20 bbls water f/ Dowell Switch over to rig pumps & displaced cmt w/ 9.8 ppg LSND mud @ 6 bbls/min for 470 bbls @ 420 to 460 psi -full returns Finish displace cement w/ 9.8. Pumped total of 505.8 bbls mud. Plug did not bump. Check floats. OK. Had small flow out annulus. Shut well in. WOC 2 hrs. 100 psi on 7" csg. Annulus is static. Bled off csg pressure. RD csg equipment. LD LJ. Pull thin wear bushing. Install upper test plug. Change top pipe rams from 7" to 3 1/2" x 6" varibles. Test all BOPE to 250 / 5000 psi with annular to 3500 psi. Witness of test waived by AOGCC rep Chudc Scheve. Pull test plug. Install wear bushing. LD 5" DP from derrick. Service top drive LD 5" DP from derrick Work on Iron roughneck LD 5" DP from derrick MU 6 1/8" BHA -bit ,motor, MWD, obtain scribe on motor &MWD - Up load MWD Finish MU BHA. Shallow test MWD - 210 gpm - 375 psi. PU and RIH w/ 378 jts 4" DP from 375' to 12,394'. RIH w/ pipe from derrick f/ 12,394' to 13,540'. Wash f/ 13,540' to 13,635'. CBU at 210 gpm - 1600 psi - 50 rpms. RU and test 7" csg to 3500 psi for 30 min. Clean out shoe track f/ 13,635' to 13,774' - Cmt & wiper plugs to top of FC @ 13,684' cmt to top of FS @ 13,772' -clean out rat hole to 13,784' Drill 20' new hole f/ 13,784' to 13,804' - 7114' TVD WOB 4/8 k RPM 50 GPM 214 @ 1980 psi String wt. PU 280 SO 120 Rot 175 Torque on/off btm. - 1800/1700 ft. lbs. ADT - .52 hrs. AST - .52 hrs. Circulate hole clean for FIT - 215 GPM @ 1750 psi Printed: 9/19/2005 12:56:37 PM • • ConocoPhillips Alaska Page 5 of 7 Operations Summary Report Legal Well Name: CD2-03 Common Well Name: CD2-03 Spud Date: 7/10/2005 Event Name: ROT -DRILLING Start: 7/8/2005 End: 7/30/2005 Contractor Name: Doyon Drilling Inc Rig Release: 7/30/2005 Group: Rig Name: Doyon 19 Rig Number: Date From - To Hours Code '' Code Phase '' Description of Operations 7/22/2005 ~ 21:00 - 21:45 ~ 0.75 (DRILL ~ FIT INTRM1 21:45 - 00:00 7/23/2005 00:00 - 09:00 09:00 - 10:00 10:00 - 11:00 2.25 I DRILL I CIRC I PROD 9.00 DRILL DRLG PROD 1.00 ~ DRILL CIRC PROD 1.001 DRILL ,TRIP PROD 11:00 - 11:15 0.25 RIGMNT SFTY PROD 11:15 - 16:00 4.75 RIGMNT RSRV PROD 16:00 - 19:30. 3.50 ~ RIGMNT RSRV PROD 19:30 - 20:00 0.50 DRILL TRIP PROD 20:00 - 00:00 4.00 DRILL DRLG PROD 7/24/2005 100:00 - 12:00 I 12.001 DRILL i DRLH I PROD 12:00 - 00:00 I 12.00 I DRILL I DRLH I PROD 7/25/2005 00:00 - 02:30 ~ 2.50 DRILL DRLH !;PROD 02:30 - 04:00 1.50' DRILL S TRIP PROD 04:00 - 06:00 2.00 DRILL CIRC PROD 06:00 - 09:00 3.00 DRILL OTHR PROD 09:00 - 12:00 3.00 ( DRILL i OTHR PROD 12:00 - 12:15 0.25 DRILL OTHR PROD 12:15 - 12:45 0.50 DRILL OTHR PROD 12:45 - 13:45 I 1.001 DRILL I OTHR I PROD RU & perform FIT to 12.5 ppg EMW - 1050 psi w/ 9.7 ppg mud @ 7111' TVD - RD PJSM -Change well over f/ 9.7 ppg LSND mud to 9.4 ppg OBM - 214 GPM @ 2400 psi w/ 50 RPM Drill 6 1/8" horz. hole w/ motor f/ 13,804' to 14,160' MD 7103' TVD AD7 - 6.56 hrs. =ART -1.01 hrs. AST - 5.55 hrs. WOB - 7/9 k RPM - 60 GPM 220 @ 3120 psi String wt. PU 255 SO 120 Rot 172 Torque on/off btm. - 16,000/15,000 ft/Ibs. ECD - 10.6 to 11.0 ppg CBU at 220 gpm - 2750 psi - 60 rpms. Check flow. OK. POH w/ pump f/ 14,160' to 13,731' at 3 bpm - 1080 psi. PJSM on changing out drilling line. Change out drilling line. Repair hose on drill line dead man PJSM -Change out blower hose for TD - Servicxe TD & draw works - calc. block height Monitor well on TT during power shut down -hole took 3 bbls RIH f/ 13,731' to 14,160' Drill 6 1/8" horz. hole w/ motor f/ 14,160' to 14,245' MD - 7001' TVD ADT - 1.94 hrs. =ART - .36 hrs. AST - 1.58 hrs. WOB 7/9 k RPM 0/60 GPM 220 @ 3100 psi String wt. PU 250 SO 120 Rot 172 Torque on/off btm. - 16,000/15,000 ft. lbs. ECD - 10.6 to 11.1 ppg Drill 6 1/8" horz. hole w/ motor f/ 14,245' to 15,014' MD - 7114' TVD ADT - 6.97 hrs. =ART - 5.05 hrs. AST - 1.92 hrs. WOB 9/11 k RPM 0/60 GPM 220 @ 3300 psi String wt. PU 255 SO 115 Rot 165 Torque on/off btm. - 16,500/16,000 ft. lbs. ECD - 10.8 to 11.0 ppg Drill 6 1/8" horz. hole w/ motor f! 15,014' to 15,507' MD - 7116' TVD ADT - 7.51 hrs, =ART - 5.52 hrs. AST - 1.99 hrs. WOB 5/10 k RPM 40/70 GPM 220 @ 3100 psi String wt. PU 265 SO 110 Rot 170 Torque on/off btm. - 16,000115,000 ft. lbs. ECD - 10.6 to 11.0 ppg Drill 6 1/8" horz. hole w/ motor f/ 15,507' to 15,682' MD - 7134' TVD ADT - 1.84 hrs. =ART - 1.46 hrs. AST - 0.38 hrs. WOB 8/12 k RPM 60 GPM 220 @ 3320 psi String wt. PU 255 SO 120 Rot 165 Torque on/off btm. - 16,000/15,000 ft. lbs. ECD - 10.8 to 11.0 ppg POH w/ pumps f/ 15,682' to 14,875' at 3 bpm - 1400 psi and 60 rpms. CBU 2X at 220 gpms - 2920 psi - 60 rpms MU std. trough from 14,926' to 14,971'. 220 gpms - 2900 psi - 0 rpms. Time drill f/ 14,971' to 14,975'. Hi-line power down at 0930. Time drill with one generator. Continue time drill to 14,975.85' (sliding) Lost high line power - PU off btm - pullled tight - LD single -pulled 100k over -pulled pipe free Time drill w/ rotary f/ 14,970.5' to 14972.8' - 210 gpm w/ 12,000 torque - lost hi line power Printed: 9/19/2005 12:56:37 PM • • C©nocoP'hillips Alaska Page 6 of 7 Operations Summary Report Legal Well Name: CD2-03 Common W ell Name: CD2-03 Spud Date: 7/10/2005 Event Nam e: ROT -D RILLING Start: 7/8/2005 End: 7/30/2005 Contractor Name: Doyon D rilling In c Rig Release: 7/30/2005 Group: Rig Name: Doyon 1 9 Rig Number: Date From''- To ' Hours Code Phase Description of Operations Code 7/25/2005 13:45 - 16:00 2.25 DRILL CIRC PROD Circulate & work pipe W/O high line power f/ 14,973' to 14,984' 16:00 - 00:00 8.00 DRILL OTHR PROD Continue time drill w/ rotary f/ 14,984' to 15,001' - 210 gpm @ 2700 psi w/ 60 rpm -torque 12,000 7/26/2005 00:00 - 08:30 8.50 j DRILL DRLH PROD Time drill to sidetrack well from 15,001' to 15,045' 210 gpm / 2740 psi / 60 rpm Sidetracked well @ 15,045' 08:30 - 12:00 3.50 DRILL DRLH PROD Drill 6 1/8" horz. hole w/ motor f/ 15,045' to 15,089' MD - 7115' TVD ~ ADT - 1.98 hrs. =ART - 0.7 hrs. AST - 1.28 hrs. WOB 5/7 k RPM 60 GPM 220 @ 2900 psi String wt. PU 260 SO 115 Rot 165 Torque on/off btm. - 14,000/13,000 ft. lbs. ' ECD - 10.8 to 10.9 ppg 12:00 - 00:00 12.00 DRILL DRLH PROD Drill 6 1/8" horz. hole f/ 15,089' to 15,356' MD 7093' TVD ADT - 10.49 hrs. =ART - 3.34 hrs. AST - 7.15 hrs. WOB 4/10 k RPM 60/70 GPM 220/222 @ 3150 to 3190 psi String wt. PU 260 SO 110 Rot 165 ~ Torque on/off btm. - 16,000/14,000 ft. lbs. ECD - 10.9 to 11.0 ppg TD called @ 15,356' by geologist Jeff Yeaton 7/27/2005 00:00 - 01:30 1.50 DRILL CIRC PROD Circ and cond mud - 220 gpm / 2860 psi / 60 rpm Set back 1 stand / 30 min: to 14971' 01:30 - 04:00 2.50 DRILL TRIP PROD Flow check well, static. POOH w/ pump from 14,971' to 13730' - 126 gpm / 1260 psi / 60 rpm - Hole taking proper fill 04:00 - 05:00 1.00 DRILL CIRC PROD Circ and condition mud - 210 gpm / 2550 psi / 60 rpm 05:00 - 06:30 1.50 DRILL TRIP PROD POOH w/ pump from 13, 730' to 12776' - 126 gpm / 1000 psi Hole taking proper fill -monitor well, static 06:30 - 07:30 1.00 DRILL TRIP PROD POOH on trip tank from 12,776' to 12,108' - 0.5 bbl short on hole fill 07:30 - 10:30 3.00 DRILL TRIP PROD Monitor well, static -POOH w/ pump from 12,108' to 10,199' 126 gpm / 920 psi -Hole taking proper fill 10:30 - 11:15 , 0.75 DRILL TRIP PROD Monitor well, static -POOH from 10,199' to 10,008' - 2 stands -short 0.3 bbl hole fill 11:15 - 11:45 0.50 DRILL OBSV , PROD Monitor well 30 min, static. Raised mud wt. in pit #5 to 9.7 ppg 11:45 - 16:30 4.75 DRILL TRIP PROD POOH w/pump from 10,008' to 6,669' 147 gpm / 1140 - 950 psi -Maintain mud wt. in at 9.7 ppg Monitor well at 7,146' 10 min -static 16:30 - 23:15 6.75 DRILL TRIP PROD POOH on trip tank from 6,669' to 374' (BHA) Hole took proper fill 23:15 - 00:00 0.75 DRILL TRIP PROD Monitor well (static) -Stand back HWDP & Jars 7/28/2005 00:00 - 02:00 2.00 DRILL PULD PROD Flush tools -stand back nmfc's -down load MWD -lay down bha - clean up rig floor 02:00 - 02:30 0.50 CMPLTN OTHR CMPLTN Pull wear bushing 02:30 - 03:15 0.75 ~ CMPLTNI RURD ~ CMPLTN RU to run tubing - PJSM. 03:15 - 21:00 17.75 CMPLTN RUNT CMPLTN Run 3 1/2" completion as follows - MU WLEG - 3 1/2" 9.3 # L-80 EUE pup - XN nipple - 1 jt. 3 1/2" 9.3# L-80 EUE -mod. tbg -Baker Premier ', ; i packer -3 1/2" 9.3 # L-80 EUE pup (all connections below packer made up w/ BakerLok) - 2 jts. 3 1/2" 9.3 # L-80 EUE mod tbg -pup -Baker I CMD sliding sleeve -pup - 2 jts 3 1/2" 9.3 # L-80 EUE mod -pup -GLM # 1 -pup - 84 jts. 3 1/2" 9.3 # L-80 EUE mod tbg -GLM # 2 - 145 jts 3 1/2" 9.3# L-80 EUE mod tbg -GLM #3 - 107 jts. 3 1/2" 9.3# L-80 EUE mod tbg - Camco TRMAXX-5E SCSSV -Tie in control line & test to 5000 psi - 70 jts 3 1/2" 9.3# L-80 EUE tbg (w/ 86 5/8" SS bands for control line) - XO 3 1/2" EUE mod pin X 4 1/2" IBTM box - 2 jts. 4 1/2" 12.6 # L-80 IBTM tbg -pup 4 1/2" 12.6# L-80 IBTM -FMC 4 1/2" tbg ~~ ; hanger -tie in control line through tbg hanger & test -Land completion Printed: 9/19/2005 12:56:37 PM • • Con©coPhillips Alaska Page 7 of 7 Operations Summary Report Legal Well Name: CD2-03 Common Well Name: CD2-03 Spud Date: 7/10/2005 Event Name: ROT -DRILLING Start: 7/8/2005 End: 7/30/2005 Contractor Name: Doyon Drilling Inc Rig Release: 7/30/2005 Group: Rig Name: Doyon 19 Rig Number: Date From - To Hours Code 'Code Phase Description of Operations 7/28/2005 03:15 - 21:00 17.75 CMPLTN RUNT CMPLTN string on FMC hanger in wellhead - PU wt. 155 SO wt. 100 TBG tail @ 13,130' - XN @ 13,118' -Packer @ 13,071' Sliding sleeve @ 12,985' -GLM #1 @ 12,896' -GLM #2 @ 10,238' - GLM # 3 @ 5675' - TRMAXX-5E SCSSV @ 2321' 21:00 - 22:00 1.00 CMPLTN DEQT CMPLTN LD landing jt. A -set TWC - MU landing jt. B -test hanger seals to 5000 psi - LD landing jt. B 22:00 - 23:30 1.50 CMPLTN OTHR CMPLTN MU stack washer- Flush BOP stack, mud pumps, & top drive w/ Safe Surf O (OBM clean up) -blow down TD, choke & kill lines 23:30 - 00:00 0.50 CMPLTN OTHR CMPLTN Pull mouse hole -Begin ND BOPE 7/29/2005 00:00 - 01:30 1.50 CMPLTN NUND CMPLTN ND BOP -change TD saver sub to 4 1/2 IF 01:30 - 03:00 ~ 1.50 CMPLTN NUND CMPLTN Terminate control line through wellhead -test control line to 5000 psi - NU tree & test to 5000 psi 03:00 - 03:30 0.50 CMPLTN OTHR CMPLTN RU FMC lubricator & pull TWC - RU hard lines to tbg & annulus - RU floor manifold 03:30 - 07:30 4.00 CMPLTN FRZP CMPLTN PJSM. Change well over from OBM to diesel - Pressure test lines to 3000 psi -Pumped 22 bbls mineral oil down tubing followed by 449 bbls diesel -Maintained back pressure schedule on annulus -monitored return volumes to pits -Shut down & shut in well - 750 psi on tbg, 575 psi on annulus 07:30 - 08:30 1.00 CMPLTN PCKR CMPLTN RU Doyon lubricator and drop ball and rod - RU hard lines and pressure test to 5000 psi 08:30 - 10:00 1.50 CMPLTN DEQT CMPLTN Pressure up on tbg to 4600 psi to set packer -bled 600 psi off annulus - Pressure test tubing with 4500 psi, bled to 4275 psi in 30 minutes - bled down tubing to 1020 psi -pressure up annulus to 3580 psi, bled to 3420 psi in 30 minutes -Bleed off annulus to 0 psi -Bled tubing to 750 psi and shut in at wellhead. ,10:00 - 12:00 2.00 CMPLTN OTHR CMPLTN ;Blow down lines - RD hard lines & manifold - RU FMC lubricator & set BPV - RD lubricator & secure wellhead 12:00 - 23:00 11.00 CMPLTN OTHR CMPLTN Lay down 4" drill pipe fpr rig move 23:00 - 23:30 0.50 CMPLTN OTHR CMPLTN Move 6 3/4" NM flex DC's & 5" HWDP w/jars f/ off drillers side to drillers side in derrick for rig move 23:30 - 00:00 0.50 CMPLTN OTHR CMPLTN LD mouse hole - LD hanger box & subs -Begin cleaning up f/ OBM 7/30/2005 00:00 - 02:30 2.50 j CMPLTN OTHR ,CMPLTN Clean up after OBM -Released Rig @ 0230 hrs. Printed: 9/19/2005 12:56:37 PM ConocoPhillips Alaska, Inc. Alaska North Slope North Slope, Alaska Alpine CD-2 CD2-03L 1 Job No. AK-ZZ-0003811902, Surveyed: 26 July, 2005 Survey Report 15 August, 2005 Your Ref: API 501032051260 Surface Coordinates: 5974761.44 N, 371684.74E (70° 20' 21.4010" N, 151 ° 02' 28.4787" VV) Grid Coordinate System: NAD27 Alaska Stafe Planes, Zone 4 Surface Coordinates relative to Project H Reference: 974761.44 N, 128315.26 W (Grid) Surface Coordinates relative ib Structure: 317.92 N, 38.20 W (True) Kelly Bushing Elevation: 52.50ft above Mean Sea Level Kelly Bushing Elevation: 52.50ft above Project V Reference Kelly Bushing Elevation: 52.50ft above Structure ~Rr~-~-r~~ ~~~~~~~~ SurveyRef.•svy506 A Htilltburtprr Company ConocoPhillips Alaska, lnc. Survey Report forA/pine CD-2 - CD2-03L1 Your Ref: API 501032051260 Job No. AK-ZZ-0003811902, Surveyed: 28 July, 2005 Alaska North Slope Measured True Sub-Sea Vertical Local Coord inates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 14926.58 88.570 331.430 7059.68 7112.18 11147.46 N 5320.09 W 5985998.31 N 366556.20 E 14991.00 91.060 328.760 7059.89 7112.39 11203.29 N 5352.20 W 5986054.68 N 366525.04 E 15022.03 89.050 329.480 7059.86 7112.36 11229.92 N 5368.13 W 5986081.58 N 366509.58 E 15117.38 90.900 332.790 7059.90 7112.40 11313.41 N 5414.15 W 5986165.85 N 366464.99 E 15210.07 95.850 331.060 7054.45 7106.95 11395.02 N 5457.68 W 5986248.19 N 366422.87 E 15308.02 95.300 331.430 7044.93 7097.43 11480.49 N 5504.57 W 5986334.45 N 366377.44 E 15356.00 95.300 331.430 7040.50 7093.00 - 11522.45 N 5527.42 W ~ 5986376.79 N 366355.31 E All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB: 52'. 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 334.120° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 15356.OOft., The Bottom Hole Displacement is 12779.64ft., in the Direction of 334.373° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 14926.58 7112.18 11147.46 N 5320.09 W Tie-On Point 14991.00 7112.39 11203.29 N 5352.20 W Open Hole ST Point 15356.00 7093.00 11522.45 N 5527.42 W Projected Survey North Slope, Alaska Dogleg Vertical Rate Section Comment (°/100ft) 12351.64 Tie-0n Point 5.667 12415.89 Open Hole ST Point 6.881 12446.80 3.977 12542.00 5.656 12634.43 0.676 12731.79 • 0.000 12779.51 Projected Survey • 15 August, 2005 -16:33 Page 2 of 3 Dri//Quest 3.03.06.008 ConocoPhillips Alaska, Inc. Survey Report forAlpine CD-2 -CD2-03L1 Your Ref.• API 501032051260 Job No. AK ZZ-0003811902, Surveyed: 28 Juty, 2005 Alaska North Slope Survey tool program for CD2-03L1 From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 349.00 348.89 349.00 348.89 15356.00 7093.00 Survey Tool Description North Slope, Alaska CB-SS-Gyro (CD2-03) . MWD+IIFR+MS+SAG (CD2-03) • 15 August, 2005 - 16:33 Page 3 of 3 DrillQuest 3.03.08.008 • • 30-Aug-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD2-03 L1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 14,926.58' MD Window /Kickoff Survey: 14,991.00' MD (if applicable) Projected Survey: 15,356.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.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 ~~~~ `~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • • 30-Aug-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD2-03 L1 MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 14,926.58' MD Window /Kickoff Survey: 14,991.00' MD (if applicable) Projected Survey: 15,356.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.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 / ~, a' ~, ~ f ~ , Date / ~ ~ ~~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) `~v j - it 3 ~ ~i.. • • WELL LOG TRANSMITTAL To: State of Alaska August 19, 2005 Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD2-03 Ll, AK-MW-3811902 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, S rry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 F, ,_-~__~_-Jl 1 LDWG formatted Disc with verification listing. API#: 50-103 -20512-60. ~ ~ ~~~ ;~ ~ ~ ~ ~~ ~ ~ ,~' 1"~ •~ ~ 1 ~, 1, ~`m~ ! ~~ ~ ~ FRANK H. MURKOWSKI, GOVERNOR ~~ OIL ~ ~ ~~ 333 W. 7T" AVENUE, SUITE 100 COI~TSERQA'I`I011T CO1~II~'IISSIOIQ ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Colville River CD2-03L1 ConocoPhillips Alaska, Inc. Permit No: 205-113 Surface Location: 1597' FNL, .1560' FEL, SEC. 2, T11N, R4E, UM Bottomhole Location: 623 FNL, 1825' FEL, SEC. 27, T12N, R4E 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 CD2-03 Permit No. 205-092, API No. 50-103-20512-00. 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- 3607 (pager). ~~ ~ DATED this',~day of July, 2005 cc: Department of Fish 8s Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 July 26, 2005 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-03L1 Dear Sir or Madam: ~~~ Alaska Qtl ,~ Ggs Cons. Go~i~trssio-~ Anchorage 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, CD2-03. Production is expected from both legs of the well. The sidetrack will be performed to galh~r 9 da#~-and determine the depth base of the Alpine formation. The well will be sidetracked at +/- 14991' MD and drilled to the revised TD at +/- 15381' MD. 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 ACC 25.005 (a). 2. A proposed drilling program 3. A directional plan for the sidetrack. 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 lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser setup which replaces diverter S' rely, ~~'~ ~/0 5 .~-~ ern J~ n Drilling Engineer Attachments cc: CD2-03 Well File /Sharon Allsup Drake Chip Alvord Vern Johnson/Zane Kuenzler Tim Schneider Steve Moothart/Jeff Yeaton Bill Esco ATO 1530 ATO 1700 ATO 1702/1704 ATO 1768 ATO 1756/1752 Anadarko -Houston ConocoPhillips STATE OF ALASKA ~SKA OIL AND GAS CONSERVATION C ~~ ISSION PERMIT TO DRILL 20 AAC 25.005 ~~4G~ V EQ ~ L 2 2005 ~~ ~ ~ ~t~tl~a ait & Gas Cons• Commission 1a. Type of Work: Drill Q Redrill ~ 1b. Current Well Class: Exploratory ~ Development Oil ~~~$~ Zone Re-entry ~ Stratigraphic Test ~ Service ~ Development Gas ~ Single Zone 2. Operator Name: 5. Bond: Blanket Q Single Well ~ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 CD2-03L1 3. Address: 6. Proposed Depth: 12. Field/Pool(s): PO Box 100360, Anchorage AK 99510-0360 MD: 15381 TVD: 7090 Colville River Field 4a. Location of Well (Governmental Section): 7. Property Designation: ~ Z~„~% Alpine Oil Pool Surface: ~ 1597' FNL 1560' FEL, Sec 2 T11 N, R4E UM ' ADL 38 1, 025530, 380075, 387212 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2122' FNL, 977 FEL, Sec 27 T12N R4E per original wellplan ASRC NPRA02 26-Jul-05 Total Depth: 9. Acres in Property: 14. Distance~o Nearest G 623, FNL 1825' FEL Sec 27 T12N R4E per original wellplan 2560 Property: u~~~~-p0 084148 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Surface:x- 371685 y- 5974761 Zone- 4 (Height above GL): 36.7 feet Within Pool: CD2-20 597 ft "~ 16. Deviated wells: Kickoff depth:7~~f~ feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: 3206 Surface: 2494 18. Casing Program: .7 2~` "~--s" Setting Depth Quantity of Cement Size Specifications Top Bottom c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 16" 62.5# H-40 Weld 77 37 37 114 114 Portland Cement 12.25" 9.625" 36# 155 BTC 3223 37 37 3260 2381 601 Sx AS Lite & 230 sx Litecrete 8.75" 7" 26# L80 BTC-M 13737 37 37 13774 7111 138 Sx 15.8 ppg class G 6.125" 3.5" 9.3# L80 EUE-M 17262 32 32 17294 7087 Tubing 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 4~~~~ Perforation Depth TVD (ft): G O7 20. Attachments: Filing Fee ~ BO P Sketch Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis Property Plat ~ Diverter Sketch ~ Seabed Report ~ Drilling Fluid Program ~ 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: TOM MAUNDER Date 7/25/2005 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact V. Johnson 265-0681 Printed Name Chip Alvord Title Alpine Drilling Team Leader Signature ~, Phone 907-265-6120 Date 26-Jul-05 Commission Use Only Permit to Drill PI Number: Permit Approval See cover letter for other ~f1~~,, / / Number: c~sJ '~ / / jp; / 50- ! t-/~ r~~~~ "'-(v ~/ Date: , ~, ~ p ~- requirements. Conditions of approval I r uired Yes ~ No ~ Mud log required Yes ~ No roge ide measures Yes ~ No ~ Directional survey required Yes ~ No Other: ~ ~ ~?.p'e ~~. APPROVED BY Approved y: THE COMMISSION Date: Form 10-401 R vised 06/2004 ~~ Submit inDuplicate • • CD2-03 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 6-1 /8" Hole /Horizontal Production Hole Event Risk Level Miti ation Strate Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin ,wei hted swee s. Abnormal Reservoir Medium BOPE drills, Keep mud weight above 8.8 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. Hydrogen Sulfide gas Low HZS drills, detection systems, alarms, standard well control ractices, mud scaven ers ~ ~ Alpine : CD2-03L1 Procedure Procedure 1. Pull back to +/- 14990' MD and low side sidetrack the well in open hole. 2. Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD). 3. Circulate the hole clean and pull out of hole. 4. Run 3-%2, 9.3#, L-80 tubing with SCSSSV, gas lift mandrels, landing nipple, sliding sleeve and packer. Land hanger. 5. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 6. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 7. Circulate tubing to diesel and install freeze protection in the annulus. 8. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 miss. 9. Set BPV and secure well. Move rig off. ORIGINAL i ~ ~ ~~ ~~ Well Proximity Risks: T~~ ~ ~~~~~~~ ~~~ r ~p~-~~~~rfC. h2~.~'S~h~ . Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-02 wilt be the closest well to CD2-03. Well separation is 6.8' @ 325' MD. Accounting for survey uncertainties, the ellipse-to-ellipse separation is 2.8' @ 325' MD. Drilling Area Risks: ~ ~~~~'~ ~~ Z©~~t ~~ ~~~~w~`\~~ ,~ `t ~ ~hcc ~vcc~.~~ .'r' S QS~ v~~- ~ ,lc~~(~c col\'~ ~~~1 There are no high-risk events (e.g. over-pressures zones) anticipated. ~ ~ gv~~ ~~"t~ 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. DRILLING FLUID PROGRAM Production Hole Section - 6 1 /8" Density 8.1-8.8 ppg PV 10 -15 YP 25 -30 Funnel Viscosity Initial Gels 10-15 10 minute gels 12-20 API Filtrate NA HPHT Fluid Loss at 160 12-14 cc/30 min PH 9.0-9.5 KCL 6% Oil /water ratio A rox.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 flashpoint (>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. ORIGINAL ~ • Completion Schematic TOC @ +/- 12850' MD / 6818' TVD Top Alpine C at 13595' MD / 7077' ND 16" Conductor to 114' 3-'/:" x 4'/z" cross-over, 2 jts below 4-'/2" hanger 3-1/2" Camco TRM-4E SSSV Nipple (2.813" ID) at 1937' ND = 2300' MD -2.813" X-Over -Single'/+'x0.049" s/s control line Updated 07/25/2005 9-5/8" 36 ppf J-55 BTC Sperry Sun Directional v WP03 Surface Casing Completion depths per original plan - ~ 32so' MD / 2381' ND revised TD and casing depths cemented to surface Camco KBUG GLM (2.867" ID) at 3400' TVD for Packer Fluid mix: E Dummy with 1" BK-2 Latch Diesel in tubing and annulus Completion Mfg IYQ 3-1/2" 9.3 ppf L-80 IBT Mod. R3 tubing run with Jet Lube Run'n'Seal Tubing Hanger 32' 32' pipe dope 4-''/2' 12.6 #/ft IBT-Mod Tubing (2) Crossover 3-1/2", 9.3#/ft, IBT-Mod Tubing Camco TRM4E SCSSSV 2300' 1937' 3-1l2", 9.3#/ft, IBT-Mod Tubing Camco KBUG GLM (2.867" ID) 5462' 3400' 3-1/2", 9.3#/ft, IBT-Mod Tubing Camco KBUG GLM (2.867" ID) ' Camco KBUG GLM (2.867" ID) 10220' 5600' at 5soo ND for E Dummy with 1" BK-2 Latch 3-1/2", 9.3#/ft, IBT-Mod Tubing ' Camco KBUG GLM (2.867" ID) 12850' 6816 3-1/2" tubing joints (2) Baker 3-1/2" CMD sliding sleeve 12950' 6862' wJ 2.81" X Profile 3-1/2" tubing joint (2) Camco KBUG GLM (2.867" ID) Baker Premier Packer 13050' 5908' 2 joints above sliding sleeve 3-1/2" tubing joints (1) E Dummy with 1" BK-2 Latch HES "XN" (2.75" ID)-64° inc 13110' 6936' 3-1/2" 10' pup joint / WEG 13122' 6941' Baker 3 Ys' CMD sliding sleeve with 2.81 "'X' Profile set 2 joints above packer CW 2.81" X Profile / Baker Premier Packer at +/- 13050' MD .- ~ ~ V -l`~~4~\ ~ .~-~- r14 1 Well TD at 15381' MD / ' 7090' TVD c.~aLa3 L+~ 7" 26 ppf L-80 BTC Mod Production Casing @ 13774 MD / 7111' ND 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) Csg Setting Depth MD/TVD ft Fracture Gradient (Ibs. / al Pore pressure (psi) ASP Drilling (psi) 16 114 / 114 10.9 52 53 9 5/8 3277 / 2390 14.5 1081 1563 7" 11395 / 7077 16.0 3202 2494 N/A 17294 / 7087 16.0 3207 N/A NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to minimum 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE fASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surtace, 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 ]D 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 Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1] D =[(10.9x0.052)-0.1]x114=53 psi OR ASP =FPP - (0.1 x D) = 1081 - (0.1 x 2390) =842 psi Drilling below surtace 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) = 3202 - (0.1 x 7082') = 2494 psi `` 3. Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) _ = 3207 - (0.1 x 7297') = 2477 psi ORIGINAL MD Inc Azim. SSND ND (ft) (Deg) (Deg) (ft) (ft) 5548.77 61.34 332.81 3382.21 3434.21 5643.86 60.72 333.41 3428.28 3480.28 5739.19 61.36 333.52 3474.44 3526.44 5834.80 61.51 333.76 3520.16 3572.16 5928.80 61.42 334.08 3565.07 3617.07 6023.99 61.35 334.82 3610.65 3662.65 6119.03 61.57 336.15 3656.06 3705.06 6214.06 61.90 335.88 3701.07 3753.07 6309.67 61.84 336.34 3746.15 3798.15 6403.52 61.75 335.00 3790.51 3842.51 6498.95 61.49 334.50 3835.87 3887.87 6594.24 61.02 334.78 3881.69 3933.69 6689.52 61.31 334.86 3927.65 3979.65 6784.86 60.66 334.91 3973.89 4025.89 6879.63 60.80 334.37 4020.24 4072.24 6974.54 61.22 334.27 4066.24 4118.24 7069.93 62.06 334.20 4111.55 4163.55 7165.16 62.48 333.29 4155.86 4207.86 7260.52 63.04 332.61 4199.52 4251.52 7355.99 64.47 331.86 4241.74 4293.74 7451.07 64.33 332.67 4282.82 4334.82 7546.14 63.44 332.19 4324.66 4376.66 7641.66 62.60 331.08 4367.99 4419.99 7737.15 62.88 330.02 4411.73 4463.73 7832.50 62.42 330.64 4455.53 4507.53 7927.84 62.27 331.14 4499.79 4551.79 8022.76 63.17 330.71 4543.29 4595.29 8118.14 63.30 331.47 4586.25 4638.25 8213.32 62.98 331.64 4629.26 4681.26 8309.24 63.30 332.79 4672.59 4724.59 8403.92 63.14 333.47 4715,25 4767.25 8499.42 63.24 333.57 4758.33 4810.33 8594.60 63.39 334.33 4801.07 4853.07 8689.21 63.46 334.19 4843.40 4895.40 8784.55 63.19 335.07 4886.21 4938.21 8879.52 62.54 334.79 4929.53 4981.53 8975.25 62.05 335.36 4974.04 5026.04 9070.12 62.32 335.87 5018.31 5070.31 9165.65 62.95 336.31 5062.22 5114.22 9261.15 63.01 336.47 5105.60 5157.60 9356.51 62.69 336.34 5149.12 5201.12 9451.72 62.69 335.77 5192.80 5244.80 9546.44 63.10 335.71 5235.96 5287.96 9642.12 63.30 336.50 5279.11 5331.11 9736.89 63.25 336.27 5321.73 5373.73 9832.16 62.76 335.81 5364.97 5416.97 9926.40 62.32 334.41 5408.42 5460.42 10021.72 62.42 333.86 5452.63 5504.63 10116.97 62.54 333.77 5496.63 5548.63 10212.08 62.41 333.12 5540.59 5592.59 10307.43 61.87 332.13 5585.15 5637.15 10402.72 62.04 332.04 5629.95 5681.95 10497.73 62.55 332.97 5674.12 5726.12 10593.03 62.13 332.94 5718.37 5770.37 10688.48 61.78 333.45 5763.25 5815.25 10783.85 61.77 334.03 5808.35 5860.35 10879.14 62.27 334.60 5853.06 5905.06 10974.75 62.06 334.11 5897.71 5949.71 11070.06 62.18 334.27 5942.28 5994.28 11165.36 61.84 334.45 5987.00 6039.00 11260.60 61.92 334.25 6031.89 6083.89 11355.81 62.83 334.30 6076.04 6128.04 11451.13 62.90 333.65 6119.51 6171.51 11546.00 63.23 333.83 6162.48 6214.48 11641.21 62.68 334.01 6205.78 6257.78 11736.46 62.47 333.85 6249.65 6301.65 11832.01 62.41 333.92 6293.85 6345.85 11916.49 62.26 334.62 6333.08 6385.08 12022.05 62.77 334.69 6381.80 6433.80 12116.41 62.61 334.40 6425.09 6477.09 12211.49 62.48 334.43 6468.93 6520.93 N/S E/W (ft) (ft) 3552.07 N 1536.28 W 3626.26 N 1573.90 W 3700.89 N 1611.16 W 3776.12 N 1648.45 W 3850.30 N 1684.75 W 3925.69 N 1720.79 W 4001.65 N 1755.43 W 4078.12 N 1789.45 W 4155.21 N 1823.60 W 4230.57 N 1857.67 W 4306.51 N 1893.49 W 4382.00 N 1929.27 W 4457.54 N 1964.78 W 4533.03 N 2000.17 W 4607.73 N 2035.58 W 4682.54 N 2071.55 W 4758.14 N 2108.04 W 4833.73 N 2145.33 W 4909.24 N 2183.88 W 4985.00 N 2223.77 W 5060.90 N 2263.68 W 5136.57 N 2303.19 W 5211.47 N 2343.63 W 5285.39 N 2385.36 W 5358.98 N 2427.28 W 5432.76 N 2468.37 W 5506.49 N 2509.36 W 5581.03 N 2550.53 W 5655.69 N 2590.98 W 5731.40 N 2630.86 W 5806.79 N 2669.07 W 5883.09 N 2707.07 W 5959.49 N 2744.42 W 6035.71 N 2781.16 W 6112.68 N 2817.66 W 6189.23 N 2853.47 W 6266.09 N 2889.19 W 6342.51 N 2923.83 W 6420.07 N 2958.22 W 6498.03 N 2992.29 W 6575.78 N 3026.26 W 6653.10 N 3060.59 W 6729.97 N 3095.23 W 6808.05 N 3129.83 W 6885.61 N 3163.73 W 6963.18 N 3198.21 W 7039.04 N 3233.40 W 7115.03 N 3270.24 W 7190.83 N 3307.52 W 7266.28 N 3345.22 W 7341.13 N 3383.98 W 7415.45 N 3423.35 W 7490.07 N 3462.19 W 7565.24 N 3500.57 W 7640.43 N 3538.56 W 7715.79 N 3575.73 W 7791.62 N 3612.20 W 7867.84 N 3648.80 W 7943.68 N 3685.48 W 8019.55 N 3721.89 W 8095.27 N 3758.25 W 8171.27 N 3794.87 W 8247.50 N 3832.09 W 8323.34 N 3869.51 W 8399.51 N 3906.79 W 8475.45 N 3943.94 W 8551.51 N 3981.23 W 8618.91 N 4013.71 W 8703.54 N 4053.80 W 8779.25 N 4089.83 W 8855.35 N 4126.27 W Y X DLS V.S. (ft) (ft) °/100ft (ft) 5978338.99 N 370209.60 E 1.09 3866.40 5978413.81 N 370173.25 E 0.85 3949.57 5978489.05 N 370137.28 E 0.68 4032.97 5978564.91 N 370101.29 E 0.27 4116.94 5978639.69 N 370066.26 E 0.32 4199.52 5978715.68 N 370031.52 E 0.69 4283.08 5978792.22 N 369998.19 E 1.25 4366.55 5978869.25 N 369965.48 E 0.43 4450.20 5978946.91 N 369932.66 E 0.43 4534.46 5979022.83 N 369899.88 E 1.26 4617.13 5979099.37 N 369865.38 E 0.53 4701.09 5979175.46 N 369830.89 E 0.56 4784.63 5979251.58 N 369796.68 E 0.31 4868.09 5979327.66 N 369762.60 E 0.68 4951.46 5979402.95 N 369728.48 E 0.52 5034.12 5979478.36 N 369693.79 E 0.45 5117.13 5979554.57 N 369658.61 E 0.89 5201.07 5979630.78 N 369622.62 E 0.95 5285.36 5979706.93 N 369585.36 E 0.87 5370.13 5979783.36 N 369546.78 E 1.66 5455.70 5979859.92 N 369508.18 E 0.78 5541.40 5979936.25 N 369469.98 E 1.04 5626.73 5980011.83 N 369430.83 E 1.36 5711.78 5980086.44 N 369390.37 E 1.03 5796.50 5980160.73 N 369349.71 E 0.76 5881.00 5980235.20 N 369309.90 E 0.49 5965.31 5980309.61 N 369270.18 E 1.03 6049.55 5980384.85 N 369230.29 E 0.72 6134.59 5980460.18 N 369191.14 E 0.37 6219.41 5980536.55 N 369152.55 E 1.12 6304.93 5980612.59 N 369115.65 E 0.66 6389.44 5980689.51 N 369078.96 E 0.14 6474.67 5980766.53 N 369042.93 E 0.73 6559.71 5980843.36 N 369007.49 E 0.15 6644.33 5980920.94 N 368972.32 E 0.87 6729.51 5980998.09 N 368937.83 E 0.73 6814.02 5981075.54 N 368903.43 E 0.73 6898.76 5981152.54 N 368870.11 E 0.55 6982.64 5981230.67 N 368837.06 E 0.78 7067.43 5981309.19 N 368804.32 E 0.16 7152.44 5981387.51 N 368771.70 E 0.36 7237.22 5981465.40 N 368738.70 E 0.53 7321.77 5981542.84 N 368705.38 E 0.43 7406.05 5981621.50 N 368672.13 E 0.77 7491.40 5981699.62 N 368639.55 E 0.22 7575.98 5981777.76 N 368606.42 E 0.67 7660.82 5981854.20 N 368572.53 E 1.40 7744.43 5981930.81 N 368537.00 E 0.52 7828.88 5982007.24 N 368501.03 E 0.15 7913.35 5982083.31 N 368464.62 E 0.62 7997.69 5982158.81 N 368427.15 E 1.08 8081.96 5982233.78 N 368389.06 E 0.20 8166.00 5982309.05 N 368351.51 E 1.02 8250.09 5982384.86 N 368314.43 E 0.45 8334.48 5982460.68 N 368277.73 E 0.60 8418.71 5982536.66 N 368241.85 E 0.54 .8502.73 5982613.10 N 368206.69 E 0.74 8586.88 5982689.93 N 368171.41 E 0.50 8671.43 5982766.38 N 368136.04 E 0.20 8755.68 5982842.85 N 368100.93 E 0.40 8839.83 5982919.18 N 368065.87 E 0.20 8923.83 5982995.78 N 368030.57 E 0.96 9008.18 5983072.63 N 367994.66 E 0.61 9093.01 5983149.10 N 367958.54 E 0.38 9177.59 5983225.89 N 367922.58 E 0.60 9262.38 5983302.45 N 367886.73 E 0.27 9346.93 5983379.13 N 367850.75 E 0.09 9431.64 5983447.07 N 367819.43 E 0.76 9506.46 5983532.37 N 367780.80 E 0.49 9600.10 5983608.67 N 367746.07 E 0.32 9683.94 5983685.38 N 367710.95 E 0.14 9768.31 ORIGINAL MD inc Azlm. SSND ND N/S E1VV Y X DLS V.S. SVY # (ft) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) °/100ft (ft) 134 12306.92 62.18 334.22 6513.24 6565.24 8931.52 N 4162.88 W 5983762.16 N 367675.64 E 0.37 9852.82 135 12401.97 61.76 333.80 6557.91 6609.91 9006.94 N 4199.65 W 5983838.19 N 367640.17 E 0.59 9936.72 136 12496.90 61.44 334.79 6603.06 6655.06 9082.17 N 4235.87 W 5983914.03 N 367605.25 E 0.98 10020.23 137 12592.37 62.01 334.99 6648.29 6700.29 9158.31 N 4271.55 W 5983990.75 N 367570.88 E 0.62 10104.30 138 12687.40 62.95 334.90 6692.20 6744.20 9234.65 N 4307.24 W X984067.69 N 367536.51 E 1.00 10188.56 139 12782.86 63.31 334.19 6735.35 6787.35 9311.53 N 4343.84 W 5984145.18 N 367501.23 E 0.76 10273.71 140 12877.84 64.09 333.02 6777.44 6829.44 9387.80 N 4381.69 W 5984222.08 N 367464.69 E 1.38 10358.85 141 12973.10 64.88 332.61 6818.47 6870.47 9464.27 N 4420.97 W 5984299.21 N 367426.73 E 0.92 10444.80 142 13068.12 64.90 332.89 6858.79 6910.79 9540.76 N 4460.36 W 5984376:36 N 367388.65 E 0.27 10530.81 143 13161.89 67.72 332.39 6896.47 6948.47 9617.01 N 4499.83 W 5984453.26 N 367350.51 E 3.05 10616.64 144 13259.04 72.22 333.78 6929.74 6981.74 9698.38 N 4541.12 W 5984535.32 N 367310.62 E 4.83 10707.87 145 13353.80 74.14 334.11 6957.16 7009.16 9779.87 N 4580.95 W 5984617.47 N 367272.18 E 2.05 10798.57 146 13449.07 74.39 333.59 6983.00 7035.00 9862.18 N 4621.37 W 5984700.46 N 367233.19 E 0.59 10890.27 147 13544.07 74.18 333.05 7008.73 7060.73 9943.89 N 4662.43 W 5984782.85 N 367193.53 E 0.59 10981.71 148 13639.11 76.31 333.02 7032.94 7084.94 10025.80 N 4704.10 W 5984865.45 N 367153.27 E 2.24 11073.59 149 13647.93 76.66 333.04 7035.00 7087.00 10033.44 N 4707.99 W 5984873.16 N 367149.52 E 4.06 11082.17 150 13661.20 77.20 333.08 7038.00 7090.00 10044.97 N 4713:84 W 5984884.78 N 367143.86 E 4.06 11095.09 151 13734.34 80.16 333.26 7052.35 7104.35 10108.96 N 4746.21 W 5984949.31 N 367112.59 E 4.06 11166.79 152 13783.99 82.81 331.85 7059.71 7111.71 10152.53 N 4768.84 W 5984993.26 N 367090.71 E 6.02 11215.87 153 13815.36 84.48 330.97 7063.18 7115.18 10179.90 N 4783.76 W 5985020.88 N 367076.27 E 6.02 11247.01 154 13846.16 86.33 327.34 7065.65 7117.65 10206.25 N 4799.50 W 5985047.50 N 367060.98 E 13.20 11277.59 155 13877.34 89.25 323.48 7066.85 7118.85 10231.89 N 4817.18 W 5985073.44 N 367043.74 E 15.51 11308.38 156 13910.04 93.07 321.22 7066. t 9 7118.19 10257.77 N 4837.15 W 5985099.65 N 367024.23 E 13.58 11340.38 157 13939.88 93.75 321.31 7064.42 7116.42 10281.01 N 4855.79 W 5985123.20 N 367005.99 E 2.29 11369.42 158 13972.55 94.70 322.76 7062.01 7114.01 10306.69 N 4875.83 W 5985149.22 N 366986.39 E 5.30 11401.28 159 14067.83 94.87 330.85 7054.06 7106.06 10386.08 N 4927.77 W 5985229.48 N 366935.82 E 8.46 11495.37 160 14113.28 91.46 334.72 7051.55 7103.55 10426.43 N 4948.51 W 5985270.17 N 366915.77 E 11.33 11540.72 161 14163.81 92.08 337.44 7049.99 7101.99 10472.59 N 4968.99 W 5985316.67 N 366896.09 E 5.52 11591.20 162 14196.88 88.44 337.88 7049.83 7101.83 10503.17 N 4981.56 W 5985347.46 N 366884.05 E 11.09 11624.20 163 14259.26 87.52 339.43 7052.03 7104.03 10561.23 N 5004.25 W 5985405.90 N 366862.36 E 2.89 11686.34 164 14314.72 85.53 333.23 7055.40 7107.40 10611.91 N 5026,46 W 5985456.94 N 366841.02 E 11.72 11741.63 165 14354.71 88.75 328.14 7057.39 7109.39 10646.72 N 5046.01 W 5985492.08 N 366822.07 E 15.05 11781.48 166 14449.54 91.09 324.92 7057.53 7109.53 10725.80 N 5098.29 W 5985572.04 N 366771.15 E 4.20 11875.46 167 14494.50 91.53 325.32 7056.50 7108.50 10762.68 N 5124.00 W 5985609.35 N 366746.08 E 1.31 11919.85 168 14545.30 90.85 332.00 7055.44 7107.44 10806.03 N 5150.40 W 5985653.14 N 366720.43 E t 3.21 11970.38 169 14638.86 89.42 332.82 7055.23 7107.23 10888.95 N 5193.73 W 5985736.78 N 366678.53 E 1.77 12063.90 170 14683.50 89.62 333.07 7055.60 7107.60 10928.70 N 5214.03 W 5985776.88 N 366658.91 E 0.72 12108.53 171 14735.90 89.37 332.88 7056.07 7108.07 10975.38 N 5237.84 W 5985823.95 N 366635.90 E 0.60 12160.91 172 14779.03 88.94 332.71 7056.71 7108.71 11013.73 N 5257.56 W 5985862.63 N 366616.85 E 1.08 12204.03 173 14829.68 88.43 331.94 7057.87 7109.87 11058.58 N 5281.08 W 5985907.87 N 366594.10 E 1.82 12254.64 174 14881.92 88.75 332.19 7059.16 7111.16 11104.72 N 5305.54 W 5985954.42 N 366570.43 E 0.78 12306.83 175 14926.58 88.57 331.43 7060.20 7112.20 11144.07 N 5326.63 W 5985994.12 N 366550.02 E 1.75 12351.44 Tie-in Point 176 - 14991.00 91.07 328.76 7060.41 7112.41 11199.90 N 5358.74 W 5986050.49 N 366518.87 E 5.68 12415.69 Sidetrack Point 177 15022.03 89.18 329.48 7060.34 7112.34 11226.53 N 5374.67 W 5986077.39 N 366503.41 E 6.50 12446.60 Last available Survey 178 15049.94 91.25 329.48 7060.23 7112.23 11250.57 N 5388.84 W 5986101.66 N 366489.65 E 7.41 12474.42 179 15087.03 94.00 329.48 7058.53 7110.53 11282.49 N 5407.65 W 5986133.89 N 366471.38 E 7.41 12511.34 180 15099.94 94.00 329.48 7057.63 7109.63 11293.58 N 5414.19 W 5986145.10 N 366465.04 E 0.00 12524.18 181 15199.94 94.00 329.48 7050.66 7102.66 t 1379.52 N 5464.85 W 5986231.88 N 366415.86 E 0.00 12623.61 182 15299.94 94.00 329.48 7043.68 7095.68 11465.45 N 5515.51 W 5986318.66 N 366366.68 E 0.00 12723.04 183 15381.40 94.00 329.48 7038.00 7090.00 11535.45 N 5556.78 W 5986389.35 N 366326.62 E 0.00 12804.03 TD ORIGINAL - ~°0~ swsn°~ o,rxvoiniarrs COM^~O~']~'"I ~C ga„~,yoa~"~"`(a..,a,l~n., Project Colville River Unit No annotannn Antdil5 hll on the wellbore. RJ r" J ~~~; site: aPlne CD2 ~..1:k:8 Oiatl11 0 ~DU,e~,~ emm~ Well: Drilling: CD2-03 Welibore: Drilling: CD2-03L1 HALLIBURTON ~~~~, r ~K~ u~ry~,,,~eae:-~s~, Plan: (,`DZ-Q3L1WpO4 _ ~<y,,,,~ ~ u~r Sperry Drilling Services ~~„~~","`"; ~ ,` '~~ srtTlDr1 Dein~s Set MD t¢ Ad TND FWS +EINV Dleg TFaoe VSec Tage[ 1 15022.030 89.183329.4800 7112.33911226.532.5374.666 0.00 0.000012446.600 2 15087.030 94.000329.4800 7110.53411282.4885407.653 7.41 0.000012511.343 3 15381.395 94.000329.4800 7090.00011535.4515558.779 0.00 0.000012804.028 12000 - __ __- _ - - - } O L~1 C, D 1 n5o _ ~V1~ O,yA G 11500 ~ - - - - '__ c N t t= O Z 11250 _ - L 3 O h 11000 __. ._- - -__ ------ ---- - __ __ 10750 _. _.. _.. _- - --.._. -- _ I fa2J0 41000 b750 fifAO {250 {A00 4750 -0500 4250 -0000 Wit(-YF~t(+) (2501~r1) ~, r ~~~ +~ ~ .,~ ~~i~ } - _ -~ ~ s_~_ .~.. ~.. _~...~ .~:.. _.... C RU C D2-03 L 1 i - - ,. ~ , Proposed Producer ...... ,,:. _... , ..,4, . .SHARON K. ALLSUP-DRAKE ~ ' ~~~ CONOCOPHILLIPS 1107 AT01530 700 G ST, ,nom'" :ANCHORAGE AK995o1 onrE~~ Z( ,~cvJ w 62-14/311 `-~ PAY TO THE ~ir ,~ O~ ~ rf~. .;, F--r r , ~ ORDER OF ( (/ F--r t ....-~-. C~~ of C ia, o~, _ 3 ~ ~ ,,p~ ' CHA ~Oe~~OLLARS L!1 ~°.o~~"° r .Chase Manhattan Bank USA, N.A. SE zDD Whke Clay CeOter Dr, Newark, DC 19)11 Valid Up to 5000 Dollars MEMO. ,,//~~ _._ _ Y ^~ _ _._ -~-=----- - -- -- NP ~~: 0 3 i L 0 0 L 4 4 ~: 2 a 8 4 7 ~ 9 0 7 9 27 611' 1 1 0 7 - -- ---- -_____-_ .. ~.. . ,, ._. -_ ~.,.-~,.,~T., _ , - , • • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# ceu ~z -c~~ r z~ ~~ ~~.~ CHECK WHAT ADD-ONS "CLUE" APPLIES OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well ~'!~ ~- ~ L'-~ ZUSlz `~ OG' ~ . Permit No, ~~'`~yAPI No. (If API number Production should continue to be reported as last two (Z) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(fj, all (p)er records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/SO) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with ZO AAC 25.055.. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. _.~,~ Rev: 04/01/05 C\ j o d y\tr a n s m i tta I_c h e c k! i s i ELL PERMIT CHECKLIST Field & Pool COLVILLE RIVER, ALPINE OIL -120100 Well Name: COLV{LLE RIV UNIT CD2-03L1 Program DEV Well bore seg ~ PTD#: 2051130 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType DEV / PEND GeoArea 890 Unit 50360 On/Off Share On Annular Disposal ^ Administration 1 Permit-fee attached_ - _ - _ _ - -Yes - This is in.exploratoryJateraldgsigned to gather geologic data and determine the base of the Alpine-Fm. - - - - - 2 Lease number appropriate- - _ _ - _ - _ - No_ - - - - _ Corrected 10-407: Surface location for CD2-03 lies in ADL 380.075. -This_well course_ lies alongthe boundary . 3 Unique well_name and number _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . _ _ _ . - _ between ADL 387212 &ADL 025530, but TD is expected to-lie within 025530. No correlative rights_issues. _ _ _ _ _ 4 Well located in a_definedpo4l___ __________________________-__ ---__Yes-__ _Colville-Rivet Unit, Alpine Oil Pool,governed_byCO443A..__-__-____--_- __-_____-- --_-- 5 Well located proper distance_ from drilling unitboundary_ - - - - - Yes - - - - Nearest property line_iS approximatelg6500 feetaway.- - , _ - - _ _ 6 Well located proper distance from other wells_ - _ _ _ - _ - - - - -Yes . - - . - -More than 500 lineal feet of another Alpine Oil Pootdeyelopment_well.- _ - - - - 7 Sufficient acreage available indtillingunit___________________________ ____Yes-_-_, _-_-__-._ ----------------------------------------------------------- 8 If deviated, is-wellbore plat_included - - - - - - - -Yes . - - - - - - - - - 9 Ope[ator only affected party - - - - - - - - -Yes . - - - - - - - - - - - - 10 Opetatorhas-appropriate-bond %n force- ---- --------- ---- ------ -- --Yes.---- - -- ----------- -- --~---- --~ -- -- -------- ----- ----------- -- 11 Permit_canbeissuedwithoutconservationorder____--_--------------- -----Yes--__ --_---__--__---_-------_--___-----------__.__.._____.-__.-__-.-- Appr Date 12 Pe[mitcanbeissuedwithautadministrative_approval____________________ _____Yes,__-_ -___-___--__--__-. SFD 7!2812005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized bylnjectionOrder#(put_19#in_comments)-(For- NA_,--__ ---_- _---__----------------------------------------- ----_. -.---- 15 All wellsvrithin114_milearea_ofreyiewidentified(Forsen[icewellonly)__________ _____ NA_-___ ---_---__-_______.._-_-___-_._-_--____-___.___.___.-__--_._____-..-._, 16 Pte-produced injector: duration of pre-p[oduction Less than 3 months-(Forservice well only) _ - NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - 17 ACMP-Finding of Consistency_has been issued_forthis p[oject_ - _ - _ _ NA_ - _ Multilateral-will branch of an-existing_well._ - . _ _ _ ------------------- Engineering 18 Conductor string provided - - - _ - NA_ _ _ - _ _ Conductor setin mother_bare,-CD2r03-(205r092~. _ _ 19 Su_rfacecasing-proteclsallknownUSDWs.__._-.__.____-__ ___NA---__ --NOaquifers,_perA1O18Aconclusion3.__--___ -_______-_________________________ 20 CMT.vol_adeguate-tgcircul_ate_onconductor&surf-csg_--__--__-___--___ ,-_, NA_-___- _Surf-ace ca-sing set in_Gq2-03._-_.-_--______-___--__-__--_---____-,_ 21 CMT_voladequate_to tie-in long string tosurf csg_ - . - NA_ - _ _ Production_casing set in CD2-03, All hydrocar_bons_planned_to be covered,_ - - - - _ _ 22 CMT.willcoyer_allkno_w_n-productive horizons_--_---__-______-__-- ,__--No_-__-.- _Open_holecompletionplanned.-__--___-___ _________________ ___, 23 Casing designsadequafefo[C,T,6&_permafrost-------------------_- --_- NA_-__--_ _NOCasingset in this lateral,_,-__-____________-__--__,-__.-__--__-._- _-_- 24 Adequate tan_kageo_r reserve pit - - - Yes - _ _ Rig is-equipped with steelpits.-No reserve_p_itplanned: All waste to approved annulus or CI_ass II well. 25 If_a_re-drill,has_a10-4.03forabandonmentbeenapproved_--__--_____- -____ NA____-__ _-.__________________________-__--__--___-___-__--__---_--___-____- 26 Adequate wellbofe separationproposed- - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes _ - . _ _ - Nearest wellbore will beprimary penetration in_Alpine.. - - - _ _ - - . _ - - . - . - - .. - - . _ - - - ' 27 Ifdive[terrequired,doesitmeet-regulations___________________,__ _-__. NA_-___- _6OPstack-already in place.-_--______-___-__---_---_ Appr Date 28 Drilling fluid-program schematic-& equip list adequate- - - - - - - - - - - - - -Yes - - Maximum expected formation pressure 8,7_EMW._ Planned MW up ko 8,8 ppg, . - TEM 7!2 9!2005 29 BOPES,dolheymeet_regulation--- ------------------------_ _----Yes----- --.----------------_-----------------------------,----------- - ^ 9 N' 1 30 BOPE_press rating appropriate; test to-(pu_t psig i_n comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - - _ _ - - MA$P calculate_dat 2494psi._ 3500_psi-appropriate, CPAI_ normally tests to 50.00 psi._ - _ _ - - _ _ _ _ _ _ - _ - - _ \ 31 Choke-manifold compliesw/API_RP-53(May84)_______________________ _____Yes-___- -_.-__ --------------------------------------------------------------- 32 Work willocc_urwithoutoperationshutdown---__-___-__ _-~-__-__ --___Yes____- -____--__--__--_.--_________________ 33 Is presence-of H2$ gas-probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ - - _ _ - _ H2$ has notbeen [eported at Alpine. _Rig is equipped with sensors and_ alarms.- - _ - - _ _ . - _ _ _ - _ - - _ _ - _ 34 Mechanical condition of wells within AOR verified (ForseCvice well only) _ _ _ _ _ - - NA_ _ _ _ . _ ---------------------------------------------- Geology 35 Permitcanbeissuedwlohydrogen_sulfidemeasures_.-__-___________ _____Yes-__--_ _-.___---------- ---____--___-_.____-_____-__--__--__--_____-__-__ 36 Data-presented on-potential overpressure zones _ - - _ - - - _ _ . - - - - - _ Yes _ Expected reservoirpressure is 8,7-ppg EMW; will be drilled with 8.1 - 8.8 ppg mud. - - - _ _ - _ Appr Date 37 Seismic analysis-of shallowgas-zones--_---_----_--------------- _-__. NA_--__-- __.-__--____ - - SFD 7128!2005 38 Seabed conditionsurvey_(ifoff-shoCe)_--________-________________ _____ NA_____- ____-___-___ 39 _Contactnam_elphoneforweeklyprogressreports[exploraioryonly]-_____--__- -__--Yes______ __________-__-._---.----__---_-_.--_-----_-__-.._-.-__.- ---_._ Geologic Engineering Public Commissioner: Date: Commissioner: Date Co si er Date Q ~s ~~ 2~~~ G~~j~ ~-29_~ ~ ZQ 6~ • • Well History File APPENDIX • Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify f finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronological{y . organize this category of information. Sperry-Sign Drilling Services ~,IS Scan Utility $Revision: 3 S LisLib $Revision: 4 $ Fri Aug 19 10:23:28 2005 Reel Header Service name .............LISTPE Aate .....................05/08/19 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Tape Header Service name .............LISTPE Date .....................05/08/19 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 CD2-03 L1 501032051260 ConocoPhillips Alaska, Inc. Sperry Drilling Services 19-AUG-05 MWD RUN 2 MWD RUN 3 MWD RUN 4 JOB NUMBER: MW0003811902 MW0003811902 MW0003811902 LOGGING ENGINEER: M. HANIK R. KRELL R. KRELL OPERATOR WITNESS: A. LUTRICK D. LUTRIK D. LUTRICK SURFACE LOCATION SECTION• 2 TOWNSHIP: 11N RANGE: 4E FNL: 1597 FSL: FEL: 1560 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 52.50 GROUND LEVEL: 15.9D WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE CIN) SIZE (IN) DEPTH (FT) 1ST STRING 8.750 9.625 3260.0 2ND STRING 6.125 7.000 13774.0 3RD STRING PRODUCTION STRING 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 CD2-03 AT I4991'MD/7II2'TVD. a ~ ~~~~~ • • 9. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 5. MWD RUNS 2 - 4 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AND PRESSURE WHILE DRILLING (PWD). RUN 2 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). RUNS 3 & 4 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 1 - 4 REPRESENT WELL CD2-03 L1 WITH API#: 50-103-20512-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15356'MD/7093'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITX (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.......05/08/19 Maximum Physical Record..65535 File Type .. .............LO Previous File Name.......STSLiB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Aepth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH FET 3224,5 15298.5 RPD 3224,5 15298.5 RPM 3224,5 15298.5 RPS 3224,5 15298.5 RPX 3224,5 15298.5 GR 3232,5 15292.5 ROP 3270,5 15356.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ---- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BTT RUN NO MERGE TOP MERGE BASE MWD 2 3224.5 13784.0 MWD 3 13784.0 14991.0 MWD 4 14991.5 15356.0 • S REMARKS: MERGED MAIN PAS5. 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 5pacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3224.5 15356. 9290.25 24264 3224.5 15356 ROP MWD FT/H 1.38 401.85 194.59 24172 3270.5 15356 GR MWD API 22:96 377.64 107.143 24121 3232.5 15292.5 RPX MWD OHMM 0.55 1554.92 11.1319 24149 3224.5 15298.5 RPS MWD OHMM 0.12 2000 13.9715 24149 3224.5 15298.5 RPM MWD OHMM 0.13 2000 22.7071 24149 3224.5 15298.5 RPD MWD OHMM 0.12 2000 32.4924 29149 3224.5 15298.5 FET MWD HOUR 0.16 95.96 1.21207 24149 3224.5 15298.5 First Reading For Entire File..........3229.5 Last Reading For Entire File...........15356 File Trailer Service name .............STSLIB.001 Service Sub Level Name... version Number...........1.0.0 Date of Generation.......05/08/19 Maximum Physical Record..65535 File Tyge ................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.......05/08/19 Maximum Physical Record..65535 File Type ................LO Previous Fiie Name.......STSLiB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT; .5000 FILE SUMMARY • • VENDOR TOOL CObE START DEPTH STOP DEPTH RPD 3224.5 13738.0 RPM 3224.5 13738.0 RPS 3224.5 13738.0 RPX 3224.5 13738.0 FET 3224.5 13738.0 GR 3232.5 13745.5 ROP 3270.5 13784.0 S LOG HEADER DATA DATE LOGGED: 19-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION; Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 13784.0 TOP LOG INTERVAL (FT): 3270.0 BOTTOM LOG INTERVAL (FT): 13784.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE; 60.6 MAXIMUM ANGLE: 80.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOQL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 121079 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 3260.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (S): 37.0 MUD PH: 8.6 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3}: 7.0 RESISTIVITY (OHMM) AT TEMPERAT URE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2.400 80.0 MUD AT MAX CIRCULATING TERM PERATURE: 1.390 143.0 MUD FILTRATE AT MT: 1.600 80.0 MUD CAKE AT MT: 2.500 80.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS; S 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...0 Name Service Order Units Size Nsam Rep Cade 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 6$ 12 9 RPS MWD020 OHMM 4 1 68 16 5 • • RPM MWD020 OHMM 9 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First List Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3224.5 13784 8504.25 21120 3224.5 13784 ROP MWD020 FT/H 2.67 354.77 211.20$ 21028 3270.5 13784 GR MWD020 API 40.47 377.64 115.032 21027 3232.5 13745.5 RPX MWD020 OHMM 0.55 1554.92 6.02073 21028 3224.5 13738 RPS MWD020 OHMM 0.12 2000 6.36644 21028 3224.5 13738 RPM MWD020 OHMM 0.13 1809,23 8.89013 21028 3224.5 13738 RPD MWD020 OHMM 0.12 2000 13.3995 21028 3224.5 13738 FET MWD020 HOUR 0.16 61.04 0.624946 21028 3224.5 13738 First Reading For Entire File..........3224.5 Last Reading For Entire File...........13789 File Trailer Service name.... ......STSLIB.002 Service Sub Level•Name... Version Number...........1,0.0 Date of Generation.......05/08/19 Maximum Physical Record..65535 File Type ................L0 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.......05/08/19 Maximum Physical Record..65535 File Type ................L0 Previous File Name.......STSLiB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 13738.5 14991.0 RPD 13738.5 14991.0 RPM 13738.5 14991.0 RPS 13738.5 14991.0 RPX 13738.5 14991.0 GR 13746.0 14991.0 ROP 13784.5 14991.0 S LOG HEADER DATA DATE LOGGED: 25-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 14991.0 TOP LOG INTERVAL (FT): 13784.0 BOTTOM LOG INTERVAL (FT): 14991.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.3 MAXIMUM ANGLE: 94.9 • • TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156435 EWR4 Electromag Resis. 4 153663 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CA5TNG DEPTH (FT): 13774.0 BOREHOLE CONDITIONS MUD TXPE: MOBM MUD DENSITY (LB/G): 9.40 MUD VISCOSITY (S): 57.0 MUD PH: .0 MUD CHLORIDES (PPM): 76000 FLUID LOSS (C3): 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE {MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 251..0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .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 .lIN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 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 OR 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 13738.5 14991 14364.8 2506 13738.5 14991 ROP MWD030 FT/H 1.76 401.85 93.8484 2414 13784.$ 14991 GR MWD030 API 22.96 145.41 51.4953 2491 13746 14991 RPX MWD030 OHMM 2.18 777.95 42.9335 2506 13738.5 14991 RPS MWD030 OHMM 2.47 2000 62.216 2506 13738.5 14991 RPM MWDfl30 OHMM 1.25 2000 111.867 2506 13738.5 14991 RPD MWD030 OHMM 5.05 2000 149.199 2506 1373$.5 14991 FET MWD030 HOUR 0.45 95.96 5.22459 2506 13738.5 14991 First Reading For Entire File..........13738.5 Last Reading For Entire File...........14991 File Trailer • • Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/08/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0,0 Date of Generation.......05/08/19 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 14991.5 15298.5 RPM 14991.5 15298.5 RPS 14991,5 15298.5 RPX 14991.5 15298.5 GR 14991.5 15292.5 ROP 14991.5 15356.0 FET 14991.5 15298.5 S LOG HEADER DATA DATE LOGGED: 27-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 15356.0 TOP LOG INTERVAL (FT): 14991.0 BOTTOM LOG INTERVAL (FT): 15356.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 89.0 MAXIMUM ANGLE: 95.8 TOOL STRING (TOp TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY. 156435 EWR4 Electromag Resis. 4 153663 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 13774.0 BOREHOLE CONDITIONS MUD TYPE: MOBM MUD DENSITY fL$/G}; 9.40 MUD VISCOSITY (S): 57.0 MUD PH: .0 MUD CHLORIDES (PPM): 76000 FLUID LOSS (C3): 1.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 154.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .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 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 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 Readinq Reading DEPT FT 14991.5 153'56 15173.8 730 14991.5 15356 ROP MWD040 F"P/H 1.38 308.81 49.0943 730 14991.5 15356 GR MWD040 API 23.87 154.86 61.9103 603 14991.5 15292.5 RPX MWD040 OHMM 2.74 102.24 56.3065 615 14991.5 15298,5 RPS MWD040 OHMM 2.87 135.93 77.4164 615 14991.5 15298.5 RPM MWD040 OHMM 3.04 2000 131.824 615 14991.5 15298.5 RPD MWD040 OHMM 3.46 2000 209.754 615 14991.5 15298.5 FET MWD040 HOUR 0.74 45.23 4.93662 615 14991,5 15298.5 First Reading For Entire File......,...14991.5 Last Reading For Entire File...........15356 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/08/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................05/08/19 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 .....................05/08/19 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF • Writing Library. Scientific Technical Services End Of L15 File
