Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
207-023
Image P~ject Well Hist®ry File Cr 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. - ~~~ Well History File Identifier Organizing (done) ,.o.,a~ iiui~iiiiiiium „R..~a~~~~ iuuiuimuuuu RE AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: DIGITAL DATA Diskettes, No. I ^ Other, No/Type: BY: Maria Date: ~ ~ ~~ Project Proofing BY: Maria Date: Scanning Preparation ~~ x 30 = QY: Mariam Date: ~ ~ Production Scanning OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: Jmumiimiui P + _~ =TOTAL PAGES (Count does not include cover sheet) a /~/~ /s/ ~ r Stage 1 Page Count from Scanned File: ~ (Count does include cover heet) hes Number in Scann'n Pre aration: !~ YES Page Count Matc g P - BY: Maria Date: ~? ~ ~7 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO /s/ ~ ~/ I NO BY: Maria Date: ~s~ Scanning is complete at this point unless rescanning is required. II I II II II I II II I I III ReScanned III 111111 IIIII II III BY: Maria Date: /s~ his file: Quality Checked III II'lll III II'I II Comments about t 10/6/2005 Well History File Cover Page.doc ~. ~... ~~, ~~ ~; ~~ ~~~ w_ ,. 'sf k MICROFILMED- 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:ltemp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~EC~~~ ~ STATE OF ALASKA APR ~~~~ OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION:OR RECOMPLETION REPORT. AND LOG 1a. Well Status: Oil ^ ther ^ Abandoned Q r Suspended ^ ~~ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WAG ^ WDSPL ^ No. of Completions: 1b. Well Class: Development 0 ~ Exploratory ^ Service ^ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: March 13, 2010 12. Permit to Drill Number. 207-023 / 309-388 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: April 9, 2007 13. API Number: 50-103-20543-00 4a. Location of Well (Governmental Section): Surface: 1382' FSL, 680' FEL, Sec. 5, T12N, R5E, UM 7. Date TD Reached: April 25, 2007 14. Well Name and Number: CD3-301 Top of Productive Horizon: 184' FNL, 2236' FEL, Sec. 32, T13N, R5E, UM 8. KB (ft above MSL): 50' RKB GL (ft above MSL): 37' AMSL 15. Field/Pool(s): Colville River Field Total Depth: 1462' FSL, 415' FWL, Sec. 28, T13N, R5E, UM 9. Plug Back Depth (MD + TVD): 10480' MD / 6342' TVD Fiord Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 388364 y- 6003874 Zone- 4 10. Total Depth (MD + TVD): 15140' MD 6774' TVD 16. Property Designation: ADL 372105, 364472, 364471 TPI: x- 389557 y- 6012850 Zone- 4 Total Depth: x- 392226 - 6014457 Zone- 4 11. SSSV Depth (MD + TVD): 2306' MD / 2006' TVD 17. Land Use Permit: 2112 18. Directional Survey: Yes ^ Noa (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost MDlTVD: 1262' MD / 1250' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): none 22. Re-drill/Lateral Top Window MDlfVD not applicable 23. 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 36' 114' 36' 114' 24" 362 sx Class G 9.625" 40# L-80 36' 3233' 36' 2493' 12.25" 409 sx AS Lite, 234 sx Class G 7" 26# L-80 36' 12062' 36' 6849' 8.75" 147 sx Class G 4.5" 12.6# L-80 11883' 15121' 6824' 6775' 6.125" slotted /blank liner 24. Open to production or injection? Yes ^ No ^ If Yes, list each 25. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET (MDlrVD) 4.5" 10480' slotted liner squeezed off , ~ ~ 6 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. I -~. ~, u~ ' DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 10733' 102 bbls Class G 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) abandoned 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) 28. CORE DATA Conventional Core(s) Acquired? Yes ^ No O Sidewall Cores Acquired? Yes ^ No ^ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only RBDMS APR 0 9 Z0~ c~~ ~ ~, ~~ ~~~~~ 28. GEOLOGIC MARKERS (List all formations and marker untered): 29. FORMATION TESTS NAME MD TVD Well tested? ^ Yes ^~ No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1262' 1250' needed, and submit detailed test information per 20 AAC 25.071. Kuparuk D 11780' 6487' Kuparuk C 12000' 6842' N/A Formation at total depth: 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Daniel Herrmann @ 263-461 ~~~ Printed Name G. L. Alvord Title: Alaska Drilling Manager / ~ C~ ~ 2 O ( o ~~ ~ Signature Phone 265-6120 Date INSTRUCTIONS 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 CD3-301 PSheet1 Well Events DATE SUMMARY 1/7/10 TPOT- PASSED; T PPPOT- PAS ; IC POT- PASSED; IC PPPOT- PASSED!fUNCTION TEST LDS 1/9/10 PULLED 3.812" WRDP FROM 2306' RKB. PULLED OV FROM 10,732' RKB. WELL IS READY FOR COIL. - ~; " 1/13/10 PUMPED 102 BBLS 15.8 PPG CLASS-G CEMENT FROM 10600 CTMD, PSISHED 57 BBLS BEHIND PIPE, SPOTTED BIOZAN IN MANDREL AT 10732 RKB, FREEZE PROTECTED WITH 35 DIESEL, TRAPPED 1230 PSI ON TUBING. 1/14/10 TAGGED CEMENT @ 10,733' SLM W/ 3.65" CENT AND 10' x 2.5" BAILER, MIRU LRS AND PUMPED DOWN TBG FQR CMIT-TxIA TO 2000 PSI, HELD FOR 30 MINUTES WITH NO LOSS OF PRESSURE, BLED TO 0 PSI. COMPLETE. 1/17/10 CUT TUBING WITH RCT-2937-300 AT DEPTH OF 10480'. TOOLSTRING STUCK AFTER GUYING TUBING, AND AWAITING SLICK LINE TO FISH TOOLSTRING OUT OF WELL. 1/18/10 RECOVERED E-LINE TOOLSTRING FROM 10,464' SLM ****PRESSURE BALANCE ANCHOR LEFT IN HOLE"**" COMPLETE. ~t/1',~ 3/6/10 Blow down & disconnect lines, Move Pipe shed, Boiler room, Motor room & Rock washer. 3/7/10 Move to CD3-301, Rig up, Accept rig @ 12:00 hrs 3/7/10, Pull BPV, Circ Sea H2O & 400 bbls 10.5 ppg brine, WeN dead, N/D Tree, N/U BOP, Rig to test BOP. 3/7/10 TRAVEL TO ALPINE WITH E-LINE UNIT 4863. STAGE UNIT FOR DOYON 141 AT CD3 FOR POSSIBLE RE-CUT ON CD3-301, 4-1/2" TUBING. 3/8/10 STANDBY FOR TUBING CUT FOR DOYON 141 UNTIL THEY WERE ABLE TO PULL TUBING, CONFIRMING ORIGINAL CUT. RETURN TO KUPARUK. 3/8/10 Finish rig up f/ BOP test, Start first test found Blanking plug in Hanger leaking, Nipple down & raise stack, Remove Blanking plug, Wrap w/ teflon tape & reinstall, Nipple up BOP, Rig & test BOP w/ 4- 1/2" test jt. 250/3500/2500 as per permit (AOGCC Chuck Scheve waived test), Pull BPV, Pull hanger to floor, Monitor well -Static, Rig & POOH w/ 4-1/2" completion. 3/9/10 Finish testing BOPE -RIH & set bridge plu _ 3472' -POOH w/ running tool - MU casing cutter & RIH -tag bridge plug @ 3472' -Test csg to 1500 psi -Change over to 9.6 ppg LSND -POOH w/ running tool - MU casing cutter - RIH 8~ tag BP @ 3472' - PU & locate collar @ 3439' - PU to 3419' & cut casing @ 3419' -Circ btms up - Obesrved gas @ btms up - Burnp mud wt. to 9.9 ppg -Circ 9.9 ppg mud in IA -Unable to pump down OA -Flow ck -static -POOH w/ casing cutter 3/10/10 Change top pipe rams to 7" & test - MU spear assembly & engage fish @ 28' -Pull on & work fish - puliling up to 390 k -unable to work 7" casina free -Release & LD spear - MU csg cutter &RIH & cut csg @ 2416' -Circ -POOH w/ csg cutter - MU spear & engage fish -Pull 7" csg hanger to rig~foor LD spear -Install Circ swedge &Circ -POOH & LD 7" csg 55 jts & cut -fff jt (total length 2386.83') - MU spear -wait on DC's -slip & cut drill line 3/11/10 MU spear &RIH engage fish @ 2416' -Jarred on fish -unable to jar free -POOH w/ spear - MU casing cutter -RIH & cut csg @ 3184' & 2839' -POOH w/ csg cutter -Change pipe handling equipment to 5" -Change top rams f/ 7" to 3 1/2" x 6' VBR & test - MU spear -RIH & engage fish @ 2416' -jarred 3 X & fish came free -Circ btms up 3/12/10 POOH w/Spear & fish - LD 18 jts. 7" csg(768' - MU spear &RIH -engage fish @ 3184' - Jar on fish unable to jar free -Release spear & POOH - MU csg cutter &RIH cut 7" csg @ 3303' -POOH w/ cutter - MU spear 7 RIH engage fish @ 3184' -Jar fish free -Circ btms up -POOH to 2928' 3/13/10 POOH -Break out spear & LD last of 7" csg (121') - MU bit & reamer -Make clean out run to top of 7" stub @ 3303' -Circ -POOH w/ clean out assembly - MU cmt stinger - RIH on 5" DP to 3303' - unable to get into 7" csg stub w/ 3 1/2" tbg -Set KO plug f/ 3303' to 3083' (talc top) w/ 22 bbls class G @ 17.0 ppg - PU to 2809' -Circ 3 X btms up -POOH & LD cmt stinger ,~ ^~~ WNS CD3-301 ~"° ~Ofi1C1C0~}'ll~~lp$ ell Attributes ax An 1e.3 MD TD tTli3£i)v'3 I~^; Welitrorc APW WI Field Name Well Status ' Inel (') MD (ttNB) Act Btm (IBCB) / ...r., 501032054300 FIORD KUPARUK PROD 94.54 14,124.28 15,140.0 _ ..............:.........................._..._...._................._. Comment H25 (ppm) Date Annotatlon End Data KBGrd (R) Rig RNease Date ••• SSSV: WRDP Last WO: 4279 4!29/2007 Wtll Con : -cD3-307 t?/fi120091:34:47 PM- -- gchsrpatp_ Annotation Depth (IR(B) Entl Dah Annotation Last Mo d _. End Date Last Tag: Rev Reason:OCTALLIES Imosbor .12/6/2009 t Ca$ie:$ti7n $ HANGER. 31 Caalrg Deuriptlon String O._ String ID._' Top (ttlCB) ' Set Depth (f._ Set Depth (ND)._ SMng WL_ SMng ... Stnm3 Top Th1d - ~ CONDUCTOR 36" 16 15250 36.7 114.0 114.0 65.00 H-00 - Insulated Casing DeuNption SMng 0... SMng ID ... Top (ftlt8) Set Depth (L_ Set Depth (TVD) ._ String WL_ String _. SMng Top Thrd SURFACE 9 5l8 8.835 36.5 3,232.7 2,493.9 40.00 L-80 Caeing DeuHptlon String 0... SMng ID ... Top (1tK8) Set Depth (L_ Set Depth (ND) ... SMng wt._ String ... SMng Top Thrd INTERMEDIATE 7 6.276 34.2 12,061.8 6,854.6 26.00 L-80 Buttress Thread ' = ~ J Casing Deudption SMng 0... String ID ... Top (RKB) Set Depth (L_ Set Depth (TVD) ... SMrtg WL_ SMng ... String Top Thrd coeoucTOR ~ LINER 41/2 3.958 11,882.6 15,120.7 6,775.5 12.60 L-80 SLHT - 3~~i;ed' - - r ~D etails - - Line _ - _ _- .. _ . _ - ToP Depth ITVDI Top Intl Noml... Top (1B(B) (RKB) (•) Rem Oescriptlon Comment ID (inl 11,8826 6,823.6 78.71 SBE Seal Bore Extension 5.000 11,898.9 6,827.0 79.07 PACKER Baker "HRD" ZXP Liner Top Packerw/ HD 4.970 11,908.4 6,828.8 79.28 HANGER . Baker "DG" S' x 7" Flex Lock Hanger 5.92 OD x 4. 4.400 NIPPLE, 2,306 waDP, z3oe ~ Tubin--~-:Stein s -' - ;- Tubing DesCdpgon String 0... String ID ... Top (ttKB) Set Depth (t._ Set Depth (TV D) ... ~, 5tnng Wt._ String ... (String Top ThM ~ TUBING 41/2 3.958 31.2 11,882.6 6,823.6 I 12.60 L-80 IBTM Com le tion°Details _ Top Depth (TVD) Top Intl Nomi_. T tR(B) (RKB) (•) Mem DeaMption Comment ID (In) 31.2 31.2 -0.02 HANGER FMC TUBING HANGER 4.500 SURFACE. 2,305.7 2,005.8 58.17 NIPPLE 4.5" BAL-0 Nipple w/ (Dummy P/O 25" ID) 6.062" OD 3.812 cAS uFr, 11,880.4 6,8232 78.66 WLEG WLEG w! seals -14.37 w/ 1219' Inslde seal bore - E X rtrvus 7-L Irv I u 3 a,szs SLOTTED LINER ' Otherl n Hole relin e retrievable` lu s valves um` fish etc, Top Depth (TVD) Top Inc! Top (i1K8) (RKB) (•) Desedpdon Comment Run Dale ID GAS uFT, 263 9 2,306 2,006.0 58.17 WRDP WRDP OAL 105°(HRS-244) 3/272008- 2.1 , 13,700 6,820.6 90.17 PLUG BAKER COMPOSITE BRIDGE PLUG 324/2008 0.L I Perforations dr SlOts Shot - lap (i1/D) Btm (TVD) Dens GAS LIF7 To RKB Btm (RKB) (RKB) (RKB) Zone Date (sh-• T Comment , 10,732 12,081 14,073 6,853.0 6,821.4 4/252007 32.0 SLOTS Altemahng slotted/solid pipe, slots 1/4" x 1/8" 14,196 14,276 6,811.8 6,809.6 4252007 32.0 SLOTS Altema6ng slottedlsolid pipe, slots 1/4" x 1/8" NIPPLE, 10,828 14,395 14,756 6,808.3 6,790.5 4252007 32.0 SLOTS Altemagng slotted/solid pipe, slots: _ 1/4" x 1/8" 14,836 14,876 6,788.6 6,788.2 4252007 32.0 SLOTS Altemadng slottedlsolid pipe, slots: 1/4" x 1/8" LOCATOR , 11,e7s 15,077 15,119 6,778.7 6,775.6 4252007 32.0 SLOTS Altemadng slottedlsolid pipe, slots: WLEG. 11.860 - ~ _ 1l4" X 1/8" i:; Notes: Generdf S Safety =I I- SLOTS, _ _ 12,061-14,073 _ _ PLUG, 13,700 _I I = SLOTS, _ _ 14,19&14,276 - - SLOTS, = I I 14,39574,756 = __ I I _ 1 1 _ SLOTS, - 1 1 14,838-14,676 -_ _ SLOTS I I_ 15,077-15,119 - r 1 = r - LINER, I 11,88115,121 I TD (CD1301), 15,140 Mandrel Details Top Depth Top Port (TVD) Inel OD Valve Lateh Site TRO Run Stn 70o IRKB1 (RKB) (•) Make Model Iinl Serv Type Type Qn) (ps0 Run Date Com._ WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: CD3-301 Run Date: 1/17/2010 January 25, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD3-301 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20543-00 P r~l~ " ~ ~ ~ ~ ~~ ~'.1J~ . ~„~; ~," PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating ~OZ - O a-.~ Attn: Rafael Barreto ~~~ 6900 Arctic Blvd. Anchorage, Alaska 99518 ~ 9 ~ ~° 9 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto~hallibtrtan.com ._ , , ,:,: , / Date: Signed: L tlFB i I\ La / SEAN PARNELL, GOVERNOR ALASKA OIL AND GALS 333 W' 7th AVENUE, SUITE 100 ATIO COMUSSION ANCH RAGE, ALASKA 99501-3539 CONSF iN PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Daniel Herrmann Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-301 Sundry Number: 309-388 Dear Mr. Herrm Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this _L_ day of December, 2009 Encl. o� ,owl \ f I STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 1 7 2009 v APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 .Alaska Gli & Gas Cons. Cntrmtissio n 1. Type of Request: Abandon Q Suspend ❑ Operational Shutdown ❑ j J� 01 Perforate ❑ Re -emdWARed Well ❑ Alter casing ❑ Repair well ❑ Plug Perforations <r Stimulate ❑ Other ❑ Specify: Change approved program ❑ Pull Tubing ❑ Perforate New Pool ❑ Time Extension ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development E] ' Exploratory ❑ 207 - 023 ' 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20543 - 00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes ❑ NO Ej CD3 -301 9. Property Designation (Lease Number): 10. Field/ Pool(s): ADL 372105,'364472, 364471 Colville River Field / Fiord Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15140' 6774' 15140' 6774' 13700' Casing Length Size MD TVD Burst Collapse CONDUCTOR 65# 16" 114' 114' SURFACE 40# 9.625" 3233' 2493' INTERMEDIATE 26# 7" 12062' 6849' SLOTTED LINER 12.6# 4.5" 15121' 6775' 1 - r - I Perforation Depth MD (12081 14073', 14196 Perforation Depth TVD (ft): 6847'- 6818', 6813'- Tubing Size: Tubing Grade: Tubing MD (ft): 14276', 14395' 14755', 14835' 6811', 6808' - 6791', 6788'- 6788', 6779' -6776 4.5" L - 11883' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) Baker'HRD' ZXP liner top packer @ 11899' MD/ 6827' TVD SSSV @ 2306' MD / 2005' TVD 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: 7p.4 Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑., • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: January 1, 2010 Oil ❑ Gas ❑ WDSPL ❑ Plugged L ] 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned❑ Commission Representative: I GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Daniel Herrmann @ 263 -4619 Printed Name i errman p / J Title: Wells Engineer // Signature / / &/ Phone 263 -4619 Date Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity V/ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: / 2j) APPROVED BY Ap roved by' COMMISSIONER THE COMMISSION Date: ` r 3 T� W R 09 i Submit in Duplic Well CD3 -301 Proposed Plug and Abandonment for Sidetrack Well CD3 -301 is a Fiord Kuparuk C sand producer that was completed April 2007 with an uncemented 4.5" slotted liner. The well is currently shut -in due to high water rate (-5700 BWPD' >95% WC). A Baker composite bridge plug lu was set in the liner of CD3 -301 at 13700' RKB above the p fault on 3/24/08 to try and isolate the fault, but the plug was unsuccessful in reducing the high water production. CD3 -301 is now scheduled for rig sidetrack in order to move the well location away from a large fault. A cement pug will a pumped on top of the composite bridge plug at to fill the liner, and the liner x OH annulus above the plug. The lower section of the IA just above the ZXP Liner Top Packer at 10804' RKB will also be filled with cement through an open GLM pocket at 10732' RKB. erwcor, E cr F,'orcl wells 1-0-p Proposed Plug & Abandonment Procedure: j «�c ?, 5��� A- V e t O ,cy (e c0 vary it y tn�i f lPq�v�Pc� /1Qa/�'l / Slick Line j i lf well for R vI r,*o"r / ,re CO vCryt lo /9lof 1. RIH and pull the DV from the gas lift mandrel at 10732' RKB. IH with drift assembly to check for restrictions and tag as deep as possible. Coil Tubing: 2. RIH with coiled tubing to 13700' RKB (top of composite plug). PU CT and begin laying in 100 bbls of Class G cement from CBP (or PBTD) while POOH with nozzle. Lay in all 100 bbls of cement to fill the liner and tubing to 7130' RKB (max attainable cement top). With the IA open to take returns, squeeze 2 bbls of cement to fill 116' of the lower IA through the open mandrel pocket at 10732' RKB. After 2 bbls of cement has been squeezed to the IA, shut -in the CT x tubing annulus and tubing x casing annulus, and squeeze away 55 bbls of cement through the 0.125" wide slots in the liner to fill the liner x open hole and the trunk of the fault. WOC for 24 hours before PT. Slickline 3. RIH & tag TOC. Pressure test cement plug to 2000 psi. If cement plug does not pass pressure test, plan to resqueeze until a good pressure test is achieved. Drift the well with a drift assembly in preparation for E -line tubing cut. E -line 4. RIH with erforator and erf the tubing at 4245 RKB in preparation for making p P 9 p p 9 a tubing cut. After the perforations are shot, RIH with a rotary torch cutter and cut the tubing at 4235' RKB (1000' below the surface casing). 0 ConacoPhllips Alaska, Inc" ALPINE CD3 -301 - C 03-301 TUBING (32 11895, API: 5 Well Type PROD _ An le TS: d - 00:4.500, SSSV Type: WRDP Orig Completion: 4/29 /2007 Angle @ TD: 94 deg @ 15140 10:3.958) Annular Fluid: Last W /O: Rev Reason: Set PLUG, RESET WRDP Reference Lo : 36' RKB Ref Log Date: Last Update: 3/29/2008 Last T TD: 15140 ftKB °RODUCTION Last Tag Date: Max Hole Angle: 95 deg @ 14124 (34- 12062. Casing String - ALL STRINGS 00:7.000, Description Size Tog_— Bottom TVD Wt Grade Thread wL2s.00) CONDUCTOR 16.000 0 114 114 65.20 H -40 WELD PR 7.000 34 12062 6848 26.00 L -80 MBTC SURFACE 9.625 3 7 3233 2494 40.00 L -80 MBTC Gas Lift - LINER SLOTTED 4.500 11883 15122 6775 12.60 L -80 SLHT MandrelNaloe - - z Tubing String - TUBING (9263 - 9260, Size Top Bottom TVD Wt Grade Thread _ - 4.500 32 11895 6826 12.60 L -80 IBTM Perforation s_ Summary Interval . Zone Status Ft SPF Date -. T �_. _ � .. _ Co 12081 - 14073 6848- 6819 1992 32 4/25/2007 SLOTS Alternating slotted /solid pipe, slots 2 1/4 x 1/ 8" 14196 - 14276 6812-6811 80 32 4/25/2007 SLOTS Altemating slotted /solid pipe, slots 2 1/4" x 1/8" NIP 14395 - 14756 6808 - 6791 361 32 4/25/2007 SLOTS Altemating slotted/solid pipe, ' a 829, 14836 - 14876 -- -_ slots 21/4" x 1/8" 6789 - 6788 40 32 4/25/2007 SLOTS Alternating slotted/solid pipe, slots 2 1/4" x 1/8" 15077 - 15119 6779 - 6776 42 32 4/25/2007 SLOTS Alternating slotted /solid pipe, LOCATOR - - - - -- slots 2 1/4" x 1/8" ;1 187 9 -11880, OD:5.750) St - -.. -. Gas Lift D M TVD eI M Man Man Type V Mfr V Type V OD ! Latch Port TRO Date Run Vlv Cmnt 2 926 3379 CAMCO KBG -2 GLV 1.0 BK -5 0.250 2201 4130/2007 (plugs, CAMCO KBG -2 GLV 1.0 BK -5 1 -- 6. --- 2 In 4/30/2007 _ (11899 11900 3 10732, 6463, CAMCO KBG -2 OV 1.0 BEK 0.438 _ 0 4/30/2007 00:6.540) Other lugs, equip__etc.) - COMPLETION Depth TVD Type Description - _ ID 31 31 HANGER ., FMC TUBING HANGER 4.500 2306 2005 SSSV BAL -O NIPPLE 3.81 I 2306 2005 WRDP WRDP OAL 105 "(HRS -244) set 3/27/2008 2.125 10828 6508 NIP HES XN NIPPLE 3.725 11879 6823_ LOCATOR BAKER LOCATOR 11880 6823 WLEG/ WLEG w /SEALS ASSEMBLY "EXTENDS 12' INTO SLOTTED LINER" 3.940 SEAL _ 13700 6820 PLUG BAKER COMPOSITE BRIDGE PLUG set 3/242008 0.000 I — - - Other (plugs, equip., etc.) - LINER DETAIL Depth TVD_ T" Description - -__- ID -- 11899 6827 PACKER LINER BAKER'HRD' ZXP LINER TOP PACKER __ 4.970 Perf 11908 682 HANGER LINER BAKER'DG' FLEX LOCK HANGER _ 4.400 ;12081- 14073) 15119 6776 _ SHOE LINER BAKER SHOE _3.958 I I it I I � I I � �I Perf ;15077- 15119) Pagel of 2 Schwartz, Guy L (DOA) From: Anderson, Nina M [ Nina .Anderson @conocophillips.com] Sent: Tuesday, November 24, 2009 5:20 PM To: Schwartz, Guy L (DOA); Winfree, Michael Alex (Jr.) Cc: Herrmann, Daniel D Subject: RE: CD3 -301 and QW-W ' P7 2a7^ o z 3 Guy - Below I have briefly summarized the rig plan for the 301 and 302 sidetracks. Sundry's to abandon the old wellbore and change to approved program along with new PTD's will be submitted during December. Please let Mike or me know if you have any further questions. Thanks, Doyon 141 moves onto CD3 -302 " 2. Pu Tbg from the ELine cut at +/- 3690' MD (Approximated -low Surface Casing which is at 2685' MD) _ 3. Set Bridge Plug on I DP in 7" t +/- 3 4. Cut 7" casing with Mechanical Cutter at +_ D 5. Pull 7" casing 6. Lay in Cement plug - o - Bridge plug and kick off plug. Squeez ent to provide isolation. 7. Open Hole si f 100' below surface casing at 2779' MD with 8 -3/4" Drillin mbly 8. Drill t +/- 12,936' MD. 9 plete as a Kuparuk Slant Insect Doyon 141 moves onto C -301 2. Pull 4 -1/2" Tbg from the ELine cut at +/- 4235' MD (Approximately 1000' below Surface Casing which is at 3233' MD) 3. Set Bridge Plug on 4" DP in 7" Casing at +/- 3633' MD 4. Cut 7" casing with Mechanical Cutter at +/- 3533' MD 5. Pull 7" casing 6. Lay in Cement plug on top of Bridge plug and kick off plug. Squeeze cement to provide isolation. 7. Open Hole sidetrack 100' below surface casing at 3333' MD with 8 -3/4" Drilling Assembly. 8. Drill Pilot hole to TD - Verify Kuparuk sand quality 9. Plug back Pilot hole and KO to land 8 -3/4" hole at +/- 10,453' MD 10. Run and Cement 7" Casing 11. Dri ll 6 -3/4" hole to TD at +/- 12,481' MD 12. Complete as a Kuparuk Horizontal Producer. Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907) - 265 -6403 Cell: (907) 575 -3256 From: Schwartz, Guy L (DOA) [ma !Ito: guy.schwa rtz@alaska.gov] Sent: Monday, November 23, 2009 11:55 AM To: Winfree, Michael Alex (Jr.) 12/1/2009 Page 2 of 2 Cc: Anderson, Nina M Subject: CD3 -301 and CD3 -302 Mike, Can you fill me in on the base plan on how you are going to sidetrack 301 and 302. 1 received Sundries (403's) for these to P & A but nothing on what the rig is planning to do. Whipstock etc. Give me call. Guy Schwartz Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 12/1/2009 ~ ~ M I~ DATA SUBMITTAL COMPLIANCE REPORT 5/7/2009 Permit to Drill 2070230 Well Name/No. COLVILLE RIV FIORD CD3-301 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20543-00-00 MD 15140 TVD 6774 Completion Date 4/29/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION ~~- Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: GR / RES Well Log Information: Log/ Electr Data Digital Dataset T Med/Frmt Number Name D Asc Directional Survey q%E/9 C Lis 15241 Induction/Resistivity u R t 15241 LIS Verification p ~D C Lis 15615~duction/Resistivity Log Log Run Scale Media No 'L I ti i ti it d /R ? og n v y uc on es s ~D C Lis 15615YInduction/Resistivit y ~og Induction/Resistivity i ,/Log Production +~og Caliper log j,!,L~og Induction/Resistivity (/L ti I d /R i ti it og n uc on es s v y ~D C 17787 See Notes __ _ ___ 2 Blu 2 Blu 5 Blu 1 5 Col 5 Col 5 Col (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments 50 12076 Open 6/12/2007 3206 12076 Open 6/25/2007 LIS Veri, GR, FET, ROP w/Graphics txt and PDF ~' 3206 12076 Open 6/25/2007 LIS Veri, GR, FET, ROP 12076 15139 Open 10/26/2007 LIS Veri, GR, ROP, FET, RPS, DRHO, NPHI w/PDS graphics 12000 15140 Open 10/26/2007 MD Vision Service 25-Apr- 2007 12076 14294 Open 10/26!2007 P61 LIS Veri, GR, ROP, FET, RPS, DRHO, NPHI w/PDS graphics 12000 14294 Open 10/26/2007 PB1 LIS MD Vision ' Services 22-Apr-2007 10772 13850 Case 2/13/2008 PPL w/Deft 28-Jan-2008 10772 13850 Case 2/13/2008 MFCL, PMIT-A 29-Jan- 2008 114 12076 Case 4/6/2009 MD ROP, DGR, EWR 16- I' Apr-2007 114 6849 Case 4/6/2009 TVD DGR, EWR 16-Apr- ~' 2007 0 0 4/6/2009 EWR Logs in PDS, EMF and CGM graphics • DATA SUBMITTAL COMPLIANCE REPORT 5/712009 Permit to Drill 2070230 Well Name/No. COLVILLE RIV FIORD CD3-301 Operator CONOCOPHILLIPS ALASKA INC MD 15140 TVD 6774 Completion Date 4/29/2007 Completion Status 1-OIL Current Status 1-OIL Well CoreslSamples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? `~N~ Daily History Received? (~~,~,N~ Chips Received? Y / N Formation Tops S'L' rv Analysis Y / N Received? Comments: API No. 50-103-20543-00-00 UIC N __: Compliance Reviewed By: Date: u • • • ConocoPhillips ~~ P,O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri16, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: -~ , _ -. L n~,z4 ~L~';r~a~ i~~:~~~ L ~C ~ Uu~a rr.~u:p C~ r ~~~ ~~~i ~~ N1~;r ~~~~~~ ~~ Enclosed please fmd a spreadsheet with a list of wells from the Coville River Unit (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with"the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped Apri15~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, i /~ G?~~f MJ Loveland ConocoPhillips Well Integrity Projects Supervisor - • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Alpine Field Date 4/6/2009 Well am PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date a a -~ ft bbls ft al CD3-301 9" NA 9" NA 0.85 4/5/2009 CD3-302 206-010 5" NA 5" NA 0.43 4/5/2009 CD3-303 208-013 9" NA 9" NA 1.70 4/5/2009 CD3-305 208-193 8" NA 8" NA 0.85 4/5/2009 CD3-316A 208-011 26" NA 26" NA 8.93 4/5/2009 CD3-107 206-189 34" NA 34" NA 11.05 4/5/2009 CD3-108 205-033 10" NA 10" NA 1.26 4/5/2009 CD3-109 205-059 9" NA 9" NA 2.13 4/5/2009 CD3-110 205-041 4" NA 4" NA 0.43 4/5/2009 CD3-111 206-030 5" NA 5" NA 0.85 4/5/2009 CD3-112 206-032 3" NA 3" NA 0.43 4/5/2009 CD3-113 207-004 14" NA 14" NA 1.28 4/5/2009 CD3-114 207-033 5" NA 5" NA 0.85 4/5/2009 CD3-115 209-006 8" NA 8" NA 1.28 4/5/2009 CD3-117 209-026 6" NA 6" NA 0.43 4/5/2009 CD3-118 208-025 8" NA 8" NA 0.85 4/5/2009 ! ~ WlE1LL LOS T I~SM~TTAL To: State of Alaska March 24, 2009 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7'" Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-301 AK-MW-4925845 CD3-301 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Logs 50-103-20543-00 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Logs 50-103-20543-00 Digital Log Images: 1 CD Rom 50-103-20543-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 OfFce: 907-273-3536 Fax: 907-273-3535 Bryan.Burinda@halliburton.com ~'"Pq°f Date: Signed: ~®~- ~ 3 _ ` ~~~~ 02/09/08 • ~~~~~~~~ NO.4581 Schlumberger-DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken Attn: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Prints CD • CD3-301 11964570 MULTI-FINGER CALIPER ~(~ 01/29108 1 CD3-302 11964573 INJECTION PROFILE !" --(~ ~ 01/30108 1 CD3-301 11964570 PRODUCTION PROFILE '~ - 01/28/08 1 CD3-316 11963078 SCMT ~ 02/09/08 1 ,~. 1 ~f "'n SIGNED: DATE: a., .~ 4 e-~ ~~~1 ~ Jr~i l.. ~ )! ~s~ t. ;.J! i i 1 :t(Cli? Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. • ConocoPhilli $ Casing Detail 9 5/8" Surface Casin_g ~~"Q~ Well: CD3-301 Date: 4/11/2007 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS q ~ Doyon 19 RKB to Landing Ring 36.48 FMC Gen V Hanger 2.19 36.48 Jts 3 to 83 81 Jts 9-5/8" 40# L-80 BTC Csg 3113.03 38.67 HOWCO Float Collar ` 1.19 3151.70 Jts 1 to 2 2 Jts 9-5/8" 40# L-80 BTC Csg 77.59 3152.89 Ray Oil Tools "Silver Bullet" Float Shoe 2.24 3230.48 3232.72 TD 12 1/4" Surface Hole 3242.72 TOTAL BOWSPRING CENTRALIZERS - 47 1 per jt on Jt # 1 - # 13 (stop ring on Jt # 1 8~ 3 ) and over collars on jts# 15, 17, 19, 21, 23, 25, 27, 29, 31, 33, 35, 37, 39, 41, 43, 45, 47, 49, 51, 53, 55, 57, 59, 61, 63 65, 67,69, 71,73,75,77,79,81 90 joints in the pipe shed. Run 83 joints - 7 joints stay out Casin shoe ~ 3232' MD / 2493' TVD Hole TD 3243' MD / 2499' TVD Use Best-o-Life 2000 pipe dope MU torgue ~ 8600 ftllbs Remarks: Up Wt - 180k Dn Wt-145k Block Wt - 75k Supervisor.' D. Burley/L. Hill merit Details -- ;cription Cementing Start Date (Cementing End Date rfaceCement X4/11120071430 ~ 4 1 112007 17:00 rnment Surface Cement Wellbcre Name ~- CD3-301 Cement Stages __- _ - - - --- Stage # <5tage Number?> ~ ~~ ~ - -- - - .. Tn ~ PIu4 ~ BLn Plu ~ Description Objective Top (ftKB) Bottom (ftKB) F~II Retum7 .emit Ktm ( t _ 9 - Surface Cement Cement Surface Casing ~, ; h_7 3 '-,31.7 ~ Yes 121.0 I Yes 1 Yes O (start) (bbl/min) O (end) (bbVmin) ~Q (avg) (bbllmin) 'P (final) (psi) P (bump) (psi) ecip? Stroke (ft)Rotated? (Pipe RPM (rpm) - -- -- $ 4 Ta Method 600.0 Depth PIuO DOrilled O Y6S l) ? DO101 Out Diam No Depth tagged (ftKB) ~ g g eter (in) 1 - - - - -- - - -_ Comment - Cement 9 5/8" csg as follows :Rig Pumped 40 bbls Biozan water w/ nut plug as marker- Pumped 5 bbls v/ater w/ Dowell -.,Tested lines to 3770 psi - Dropped btm plug -,_Pumped 50 bbls MudPush @ 10.5 ppg -Mixed & pumped 356 bblsiead slurry (ASL) @ 10.7 ppg (r Observed nut plug marker @ shakers ~ 325 bbls lead pumped -pumped,down surge can 337 bbls total) Pumped 50 bbls tail slurry (Class G w/ additives) @ 15,8. ppg -Dropped top plug w/ 20 bbls water f/ Dowell -Switched over to rig pumps & displaced cmt w/ 221 bbls 10:0 .ppg water base mud -Displaced @ 8.2 bbls/min for first 200 bbls slowed,to 5.2 bbls/min for last 21 bbls -Bumped plug w/ 1110. psi (pre bump pressure 600 psi) Check float (held OK) CIP @ 16:45 hrs. -Full returns throughout job w/ 121 ~bbls 10.7 ppg cmt retums to surface -reciprocated pipe until) last 36 bbls rid displacement. - - -- - - Cement Fluids 8 Additives Fluid __-. _ Volume Pum ~~d bbl Fluid Type. FluidDeyenption Etirmic~Tnp(ftKBl EstBtm(ftKB) Amount(s~cks) CLiSS F' ( ) Lead Cement 36.7 2,733.0 409 G 337.0 -~ - - - -- - - Yield (fN/sack) Mix H2O Ratio (gallsa... Free Water (%) ~ Density (Ib/gal) I Plastic Viscosity (cp) IThickening Time (hrs) CmprStr 1 (psi) 4.63 _ 21.75 -J 10.70 I 1- - Additives - _ - - T- - - -- AdditiveType Concentration ,Conc Unit label Flmd _- Fluid Type Fluid Description Estimated Top (ttKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) -~~; 50.0 Tail Cement 2.73 ~_Q 2,733.0 ~- ~ _ G - - - - -- - Yield (fP/sack) Mix H2O Ratio (gal/sa... Free Water (%) LDensity (Iblgal) ,Plastic Viscosity (cp) IThickening Time (hrs) CmprStr 1 (psi) 15.80 '1.17 5.10 - - ~ -_-- ~ __ --~- -- -- -- - Additives - - - - - - __ ~ _ ~ d ~t label Type Concentration I one m - L - -- - - - -- L_ _ ~_ - - iJ - - Page 1/1 r Security Level: Development Daily Drilling Report CD3-301 Report Number: 4 tig: DOYON 19 Report Date: 4/11/2007 ' !:=E Type NetworktlD # ~' TotatAFE+SuA. ' 10165661 7,664,625.00 I Wellbore Well T pe Y 'Field Name DFS da s DOL De th ( Y) P Pro ress ft Depth Start (ftKB Depth End (ftKB) i, 9 ( ) ) ~CD3-301 Development 'FIORD KUPARUK 2.90 4.0 0.00 3,243.0 I 3,243 0 (Daily Mud Cost Cumulative Mud Cost Daily Cost Total ',Cumulative Cost 6,769.05 43,633.18 368,524.05 - 1,114,534.18 -- - _ ActualStart Date Origina _ T - - l Spud Date AFE Dur Total (days) --- ;Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 4/8/2007 4/9/2007 22.11 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) .Surface, 3,232.7ftKB I -0ps and Depth @ Morning Report 24hr Forecast I 'Picking up 5" DP. Finish test. Pick up DP. Pick up BHA and RIH. Cut Drilling line. Drill ' shoe track + 20'. FIT. Change mud and drill. Last 24hr Summary - POOH and laid down BHA. Rigged up and ran 9 /58" casing. Circulated a nd cemented casing. Tested casing. Nippled down riser and nippled up BOP. Set test plug and tested BOP. General Remarks __ ',Weather _ -_ Head Count SOW@7mph 50.0 -Supervisor Tile Da Burley, Rig Supervisor Rig Supervisor I Larry Hill, Rig Supervisor Rig Supervisor .Time Log_ _ __ Start nd I ~~r c~~- T ;Depth Stai t,e, tf~ F ~il Time Time hu, F~h_,a~ ,, , odo p_ "-N-l - .oci~ y _ ,~ (ftKB) I rbl Code Trbl Class f~~N~ ~'._ uu~i~t~on I. __ _-__- 00:00 01:45 1.75~ISURFAC DRILL (KIP N I 2,410.0 ~i 67.0 POOH from 24 i 0 to 893 -flow check well, static. -POOH from 893' to 16T ', I (stand back hwdp) 01:45 04:30 2.75 SURFAC I DRILL PULD P I 167.0 0.0 Lay down jars and flex collars -download i ', ~ MWD - LD BHA -clear tools from rig I floor 04:30 06:00' 1.50 SURFAC -- CASING RURD P O.O -- 0.0 Change out bails - Ru fill-up tool and casing running equipment 06:00 -06:30 0.50 SURFAC SFTY p ~ CASING _ I 0.0 O.OI Held Safety and Opts meeting with rig team L06:30,09:15. 2.75 SURFAC ',CASING RNCS ~P 0.0 1,535.0 RIH with 9-5/8" 40# L-80 BTC casing as follows: Float Shoe "Ray oil tools Silver I ' ' Bullet" - 2 jts csg - Halliburton Float Collar - 37 jts csg. First 4 jts made up ', '',with Baker Loc - Bowspring centralizers ' ', '~ ion jts #1-13 & every other jt after. Stop I I I rings on jts #1 8 2. 09:15'09:45 0.50 SURFAC iCASING CIRC P 1,535.0'. 1,535.0 Stage pumps up to 5 bpm / 270 psi - I ! I CBU - PUW 130K SOW 115K ~ I 09:45 12:00 2.25 SURFAC CASING RNCS P - - I 1,535.0 I - - - --- 3,232.0 Run 9-5/8" 40# L-80 BTC casing ' Ifrom1535' to 3194' - MU FMC fluted '~ 'casing hanger and LJ -Land casing with ' Shoe @ 3232', FC @ 3152'. 12:00 12:30 0.50 SURFAC CEMENT RURD P 3,232.0 3,232.0 Lay down fill-up tool -Blow down top ' drive - RU cement head and lines 12:30 14:30 2.00 SURFAC CEMENT CIRC P 3,232.0, 3,232.0 Stage pumps up to 7 bpm circulate and condition mud for cementing - ~ i ~reciprocated pipe with full returns ' i I 'throughout- FCP 310 psi -- _-- 'Latest BOP Test Data - __ _-- Qate __ _. _... Comment _:..-~ Page 1(3 Report Printed: 12/1112007 - - Daily Drilling Report CD3-301 - - -- Security Level: Development Report Number: 4j ;ig : DOYON 19 Report Date: 4/11/2007.. Time Log ~-- - --- - - - - - Btari k nd I i.~ I mu: L ; II Stan C~ pth End Tim ~ ~,.,.. h 5; ,. _„ u~ ~ ,~„ F r9T T; al icdu Trbl Class. rt~-:B) ftK$ ' ;14:30 17:00 2.50 SURFAC 'Cement 9 5/8" csg as full ~ws :Rig CEMENT DISP P i 3,232.0 3,232.0' t Pumped 40 bbls Biozan water w/ nut plug as marker -Pumped 5 bbls water w/ Dowell -Tested lines to 3770 psi - I ; Dropped btm plug - Pumped 50 bbls !i ~ Mud Push @ 10.5 ppg -Mixed & pumped '~ ', i ~ 356 bbls lead slurry (ASL) @ 10.7 ppg (' I ~~ Observed nut plug marker @ shakers w! I ', 325 bbls lead pumped -pumped down j ', surge can 337 bbls total) Pumped 50 Ibbls tail slurry (Class G w/ additives) @ I 'I 1,15.8 ppg -Dropped top plug w/ 20 bbls ', water f/ Dowell -Switched over to rig '~ ~ pumps & displaced cmt w/ 221 bbls 10.0 ppg water base mud -Displaced @ 8.2 i ~ bbls/min for first 200 bbls -slowed to 5.2 ', I bbls/min for last 21 bbls -Bumped plug '~ I ~, w/ 1110 psi (pre bump pressure 600 psi ) ~ Check flo2t (held OK) CIP @ 16:45 hrs. - Full returns throughout job w/ 121 bbls 10.7 ppg cmt returns to surface - I ~„_~ ~- ! reciprocated pipe until) last 36 bbls od I , dis lacement. p 17:00 17:45 0.75 SURFAC - - - ~ ! _ CASING DHEQ P i I 3,232.0 - - - ~, 0.0 Pressure test casing to 3500 psi for 30 1 min. -Bleed and blow down lines 17:45 18:45 1.00 _ - 0.0 - -- -- 0.0 Rig down casing and cement tools. ~ a -- 18:45 19:45; 1.00 SURFAC _ CASING NUND P ' 0.0 _- _- - __ - O.O,Nippled down riser. 225 SURFAC 45 22:00 'i CASING NUND 'P 0.0 0.0'Installed speed head and nippled up ti BOP. -22:00 22:30 0.50 SURFAC DRILL RURD P 0.0 i 0.0 Picked up and Rigged up Geo Span. - -- 22:30 00:00 1.50 SURFAC - -- - - I - - - --- WELCTL 'BOPE P 0.0' - -p g -- 0.0 Set test lu and tested BOPE 250/5000 1 psi. LMud Check Data - - ~~ ~- ype ~ Den<r T Deplh (ftKB) _ `r P ~zl ~ u•1 i ~ •., ~ i i t ~n) el (30m) - lt r~al~ ~; .i< It)-PV.CaIC(cp) Qbg100tt=) ~ ({bf1100ffi) ~ (Ibfl100ff) (Ibtll00ft') MBT(Ib/bbl) ~ t ~,nsi Rnrp > li .Corr HTHP Filt- I _°(m1-~30min) i pH r F; i '. SPUD 3,233.0 f' ~1U t~4 18.0 19.000 15.0 47.0 55.000 ' G~.S :;.5i -_ Injection Fluid _ _ ', - ---- Flue , ~;wrce _ Fr .m L~asr ht I, ,. Destina tion Note Diesel 10.0 CD3-111 From CD3-301 i Water 10.0 CD3-111 From CD3-301 Water Based Mud 1138.0 CD3-111 From CD3-301 ,_ .Drill Strings BHA No. 1 - Steerable ! Bit Run No. 1 - 12 1/4in, Hughes Christensen MX-1 , 5117404 Depth In (ftKB) Depth Out (ftKB) 'TFA (incl Noz) (ins) Nozzles (l32") IADC Bit D ull String Wt (10001bfj 114.0 3,243.0 0.75 18/18/12/16/16 3-6-WT-A-E-1-NO-TD 44 Drill String Components Jts _ Item Oescrip5on -.OD (+n} ID {in) Top Conn Sz (n) Top Thread Cum Len {ft) , _ ' . _ it Motor with St~3bilizer - - - _ _._-- _. -- _-- 8 -- -4.947 . 31.981 - 6 5/8 H 90 ----- Float Sub 8.08 2.813 6 5/8 H 90 34.56 .Stabilizer 8.1 ; 2.8131 6 5/8 H 90 41.47 MWD ~ 8' 1.920 6 5/8 Reg 67.10 UBHO ~ 8 3.250 6 5/8 H 90 70.47 NMDC 8 2.875 6 5/8 H 90 101.39 I NMDC 7 7/8 2.813 6 5/8' H 90 132.35! ~, Drilling Jars -Mecha nical 7 3/4 2.750 4 1/2 IF 166.91' 24 HWDP _-- - 5, ---- - - 3.000', 4 1/2 1F 891.39 Page 213 Report Printed: 12/11/2007 - --_ - Security Level: Development Daily Drilling Report CD3-301 ', Report Number: 4 tig: DOYON 19 Report Date: 4/11/2007 Drilling Parameters -~ow Rate ~~ --_ _' .:Start (ftKB) ~. End (ftKB) .Cum Depth (ft) ~~ Cum Ddll Time /his; ~Ld(ny i {3Pm) 12PPA ~ lure (hrsj~ (9PR+) , -~~ i,lhf ~F>m) f ~ I ?t Crill _ r h [ SPF, (xt ~ (10001bf) ~ (10001hf) i ~ ~I-''N'. XJlbf) ~ GPI B~.n I ~ ~ Drill Tq ' 3 243.0' 3,243.0 3,129.00' " 'O 625 3Q0 50'~ 2,1'?0.0 137, 132 125' 7.5(10.0 8,000.0 Weilbores _ Wellbore Name _ Wellbore APIIUWI CD3-301 501032054300 -__ Section ~ Size (in) Act Top {ItKB) Ad Btm (ftKR Start Da#e End Date ' COND1 3b 0.0 114.04/2/2007 4/3/2007 SURFAC 12 1/4 114.0 3,242.0 4/9/2007 4/10/2007 INTRM1 8 3/4 3,242.0 12,076.0 4/13/2007 4/16/2007 PROD1 6 1/8 13,880.0 15,140.0 4/23/2007 _ s 2 ;,'007 -_ _ ICasingStrings______. _ _. _ - _ ' Casing Descn p4on Fir Gate .d ) ~ OD (i i ' -. (Ibs/ft Grade Set Depth (ftKB} Coi n~,r~ ,, --- Surface ~,4i1 V2007 _ ~ ~ 9 5.a 40 00 L-80 ,,,_ _ 3,2327 Page 313 Report Printed: 12/11/200711 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3-301 Rig: Doyon 19 Date: 4/12/2007 Volume Input Volume/Stroke Pump Rate: Drilling Supervisor: D. Burley / L. Hill Pump used: #2 Mud Pump ~ Strokes ~ 0.1000 Bbls/Strk ~ 8.0 Strk/min ~ Type of Test: Casing Shoe Test LOT/Frr ~ Pumping down annulus and DP. ~ Casing Test Pressure Integrity Test Hole Size: $-3/4" ~ Casing Shoe Depth Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF: 34.2 Ft 3,232 Ft-MD 2.494 Ft-TV __3,263 Ft-MD _ _ _2.510 Ft-TVD Strks psi Min psi Strks psi Min psi Casing Size and Description: 9-5/a" 4o#/Ft L-so BTC ~ 0 0 0 3600 0 0 0 800 Casing Test Pressure IntegrityTes l 2 150 1 3590 1 50 0.25 700 Mud Weight: 10.U ppg Mud Weight: 9.8 ppg 4 360 2 3590 2 85 0.5 650 Mud 10 min Gel: 47.0 Lb/100 Ft2 Mud 10 min Gel: 22.0 Lb/100 Ft2 6 540 3 3590 3 125 1 625 Test Pressure : 3,500 psi Rotating Weight: 130,000 Lbs 8 850 4 3580 4 200 1.5 Rotating Weight: 75,000 Lbs Blocks/Top Drive Weight: 75,000 Lbs 10 990 5 3580 5 300 2 6 Blocks/Top Drive Weight: 75,000 Lbs Desired PIT EMW: 1 ~~ 0 ppg 12 1140 6 3580 6 400 2.5 610 Estimates for Test: 3.2 bbls Estimates for Test: 1063 psi 0.9 bbls 14 1300 7 3570 7 500 3 610 ~ ~ 16 1470 8 3570 8 600 3.5 610 EMW =Leak-off Pressure + Mud Weight = 833 + 9 8 PIT 15 Second 18 1650 9 3570 9 700 4 610 0.052 x TVD 0.052 x 2494 Shut-in Pressure, psi 20 1840 10 3570 10 800 4.5 610 EMW at 3232 Ft-MD (2494 Ft-TVD) = 1 ~ - ____ 700__ 22 2030 15 3560 11 850 5 610 aooo -- :~~ Lost 6o psi during test, held ~ 24 2230 20 3550 12 875 5.5 610 --- - - -- - -- ` 98.3% of test pressure. ~ 26 2440 25 3540 13 900 6 610 3soo -- '`~`~''" - 28 2640 30 3540 14 925 6 5 608 _ - - . - ~ 30 2850 15 925 7 608 3000 ~ 32 3070 16 930 7 5 608 . ~ 34 3270 8 608 _ ____ _ w zsoo =-- 36 3470 8.5 608 ~ 37 3600 9 608 N zooo 9.5 608 10 60 w a ssoo ~ooo - soo 0 o , 2 3 a o s ,o ,s 20 2s 3o Barrels Shut-In time, Minutes (CASING TEST (LEAK-OFF TEST O PIT Point Vol PUm ume ed Vol Bled ume Back Vol PU ume m ed Vol Bled ume Back s s s s Comments: Tested casing after bumping plugs on cement jol ConocoPhilli s p Casing Detail 7" Casing i Well: CD3-301 Date: 4/17/2007 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Lower lock down 34.20 FMC A-75 Fluted Hanger 1.22' pup 2.33 34.20 Jts 3 to 284 282 Jts 7" 26# L-80 BTCM Csg 11940.20 36.53 Halliburton Float Collar .99 11976.73 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 82.04 11977.72 Ray Oil Tools "Silver Bullet" Float Shoe 2.08 12059.76 12061.84 TD 8 3/4" Hole 12076.00 8-3/4" Hole TD @ 12,076' MD / 6,849.97' TVD 7" Shoe @ 12,061.84' MD / 6,848.81' TVD Total Centralizers: 52 Straight blade centralizer one perjt on jts # 1-15 Straight blade centralizer one per jt jts. 211, 212, 213 Straight blade centralizer one per jt on every other joint from #'s 215 thru 281 Top Kuparuk - 11999.72' MD 6842.95' TVD 290 joints in shed - total 284 jts. to run Last 6 jts. out Jts. 180-224 (1914.33' used casing) Use Run & Seal pipe dope MU torque - 7800 ft/Ibs Remarks: Up Wt - 380 k Dn Wt-165k Block Wt - 75k Supervisor. L. Hill/N. Woods Cement Detail Report CD3-301 Intermidate 7" Cementing SYarl Dale Cementing End Date Wellbore Name 4/17/2007 10-50 4/17/2007 1 x_30 ~ CD3-301 - - - - -- ~'. rCement Stakes __ _ - _ , 9 9 _ ?' DesenptioSta a Number Objective Top ((tKH) .Bottom (ftKB) RiIlReturn? Cmnt Rfrn (__ Top Pluy? Btm Plug? ' i Intermidate 7" Cement r' casing 34.2 i ' 061.8 ,Yes 0.0 Y~5 Yes - - -- ~ - - ~ Stro ~ Rotated? .Pipe RPM (rpm) Q (start) (bbUmin) Q (end) (bbUmin) Q (avg) (bbl min) ~P (final) (psi) P (bump) (psi) ~ ~tp. ) - ~ -- De th to Bed ftKB 4 Ta Method 400_0 - -Depth Plug Drilled ut To(~B) ? Dr0~i101 Out Diam No P 99 ( ) 9 eter (in) ~~ __ _ -- - -- - ~ -- - _ - - Comment Cemented 7" csg as follows: Pumped 5 bbls CW-100 -Test lines to 3700 psi -Pumped 15 bbls CW-100 @ 3bbls/min @ 180 psi -Mixed & pumped 40 bbls 10.5 ppg MudPush @ 5 bbls/min @..260 psi -Dropped btm plug -Mixed 8~ pumped 30.23 Mils 15.8. ppg Tail slurry (class G w/ additives) @ 5 bbls/min @ 300 psi -Dropped top plug w/ 20 bbls water f/Dowel) -switched to rig pumps & displaced cmt w/ 438.7 bbls 9.9 ppg LSND mud @ 7:5 bbls./min @ 700 psi for first 420 bbls slowed pumps to 4 bbls/min @ 430 psi for last 18.7 bbls -Bumped plug w/ 930 psi - CIP @ 12:30 hrs. Checked floats OK -Full returns throughout job -Reciprocated pipe for first 420 bbls bf di~lacen;ent -.landed pipe when. pumps wera slowed to 4 Mils/min. - - - - - 'Cement Fluids:& Additives - - -- _ - _ 'Fluid _ _ Fluid Type Fluid Description Estimated Top (ftKB) Fsf 86n (ftKB) Amount (sacks) ~ Class Volume Pumped (bbl} Tail Cement 11 too-U 1~.tir,~-0 147 ,~ G 31.0 - ; - T- - - - - - - - - Yield (ft'lsaek) Mix H2O Ratio (gallsa... Free Water (%) Density (Iblgal) ~ Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 7 (psi) 1.17 5.08 ~ - _ L- - -- - - - Additives --- -- - -- - - -_ --- - Additive Type i Concentration Cone Unit label I Page 1!1 _ - -~ - - • _ - Security Level: Development Daily Drilling Report CD3-301 Report Number: 11 '~ tig: DOYON 19 Report Date: 4/18/2007 AFEType_. - __ Netwock/1Dk T_-~-- TotaiAFE+Sup .._1016566.1._ _ _ _ _ _ _ 7.664,625.00 Wellbore Well Type - - -- - - - Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3-301 Development FIORD KUPARUK 9.90 11.0 0.00 12,076.0 12,076.0 ',Daily Mud Cost Cumulative Mud Cost Daily Cost Total .Cumulative Cost 3,374.27 ~ 342,084.26 583,658.27 3,311,823.26 ;Actual Start Date Origina l Spud Date ~AFE Dur Total (days) Projected Job Duration (days) ,Job Days Ahead (days) Projected Job End Date 4/8/2007 ~, 4/9/2007 22.11 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Intermediate, 12,061.8ftKB Ops and Depth @ Morning Report 24hr Forecast Hook up MWD ~ PU BHA PU SLB BHA - RIH to drill 6-1/8" horizontal Last 24hr Summary RIH and land 7" csg at 12,062' M D. Cement 7" Csg & test to 3500 psi. Set PO & test to 5000 psi. Change out 7" rams to VBR & test. LD 135 jts 5" DP. General Remarks Weather Head Count 18, NE @ 25 mph gusts U 44 48.0 I -Supermsor ~ Title lLarry Hill, Rig Supervisor '.Rig Supervisor Nina Woods, Rig Supervisor Rig Supervisor Time Log - _ --- -- End i Dur _ _ _ _ - _-- ~K Start i DeftKB nd '- --- ' Time Time ( ) Phase 1 ' B N T Code O Sub Code P : : Op p ~ Trbi Code Trbl Class. ~ t ) ~ opeca6on ) . -. - 00 00 03:30 3 50'',INTRM1 _ - _. - -- ---- _.. _._ _- ---- - CASING RNCS P ' 7,169.0 10,146.0 Ran 70 Jts 7" 26# L-80 BTCM casing to ', 10,146'. ~I 03:30.05:00 1.50 INTRM1 CASING CIRC P 10,146.0 10,146.0 CBU Staged pumps up to 5 BPM. FCP I . 510 psi. 05:00 07:30 2.50 INTRM1 CASING RNCS P 10,146.0 12,062.0 Ran 84 Jts 7" 26# L-80 BTCM casing to ', 12,025'. Totaf of 284 Jts ran. Made up landing Jt and Landed casing @ 12,062'. '~ ', I FC @ 11,977 and FS @ 12,060' MD. 07:30,08:15 0.75 IN7RM1 CASING RURD P i 12,062.0 12,062.0 Rigged down Franks tool and RU cement ~ I head. 08:15 INTRMI 11:00 2.75 - _ - - -- CEMENT CIRC P 12,062.0'Circulated lowering MW to 9.9 PPG. 12,062.0 I ~ Staged pumps up to 7.5 BPM. Worked pipe 20' stroke. Up wt 320 K Down wt. 165 K. FCP @ 7.5 BPM 700 psi. .11:00 12:30 1.50 INTRMI - _ - CEMENT DISP P 12,062.0 0.0 PJSM on cementing -Cemented 7" csg as follows: Pumped 5 bbls CW-100 - ', i Test lines to 3700 psi -Pumped 15 bbls ~ I CW-100 @ 3bbls/min @ 180 psi -Mixed ' I & pumped 40 bbls 10.5 ppg MudPush I 5 bbls/min @ 260 psi -Dropped btm plug ', I '-Mixed & pumped 30.23 bbls 15.8. ppg I I I ', ',Tail slurry (class G w/ additives) @ 5 ', j I ~ bbls/min @ 300 psi -Dropped top plug I ' I w/ 20 bbls water f/Dowel/ -switched to rig pumps & displaced cmt w/ 438.7 bbls 9.9 ppg LSND mud @ 7.5 bbls./min 700 psi for first 420 bbls slowed pumps to 4 bbls/min @ 430 psi for last 18.7 bbls I -Bumped plug w/ 930 psi - CIP @ 12:30 I ', ', hrs. Checked floats OK -Full returns throughout job -Reciprocated pipe for I ', 'first 420 bbls of displacement -landed ~~ I ',pipe when pumps were slowed too 'i I ! ', 'I jl bbls/min. 12:30 .13:30 1.00 INTRM1 CASING DHEO P 0.0 0.0 Rigged up and tested casing to 3,500 psi for 30 min. I --- Latest BOP Test Data -- --- .Date -~ -- - _ _ Comment..... ,,_ -... --... _....... 4/12/2007 250/3500/5000 4" and 5" i. _ _-_ Page 1!2 Report Printed: 12/11/2007 -- -_ _ __ --- _ -- • Security Level: Development Daily Drilling Report CD3-301 Report Number: 11 tig: DOYON 19 Report Date: 4/18/2007,, __ ~, Lnie 1. ~; Ih Stan Dcp,h B,r. _ _ I. ;u _- _.ic_ _ _ SubGoda _ - --- F M 1 iii _L_ w;: , L;D. !,.s....i (Fl<B) ~ ,P''R) .. c..ra:i~r,---:. ---- ~~-- --- 1 ,CASING RURD P i LD Csg Equip, Bales & Land jt. Pull Csg i (wear ring. FMC set PO and test t/5000 i ~ ', I Psi. I 15:30' 16:30 I, 1.00' INTRM 1 'WELCTL OTHR _ _ P _ _--- _ _ ' : -_ Change top set rams from 7" t/ VBR's. 16:30 17:00 0.50 INTRM1 'RIGMNT SVRG P Service Rig 17:00 19:00 2.00 INTRMI WELCTL OTHR p - _ _ ---- RU to test 4" Dart & TIW Vlv's, 4.5" Top ~ ', set BOP Rams ~ Ram Doors - 250/5000 I psi. 19:00 20:00 1.00 INTRM1 DRILL OTHR 'P ___ _ - - Install Wear bushing, Short Bails, i I Elevators. 120:00 00:00 4.00 INTRM1 __ DRILL OTHR - P - - PJSM - LD 5" DP mouse hole (135jts) Mud Check Data ', 1"F'C.a~ Gol il~;si r,q 1~:lrii Gel i3f nn ... Ii -- IIIP FiI( '.~~Den;it,~7nrnp ~1i :3; Cori. Type Degth'(t~4•.h uens (~bl gai)Vis (s/qq ', h'V Galc (cp) Pofi iGOtFj (IbD iuutrj tlGUiu~ii~j tlbC?0o1 i i MBT Oblbbl) {~n U3,Gi~ini pH ' ~'F) {~)' LSND 12,07~~ U 9 .90' 42 10.0 ~ 19.000 8.0 12.0 ~ 13-(~(1(I 20.0 2.4 9.5 86.0 ' __ _ _ _ _ .Injection Fluid - __ _ -- ' _ -- - _ _ _ __! _ - ' - - __ i Fluid S :rcA~ FromLea re(nbli Des6nateon Note _ '. Diesel 50.0 i CD3-111 FP 'Diesel II i 45.0', LOT t/CD3-301 ', ~ Water 300.0 LOT t/CD3-301 Water ', 150.0 CD3-111 Flush Water Based Mud ' i 1940.0 CD3-111 f/ CD3-301 Water Based Mud ~! 10.0 LOT t/CD3-301 Wellbores -- -- - - Wellbore Name Wellbore API/UWI CD3-301 501032054300 _ Seciton ', _ Size {in) ~ Act Top (ftK8) ~ Ac[ Btm_ (itK_B_' ~ S tert Date End. Dafe -~~-- - COND1 36' 0.0' 1 14.0 4/2/2007 4/3/2007 SURFAC 12 1/4', 114.01 3,242.0 4/9/2007 4/10/2007 INTRM1 ', 8 3/4', 3,242.0' 12,076.0 4/13/2007 4/16/2007 PROD1 ' i 6 1/8'. 13,880.0 15,140.0 4/23/2007 .4/25/2007 Page 2/2 Report Printed: 12/11/2007 ' O f~ N ~ O CO ~ l17 V N ~ O O'~ CO CO ~ V' d' (''> .. - ~ ~ O ~ O ~ 07 v 67 v 6~ v 67 v CO v ~ v CO ~ 00 v CO v c0 v CO v f~ v ti v ~ v ~ v !~ ti* r ~' ~ ~ ` '. Y y N .c a ~ ~ ~~+ F- > > m ~ ~ c •~ A ++ L (/1 ~ O O L f) N O T O O O U7 O 0 O ~ O 0 O ~ O O O tn O O 0 ln 0 O 0 ln 0 O 0 ln 0 0 0 ~ 0 0 0 ~ 0 0 O~ ~ Q ~ ~ ~ 0 0 0 ~ N N M M •~ ~7 to tn (p Ct] f~ f~ 00 o0 0) O) O - m E m G7 ~' ` 7 d O ~ C M " ' 0 0 0 ` ~ 6C) (D ~ N ~ O ~fJ M ~ O CO M O N O y O ~ ~ 'y tf ) V O ~ V N c0 N M ch 1 ch ~ '~ ~ '~ 6~ V ch L!") I ~ C.O V CO I CO CO ~ ~ ~ ~ ~ ~ CO ~ CD ~ •a to ~~ °'• E °' sZ i ~ ' ~ N O ~ ~ ~ N ~ r > ~ V ~ ~ ~ CO ~ f~ ~ ~ ~ ~ O p 3 n- a ~ o cv ri v u-i co ~ ~ ai T > d . 00 Y N ~ y Y d V y m ~~ n ~ m ~ O ~ N M ~ ~ CO t~ 00 0 0 ~ O H O •a ~ m ~ >~ C U . ~ fn Q m ~ ~ E 3 o N v ti ~ > a . > ,~ m m , ' , ~ , y a M W ~ ° ~ ~ ~ o N ~ _ ~ ao _ ~ ~ ~ OI O ~ N d fA v ° y ~ ~ C .~ y o Q•y a ~a ~ - N~ Q ~ = ~ ~ N c ~ d C7i O O M ' ~ •~ ~ ~ ~~ .o W d v ~ ~ p H oe r ~i ~ ', a ~ ~. a r U O rr L ' o C F ~ _ ~ •` ~ a ~ Z J ea ~ O ~ ~ ~ I ' mac O W = d ~° ° ~ ~~ ~ v, ' i . ~y ~ ~ ~ c ro ~ .~ ~ ~~ I o ~ V E E N ~ ~ ~~ LLJ ` 07 _ ( ~ N -a ~ f- w a 07 /~ (/ / Z 07 d d ` a y 7 V r ~ + ~ { ~U o c N~ ~ o ~ ,C LL. U W M o ~ G. ° m ~ x ~~ F Q O ono i ~ O Q 'i ~~ LL LL ~ p d O N . G~ O Y ~ j ~ \ ' W ~ Q ~ C , LL m J Z O •N ~ ~ ~ ~ ~ ~ } Q - o , _ a V ~ ~ N ~ , N _' ~ O ri y m ~ rn ~ ° ~ ~ y co J o w V H O. C C ~. M V ~ (0 t6 ~ ~ L ~ ~ / (J r O c`'> O w ~ _ = 7 fl- ZT ~ O O ~ ~~- ~ ~ M v ~ ~ ~ ~ i v Q ~~ p~ m ~ N ~ ~ U ~ = l N ayi o ~a a~ic moo ~ a~ ~=O + chl, L ~' w ~ °' ~ Q m ~ ~ ~ ~ o es ~ I' ~ ~ t ~ y iy F -- 2 Z N (~ Q N ~ - U ~ ~ x/ N c> oo `s N m ~ ° o W ~ l rn . ~ ~~ ~~~_ ~ ~ T ` LL y O = ~ • ` y ~ L N N Y (a o Q. d (~ ~ L ~ ~ N .~ C ~ N N Y V V ~~ (/~ N W J °° o °o ° ~ dl ~ Z = H y ~ O~y ~ N II N _ ~, w ~ _ ~ ~ 3 anss3ad ~ D 2 W U { ~ J ~ 6 N 3 ~~~~#I~fii~~ N0.4474 Schlumberger-DCS 2525 Gambetl Street, Suite 400 Anchorage, AK 99503-2838 Attn: Beth Well Job ~ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Log Description Date BL Prints CD 10/25/07 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. a r,~ ~ ~..~~~~ 7~ ~ , 7., ~x.... - ~c'~'-~;'- "- • • WELL LOG TRANSMITTAL To: State of Alaska June 20, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-301 AK-MW-4925845 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API#: 50-103-20543-00 (,• .~~"~ ~~-0~3 ~ ~5avi ~' ~lUl~ < . ~ 7007 Oc! & C~as Oohs. t;c~rnr ii,~sicr~ /~rxf~rxacJe r ~ 17-May-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD3-301 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 50.22' MD Window /Kickoff Survey ' MD (if applicable) Projected Survey: 12,076.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 ~ / ,~ ~ ~ . Date /02 J+^^~-'x'07 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) '7 - 0 ~- n U ConocoPhillips May 22, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 =nl~::~~ i~ka , Cis ~OnS. Commission Anchorage Subject: Well Completion Report for CD3-301 (APD 207-023) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine well CD3-301. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, ~. Z.. G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells • G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 9~07-26tt5`-6,1/20 n 1 ~f ~~.i ~~i~=;r ~ ~ Z40~ GCA/skad • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SAY 2 2 2007 WELL COMPLETION OR RECOMPLETION REPOI3i,T0ilA6~~~~~'m€:. 1a. Well Status: pil ^ Gas Plugged Abandoned ^ Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Cla nc or Development Q Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: Apri129, 2007 ~ 12. Permit to Drill Number: 207-023 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: April 9, 2007 13. API Number: 50-103-20543-00 4a. Location of Well (Governmental Section): Surface: 1382' FSL, 680' FEL, Sec. 5, T12N, R5E, UM ' 7. Date TD Reached: April 25, 2007 14. Well Name and Number: CD3-301 Top of Productive Horizon: 184' FNL, 2236' FEL, Sec. 32, T13N, R5E, UM 8. KB (ft above MSL): 50' AMSL ^` Ground (ft MSL): 14' AMSL 15. Field/Pool(s): Colville River Field Total Depth: 1462' FSL, 415' FWL, Sec. 28, T13N, R5E, UM 9. Plug Back Depth (MD + ND): 15140' MD / 6774' ND Fiord Oil Pool 4b. Location of Well (State Base Plane Coordinates): NAD 27 Surface:. x- 388364 " y- 6003874 Zone- 4 10. Total Depth (MD + ND): / 15140' MD / 6774' ND 16. Property Designation: , 372105, 364472, 364471 TPI: x- 389557 y- 6012850 Zone- 4 Total Depth: x- 392226 - 6014457 Zone- 4 11. SSSV Depth (MD + ND): SSSV @ 2306' 17. Land Use Permit: LAS 2112 18. Directional Survey: Yes ^/ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): 1250' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GRlRes 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" 65# H-40 36' 114' 36' 114' 24" 362 sx Class G 9.625" 40# L-80 36' 3233' 36' 2493' 12.25" 409 sx AS Lite, 234 sx Class G 7" 26# L-80 36' 12062' 36' 6849' 8.75" 147 sx Class G 4.5" 12.6# L-80 11883' 15121' 6824' 6775' 6.125" slotted liner 23. Open to production or injection? Yes ~ No ^ If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 11882.6' 11899' 12081'-14073' MD 6847'-6818' TVD 14196'-14276' MD 6813'-6811' TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 14395'-14755' MD 6808'-6791' TVD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 14835'-14875' MD 6788'-6788' 7VD na 15077'-15119' MD 6779'-6776' TVD 26. PRODUCTION TEST Date First Production May 2, 2007 Method of Operation (Flowing, gas lift, etc.) gas lift oil Date of Test 5/21/2007 Hours Tested 12 hours Production for Test Period -> OIL-BBL 4519 GAS-MCF 2053 WATER-BBL 0 CHOKE SIZE 100% GAS-OIL RATIO 583 Flow Tubing press. 341 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 8244 ~ GAS-MCF 4808 WATER-BBL 0 OIL GRAVITY -API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes No ~ Sidewall Cores Acquired? Yes ~ No 0 If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. P t J:f `~i s~~11 ~°} t not applicable ~, ~~ c7 5~-- -,+~ R, n.e....^ .._,,,.,~,, Form 10-407 Revised 2/2007 CONTINUED ON RESt~$¢QE~~~' ~ i ~,. '" ~ ~ z5-r07 28. GEOLOGIC MARKERS (List atl formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ~ Yes ~ No If yes, list intervals and formations tested, Permafrost -Top surface surface briefly summarizing test results. Attach separate sheets fo this form, if Permafrost -Bottom 1254' 1250' l needed, and submit detailed test information per 20 AAC 25.071. Kuparuk D 11780' 6487' Kuparuk C 12000' 6842' CD3-301 P61 TD 14294' 6804' N/A Formation at total depth: Kuparuk C J 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner detail sheet 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Liz Galinuas @ 265-6247 Printed Name Chi Alvord Title: Alpine Drilling Team Leader ,,rr~~ ~~ ~ '~~Zf r'D~ D Si + t L e gnature ,~/rL t~ a K~ Phone ~G,S,. G ~Zp INSTRUCTIONS 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 Halliburton Company Survey Report Company: ConocoPhrllips Alaska Inc. Date: 5/8!2007 Time: 15:09:42 Pagr. 1 I~icl~l: Colville River Unit Co-ordin:atc(NE)Reference: Well: CD3-301, True North , Site Alpine CD3 Vertical(IVD) Rc fcreoee: CCr3vOT' 50.2 ~~cll: CD3-301 Section (VS) Reference: Well (O;OON.O.OOE,55.OOAzi) Wellpath: CD3-301 Survey Calculation Method: Minimum Curvat ure Db: c~racfe __ _ ___ Field: Colville River Unit __ North 51ope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: CD3-301 Slot Name: Alpine CD3 " Well Position: +N/-S -14.54 ft Northing: 6003874.12 ft Latitude: 70 25 10.338 N +E/-W -124.24 ft Easti ng : 388363.67 ft Longitude: 150 54 34.034 W Position Uncertainty: 0.00 ft Wellpath: CD3-301 Drilled From: CD3-301P61 501032054300 Tie-on Depth: 13765.94 ft ~ Current Datum: CD3-301: Height 50.22 ft Above System Datum: Mean Sea Level ~ ~ Magnetic Data: 4/8/2005 Declination: 23.74 deg Field Strength: 57525 nT Mag Dip Angle: 80.71 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction i ft ~- 36.72 ft 0.00 ft 0.00 deg 55.00 Survey Program for DeSnitive Wellpath ~ Date: 5/8/2007 Validated: No Version: 4 Actual From To Survey Toolcode Tool Name ft ft ~ 77.00 716.00 CD3-301 Gyro (77.00-716.00) CB-GYRO-SS Camera based gyro single shot , 793.28 12044.53 CD3-301 Sperry (79 3.28-12044.5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12044.53 13765.94 CD3-301 P61 Schlumberger (12044 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC i 13790.13 15076.14 CD3-301 Schlumberger (13790.13 ~~ MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey ~ IbLD Incl Azim TVl) S~,I~~D V!S E/V1' ~tap~~ MapE Tool ft deg deg ft ft ft - ft ft ft 36.72 0.00 0.00 36.72 -13.50 0.00 0.00 6003874.12 ~ 388363.67 ' TIE LINE 77.00 0.14 338.53 77.00 26.78 0.05 -0.02 6003874.17 388363.65 CB-GYRO-SS I I 170.00 0.29 347.24 170.00 119.78 0.38 -0.11 6003874.50 388363.56 CB-GYRO-SS I 261.00 1.69 359.43 260.98 210.76 1.95 -0.18 6003876.07 388363.52 CB-GYRO-SS ' 353.00 2.93 3.65 352.91 302.69 5.65 -0.04 6003879.77 388363.71 CB-GYRO-SS 443.00 3.49 6.15 442.77 392.55 10.67 0.40 6003884.78 388364.23 CB-GYRO-SS 534.00 4.92 4.66 533.52 483.30 17.31 1.01 6003891.42 388364.94 CB-GYRO-SS ~~ 624.00 6.95 6.29 623.03 572.81 26.57 1.92 6003900.66 388365.99 CB-GYRO-SS 716.00 9.04 13.38 714.13 663.91 39.14 4.21 6003913.19 388368.46 CB-GYRO-SS i 793.28 10.85 18.44 790.25 740.03 51.95 7.91 6003925.94 388372.36 MWD+IFR-AK-CAZ-SC ~ 836.58 12.13 17.13 832.68 782.46 60.16 10.54 6003934.11 388375.11 MWD+IFR-AK-CAZ-SC 932.09 15.59 14.15 925.40 875.18 82.20 16.64 6003956.06 388381.53 MWD+IFR-AK-CAZ-SC 1026.32 20.46 13.43 1014.98 964.76 110.52 23.56 6003984.26 388388.88 MWD+IFR-AK-CAZ-SC 1121.55 24.37 16.04 1103.00 1052.78 145.60 32.86 6004019.20 388398.70 MWD+IFR-AK-CAZ-SC ' I 1216.29 24.97 16.72 1189.09 1138.87 183.54 44.01 6004056.97 388410.42 MWD+IFR-AK-CAZ-SC 1311.56 26.27 16.51 1274.99 1224.77 223.01 55.79 6004096.26 388422.79 MWD+IFR-AK-CAZ-SC 1406.85 30.21 16.53 1358.92 1308.70 266.23 68.61 6004139.27 388436.25 MWD+IFR-AK-CAZ-SC 1501.43 34.13 12.02 1438.98 1388.76 315.02 80.91 6004187.87 388449.28 MWD+IFR-AK-CAZ-SC 1596.95 36.64 9.76 1516.85 1466.63 369.33 91.33 6004242.01 388460.50 MWD+IFR-AK-CAZ-SC 1691.99 40.23 9.27 1591.28 1541.06 427.59 101.08 6004300.11 388471.13 MWD+IFR-AK-CAZ-SC ~' 1786.84 42.95 7.86 1662.22 1612.00 489.84 110.44 6004362.21 388481.41 MWD+IFR-AK-CAZ-SC 1881.91 44.71 7.28 1730.80 1680.58 555.10 119.10 6004427.33 388491.05 MWD+IFR-AK-CAZ-SC 1977.49 45.90 7.46 1798.02 1747.80 622.49 127.82 6004494.57 388500.77 MWD+IFR-AK-CAZ-SC j 2072.75 47,72 6.36 1863.22 1813.00 691.43 136.17 6004563.38 388510.15 MWD+IFR-AK-CAZ-SC ! 2167.52 51.04 3.84 1924.92 1874.70 763.06 142.52 6004634.90 388517.57 MWD+IFR-AK-CAZ-SC i 2262.37 55.83 1.44 1981.41 1931.19 839.13 145.98 6004710.91 388522.17 MWD+IFR-AK-CAZ-SC ' 2358.22 58.34 0.68 2033.49 1983.27 919.58 147.46 6004791.31 388524.85 MWD+tFR-AK-CAZ-SC v Halliburton Company Survey Report ~' Company: GonocoPhiilips Alaska Inc. Ih~te: 5/8/2007 Time: 15:09:42 Page: 2 Field: Colville River Unit Co-ordinate(NE) Reference: Well: CC~3-301, True PJorth Sitr: Alpine CD3 Vertical (TVD) Reference: CD3-301: 50.2 ~<<-IL• CD3-301 Section (VS)Reference: Well (0.00N,O.OOE,55.OOAzi) N'ellpath: CD3-301 Survey Calculation Method: Minimum Curvature Db: Oracle Survey ~ 11~D Intl Azi~n TVD Sys TVD V/S E/W MapN b1apE Tool ft deg deg ft ft ft ft ft ft' 2452.62 58.64 0.88 2082.83 2032.61 1000.05 148.55 6004871.75 388527.15 MWD+IFR-AK-CAZ-SC 2548.03 58.23 359.97 2132.77 2082.55 1081.34 149.16 6004953.02 388528.97 MWD+IFR-AK-CAZ-SC 2643.50 58.08 359.99 2183.15 2132.93 1162.44 149.13 6005034.10 388530.15 MWD+IFR-AK-CAZ-SC 2738.58 59.05 0.77 2232.73 2182.51 1243.56 149.67 6005115.20 388531.91 MWD+IFR-AK-CAZ-SC 2832.83 56.94 0.64 2282.68 2232.46 1323.48. 150.66 6005195.08 388534.09 MWD+IFR-AK-CAZ-SC 2928.28 56.47 0.54 2335.08 2284.86 1403.25 151.48 6005274.83 388536.10 MWD+IFR-AK-CAZ-SC 3023.40 58.81 359.90 2385.99 2335.77 1483.59 151.78 6005355.15 388537.61 MWD+IFR-AK-CAZ-SC 3117.51 59.36 0.24 2434.34 2384.12 1564.33 151.88 6005435.87 388538.91 MWD+IFR-AK-CAZ-SC 3189.07 58.46 2.02 2471.29 2421.07 1625.60 153.08 6005497.11 388541.03 MWD+IFR-AK-CAZ-SC 3261.56 57.97 1.64 2509.48 2459.26 1687.19 155.05 6005558.65 388543.92 MWD+IFR-AK-CAZ-SC 3358.27 60.36 1.99 2559.04 2508.82 1770.18 157.68 6005641.59 388547.79 MWD+IFR-AK-CAZ-SC 3453.47 60.97 2.34 2605.68 2555.46 1853.11 160.82 6005724.46 388552.17 MWD+IFR-AK-CAZ-SC 3548.83 59.97 2.45 2652.68 2602.46 1936.01 164.29 6005807.29 388556.88 MWD+IFR-AK-CAZ-SC I 3645.02 59.62 0.89 2701.08 2650.86 2019.10 166.71 6005890.33 388560.54 MWD+IFR-AK-CAZ-SC 3740.29 59.13 0.95 2749.61 2699.39 2101.07 168.03 6005972.26 388563.08 MWD+IFR-AK-CAZ-SC ~i 3835.55 57.93 0.94 2799.34 2749.12 2182.31 169.37 6006053.46 388565.64 MWD+IFR-AK-CAZ-SC 3930.93 57.48 0.82 2850.30 2800.08 2262.92 170.61 6006134.04 388568.08 MWD+IFR-AK-CAZ-SC 4026.16 .56.64 1.36 2902.08 2851.86 2342.83 172.13 6006213.91 388570.79 MWD+IFR-AK-CAZ-SC i, 4121.12 56.49 1.82 2954.40 2904.18 2422.04 174.32 6006293.08 388574.18 MWD+IFR-AK-CAZ-SC 4216.14 58.34 353.66 3005.63 2955.41 2501.93 171.11 6006373.00 388572.16 MWD+IFR-AK-CAZ-SC 4307.27 60.76 354.72 3051.82 3001.60 2580.08 163.17 6006451.25 388565.39 MWD+IFR-AK-CAZ-SC ~ 4406.20 59.86 355.78 3100.82 3050.60 2665.72 156.05 6006536.98 388559.55 MWD+IFR-AK-CAZ-SC I 4501.56 58.47 356.53 3149.69 3099.47 2747.42 150.55 6006618.74 388555.28 MWD+IFR-AK-CAZ-SC 4596.23 57.97 356.34 3199.55 3149.33 2827.74 145.55 6006699.12 388551.48 MWD+IFR-AK-CAZ-SC 4691.75 57.12 357.98 3250.82 3200.60 2908.24 141.55 6006779.66 388548.68 MWD+IFR-AK-CAZ-SC 4786.80 56.29 2.77 3303.01 3252.79 2987.64 142.06 6006859.05 388550.37 MWD+IFR-AK-CAZ-SC 4882.13 56.84 3.32 3355.54 3305.32 3067.08 146.28 6006938.41 388555.79 MWD+IFR-AK-CAZ-SC 4977.34 57.50 4.14 3407.16 3356.94 3146.92 151.49 6007018.15 388562.19 MWD+IFR-AK-CAZ-SC ~ i 5072.18 57.91 3.26 3457.83 3407.61 3226.92 156.66 6007098.06 388568.56 MWD+IFR-AK-CAZ-SC 5167.63 59.60 4.26 3507.34 3457.12 3308.34 162.02 6007179.39 388575.13 MWD+IFR-AK-CAZ-SC 5262.94 58.77 4.59 3556.16 3505.94 3389.95 168.33 6007260.89 388582.66 MWD+IFR-AK-CAZ-SC 5358.19 56.58 5.10 3607.09 3556.87 3470.15 175.13 6007340.96 388590.65 MWD+IFR-AK-CAZ-SC 5453.46 56.43 4.83 3659.67 3609.45 3549.30 182.00 6007420.00 388598.71 MWD+IFR-AK-CAZ-SC 5548.84 56.28 4.72 3712.51 3662.29 3628.43 188.61 6007499.01 388606.50 MWD+IFR-AK-CAZ-SC ~I 5643.88 56.24 5.21 3765.30 3715.08 3707.16 195.45 6007577.63 388614.52 MWD+IFR-AK-CAZ-SC 5739.06 55.73 5.07 3818.54 3768.32 3785.74 202.52 6007656.08 388622.76 MWD+IFR-AK-CAZ-SC 5834.54 54.77 5.24 3872.97 3822.75 3863.87 209.57 6007734.09 388630.98 MWD+IFR-AK-CAZ-SC 5929.69 54.32 5.14 3928.16 3877.94 3941.06 216.58 6007811.16 388639.14 MWD+IFR-AK-CAZ-SC 6025.10 55.75 6.16 3982.84 3932.62 4018.86 224.28 6007888.84 388648.01 MWD+IFR-AK-CAZ-SC ~ 6120.25 57.92 7.57 4034.89 3984.67 4097.93 233.82 6007967.75 388658.72 MWD+IFR-AK-CAZ-SC 6215.62 58.18 7.62 4085.36 4035.14 4178.15 244.51 6008047.78 388670.61 MWD+IFR-AK-CAZ-SC 6310.62 58.32 6.93 4135.35 4085.13 4258.28 254.74 6008127.75 388682.04 MWD+IFR-AK-CAZ-SC ~ 6405.31 58.69 5.29 4184.82 4134.60 4338.56 263.33 6008207.88 388691.83 MWD+IFR-AK-CAZ-SC ~ 6501.26 57.87 3.56 4235.27 4185.05 4419.92 269.63 6008289.14 388699.34 MWD+IFR-AK-CAZ-SC 6596.44 59.30 0.78 4284.88 4234.66 4501.08 272.69 6008370.23 388703.62 MWD+IFR-AK-CAZ-SC 6691.36 58.24 0.06 4334.10 4283.88 4582.24 273.29 6008451.37 388705.43 MWD+tFR-AK-CAZ-SC 6786.15 57.17 0.92 4384.74 4334.52 4662.36 273.97 6008531.46 388707.31 MWD+IFR-AK-CAZ-SC ~ 6881.02 56.48 1.09 4436.65 4386.43 4741.76 275.37 6008610.82 388709.89 MWD+IFR-AK-CAZ-SC i 6975.97 57.27 3.11 4488.54 4438.32 4821.21 278.29 6008690.22 388714.00 MWD+IFR-AK-CAZ-SC 7071.17 57.57 3.69 4539.81 4489.59 4901.29 283.04 6008770.21 388719.95 MWD+IFR-AK-CAZ-SC 7166.80 58.86 3.09 4590.18 4539.96 4982.44 287.85 6008851.27 388725.97 MWD+IFR-AK-CAZ-SC 7261.43 59.70 2.31 4638.52 4588.30 5063.70 291.68 6008932.45 388731.01 MWD+IFR-AK-CAZ-SC 7356.27 59.08 0.29 4686.81 4636.59 5145.29 293.53 6009014.01 388734.09 MWD+IFR-AK-CAZ-SC ~ Halliburton Company Survey Report Con,pani: ConocoPhillips Alaska Inc. Date: 5!x/2007 Time: 15:09:42 Page: 3 Field: Colville River Unit Co-ordinate(NE)Reference: WeII: CD3-301, True North Site: Alpine CD3 Vertical (TVD) Reference: CD3-301:50.2 WeII: CD3-301 Section (VS) Reference: Well (O.OON;O.OOE,55.OOAzi) ' N'ellpath: CD3-301 Survey Cakulation Method'i Minimum'Curvature Ub: Orade Sun c~ __ -- - -_ - - ~tU Iucl ~zim TVD Svs TVD N/S ICI~~ Mz3pN ~1ap~ Tool I ft deg deg ft ft ft ft ft ft -_ - _ __ __ 7449.00 57.45 359.24 4735.59 4685.37 5224.15 293.22 6009092.86 388734.95 MWD+IFR-AK-CAZ-SC 7546.17 56.86 359.93 4788.29 4738.07 5305.79 292.62 6009174.48 388735.58 MWD+IFR-AK-CAZ-SC 7640.83 56.64 0.13 4840.19 4789.97 5384.95 292.66 6009253.63 388736.80 MWD+IFR-AK-CAZ-SC i 7736.70 56.88 1.93 4892.75 4842.53 5465.11 294.11 6009333.76 388739.44 MWD+IFR-AK-CAZ-SC 7831.60 58.28 2.93 4943.62 4893.40 5545.15 297.51 6009413.72 388744.04 MWD+IFR-AK-CAZ-SC 7927.31 58.95 4.12 4993.47 4943.25 5626.70 302.54 6009495.18 388750.29 MWD+IFR-AK-CAZ-SC ! 8022.48 58.35 3.65 5042.98 4992.76 5707.78 308.04 6009576.17 388757.01 MWD+IFR-AK-CAZ-SC 8117.64 58.21 3.84 5093.02 5042.80 5788.56 313.33 6009656.85 388763.50 MWD+IFR-AK-CAZ-SC 8212.91 58.20 3.69 5143.21 5092.99 5869.36 318.65 6009737.55 388770.02 MWD+IFR-AK-CAZ-SC ! 8307.99 58.86 2.83 5192.85 5142.63 5950.32 323.26 6009818.43 388775.84 MWD+IFR-AK-CAZ-SC ~ 8403.08 58.93 1.91 5241.97 5191.75 6031.67 326.62 6009899.71 388780.42 MWD+IFR-AK-CAZ-SC 8497.85 58.18 0.65 5291.41 5241.19 6112.49 328.43 6009980.49 388783.44 MWD+IFR-AK-CAZ-SC 8592.76 57.02 0.27 5342.27 5292.05 6192.63 329.08 6010060.60 388785.29 MWD+IFR-AK-CAZ-SC 8687.74 56.61 0.38 5394.26 5344.04 6272.11 329.53 6010140.07 388786.92 MWD+IFR-AK-CAZ-SC 8783.73 57.38 1.04 5446.54 5396.32 6352.61 330.53 6010220.53 388789.13 MWD+IFR-AK-CAZ-SC 8878.15 58.92 0.98 5496.37 5446.15 6432.79 331.94 6010300.68 388791.74 MWD+IFR-AK-CAZ-SC 8972.98 59.21 1.03 5545.11 5494.89 6514.12 333.37 6010381.97 388794.38 MWD+IFR-AK-CAZ-SC 9068.60 58.43 1.18 5594.62 5544.40 6595.91 334.95 6010463.72 388797.18 MWD+IFR-AK-CAZ-SC ' 9163.29 58.82 2.62 5643.92 5593.70 6676.71 337.63 6010544.46 388801.07 MWD+IFR-AK-CAZ-SC 9258.56 58.04 1.11 5693.80 5643.58 6757.83 340.27 6010625.53 388804.93 MWD+IFR-AK-CAZ-SC 9353.61 57.25 1.08 5744.67 5694.45 6838.11 341.81 6010705.77 388807.67 MWD+IFR-AK-CAZ-SC 9449.16 58.50 1.75 5795.48 5745.26 6919.00 343.81 6010786.61 388810.88 MWD+IFR-AK-CAZ-SC 9544.37 58.78 1.93 5845.03 5794.81 7000.26 346.42 6010867.82 388814.70 MWD+IFR-AK-CAZ-SC 9639.08 58.48 2.26 5894.33 5844.11 7081.07 349.38 6010948.57 388818.87 MWD+IFR-AK-CAZ-SC 9734.35 57.40 2.06 5944.90 5894.68 7161.76 352.42 6011029.19 388823.12 MWD+IFR-AK-CAZ-SC i 9829.63 56.82 2.10 5996.64 5946.42 7241.71 355.32 6011109.09 388827.21 MWD+IFR-AK-CAZ-SC ~I 9924.76 57.18 1.41 6048.45 5998.23 7321.46 357.77 6011188.78 388830.85 MWD+IFR-AK-CAZ-SC 10019.90 57.71 2.37 6099.64 6049.42 7401.60 360.41 6011268.87 388834.69 MWD+IFR-AK-CAZ-SC 10115.04 57.99 3.18 6150.27 6100.05 7482.06 364.31 6011349.25 388839.80 MWD+IFR-AK-CAZ-SC 10209.40 58.33 2.29 6200.05 6149.83 7562.12 368.14 6011429.25 388844.82 MWD+IFR-AK-CAZ-SC 10304.94 57.46 1.96 6250.83 6200.61 7643.00 371.14 6011510.06 388849.03 MWD+IFR-AK-CAZ-SC 10400.17 57.75 3.55 6301.85 6251.63 7723.31 375.01 6011590.30 388854.09 MWD+IFR-AK-CAZ-SC 10495.53 61.38 6.09 6350.16 6299.94 7805.21 381.95 6011672.08 388862.26 MWD+IFR-AK-CAZ-SC 10590.46 61.41 8.49 6395.61 6345.39 7887.87 392.52 6011754.56 388874.07 MWD+IFR-AK-CAZ-SC 10685.43 61.28 11.20 6441.16 6390.94 7969.97 406.77 6011836.44 388889.54 MWD+IFR-AK-CAZ-SC ~I 10780.73 61.86 11.97 6486.53 6436.31 8052.07 423.60 6011918.27 388907.59 MWD+IFR-AK-CAZ-SC 10875.65 65.29 15.04 6528.77 6478.55 8134.69 443:48 6012000.57 388928.70 MWD+IFR-AK-CAZ-SC 10970.70 66.44 19.33 6567.65 6517.43 8217.53 469.11 6012083.01 388955.57 MWD+IFR-AK-CAZ-SC 11065.89 68.52 22.65 6604.12 6553.90 8299.60 500.62 6012164.59 388988.30 MWD+IFR-AK-CAZ-SC 11160.27 70.62 25.82 6637.07 6586.85 8380.22 536.93 6012244.66 389025.81 MWD+IFR-AK-CAZ-SC i 11255.82 72.70 30.11 6667.14 6616.92 8460.29 579.46 6012324.07 389069.53 MWD+IFR-AK-CAZ-SC i 11351.30 73.22 33.98 6695.13 6644.91 8537.65 627.89 6012400.69 389119.11 MWD+IFR-AK-CAZ-SC 11446.48 74.94 36.35 6721.24 6671.02 8612.46 680.61 6012474.70 389172.93 MWD+IFR-AK-CAZ-SC '~ 11541.44 75.96 38.01 6745.10 6694.88 8685.69 736.15 6012547.08 389229.56 MWD+IFR-AK-CAZ-SC i 11636.91 75.77 41.57 6768.42 6718.20 8756.81 795.39 6012617.31 389289.85 MWD+IFR-AK-CAZ-SC 11731.66 76.60 45.66 6791.06 6740.84 8823.41 858.85 6012682.94 389354.29 MWD+IFR-AK-CAZ-SC 11827.04 77.48 48.58 6812.45 6762.23 8886.65 926.95 6012745.15 389423.33 MWD+IFR-AK-CAZ-SC 11921.81 79.58 51.77 6831.30 6781.08 8946.11 998.28 6012803.53 389495.53 MWD+IFR-AK-CAZ-SC 12016.90 84.07 52.41 6844.82 6794.60 9003.92 1072.52 6012860.23 389570.62 MWD+IFR-AK-CAZ-SC 12044.53 85.32 53.56 6847.37 6797.15 9020.49 1094.49 6012876.46 389592.83 MWD+IFR-AK-CAZ-SC 12144.49 93.07 59.64 6848.78 6798.56 9075.43 1177.83 6012930.15 389676.98 MWD+IFR-AK-CAZ-SC 12240.40 91.95 59.67 6844.58 6794.36 9123.84 1260.52 6012977.31 389760.38 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: Conot:oPhillips Alaska Inc. Datc: 5/8/2007 time: 15:09:421- Page: -1 Field: Colville River Unit Co-ordinate(NE)Reference: Well: CD3-301, True North Site:. :,}pine CD3 Vertical (TVD) Reference: CD3-301: 50.2 tiVell: CD3 301 Section (VS) Reference: Well. (O.OON,O.OOE,5a~.00Azi) Wellpath: CD'3-301 Survey Calculation 1llethod: Minirqum Curvattare I)h: Oracle __ _- ' Sune} j - _ ___ _ -- - _ _ _ _---_ MD Incl Aim TVD Sys TVD ~/S EIW A1apN l1apE Tool ft deg deg ft ft ft ft ft ft 12334.32 91.47 60.16 6841.77 6791.55 9170.90 1341.75 6013023.14 389842.29 MWD+IFR-AK-CAZ-SC 12429.17 90.89 58.06 6839.82 6789.60 9219.58 1423.12 6013070.60 389924.38 MWD+IFR-AK-CAZ-SC 12527.31 90.89 49.71 6838.29 6788.07 9277.37 1502.33 6013127.19 390004.43 MWD+IFR-AK-CAZ-SC i 12620.93 92,54 48.65 6835.49 6785.27 9338.54 1573.14 6013187.29 390076.14 MWD+IFR-AK-CAZ-SC 12717.21 90.89 46.97 6832.61 6782.39 9403.16 1644.44 6013250.84 390148.39 MWD+IFR-AK-CAZ-SC 12810.22 91.23 46.25 6830.89 6780.67 9467.05 1712.02 6013313.69 390216.91 MWD+IFR-AK-CAZ-SC 12907.33 91.03 48.60 6828.97 6778.75 9532.73 1783.51 6013378.30 390289.37 MWD+IFR-AK-CAZ-SC j 13003.58 90.96 53.16 6827.30 6777.08 9593.43 1858.15 6013437.87 390364.91 MWD+IFR-AK-CAZ-SC 13098.07 90.34 58.32 6826.23 6776.01 9646.60 1936.21 6013489.86 390443.75 MWD+IFR-AK-CAZ-SC ~ 13191.37 91.30 63.79 6824.89 6774.67 9691.74 2017.82 6013533.77 390526.02 MWD+IFR-AK-CAZ-SC 13288.81 90.31 65.43 6823.52 6773.30 9733.51 2105.83 6013574.22 390614.64 MWD+IFR-AK-CAZ-SC 13385.35 90.82 63.81 6822.57 6772.35 9774.89 2193.05 6013614.28 390702.46 MWD+IFR-AK-CAZ-SC 13480.46 90.58 62.83 6821.41 6771.19 9817.59 2278.03 6013655.70 390788.05 MWD+IFR-AK-CAZ-SC 13574.90 90.27 64.64 6820.71 6770.49 9859.38 2362.71 6013696.22 390873.35 MWD+IFR-AK-CAZ-SC 13669.78 89.76 65.77 6820.68 6770.46 9899.17 2448.84 6013734.71 390960.06 MWD+IFR-AK-CAZ-SC 13765.94 91.06 66.38 6820.00 6769.78 9938.16 2536.73 6013772.38 391048.51 MWD+IFR-AK-CAZ-SC 13790.13 90.31 65.71 6819.71 6769.49 9947.98 2558.84 6013781.87 391070.76 MWD+IFR-AK-CAZ-SC ~ 13866.60 89.18 62.80 6820.05 6769.83 9981.19 2627.71 6013814.05 391140.11 MWD+IFR-AK-CAZ-SC 13895.99 89.22 62.74 6820.46 6770.24 9994.64 2653.84 6013827.10 391166.44 MWD+IFR-AK-CAZ-SC 13926.55 87.91 62.33 6821.22 6771.00 10008.73 2680.95 6013840.78 391193.75 MWD+IFR-AK-CAZ-SC 13964.47 88.46 61.44 6822.42 6772.20 10026.59 2714.37 6013858.14 391227.44 MWD+IFR-AK-CAZ-SC 14028.43 92.82 63.98 6821.71 6771.49 10055.90 2771.19 6013886.60 391284.69 MWD+IFR-AK-CAZ-SC 14124.28 94.53 64.80 6815.57 6765.35 10097.25 2857.44 6013926.64 391371.54 MWD+IFR-AK-CAZ-SC 14218.12 90.93 66.24 6811.10 6760.88 10136.08 2942.74 6013964.19 391457.40 MWD+IFR-AK-CAZ-SC ~ 14315.16 90.24 62.63 6810.11 6759.89 10177.95 3030.26 6014004.74 391545.52 MWD+IFR-AK-CAZ-SC 14410.11 92.64 63.99 6807.72 6757.50 10220.58 3115.05 6014046.10 391630.94 MWD+IFR-AK-CAZ-SC 14504.19 92.20 63.43 6803.75 6753.53 10262.21 3199.33 6014086.46 391715.82 MWD+IFR-AK-CAZ-SC 14601.34 93.68 63.08 6798.76 6748.54 10305.87 3285.97 6014128.82 391803.10 MWD+IFR-AK-CAZ-SC 14696.06 93.57 58.65 6792.77 6742.55 10351.88 3368.52 6014173.58 391886.32 MWD+IFR-AK-CAZ-SC 14791.89 90.38 52.19 6789.47 6739.25 10406.21 3447.31 6014226.72 391965.91 MWD+IFR-AK-CAZ-SC j 14886.85 91.44 50.82 6787.96 6737.74 10465.31 3521.62 6014284.70 392041.09 MWD+IFR-AK-CAZ-SC j 14982.78 92.75 46.99 6784.45 6734.23 10528.30 3593.86 6014346.60 392114.25 MWD+IFR-AK-CAZ-SC 15076.14 94.23 43.52 6778.77 6728.55 10593.89 3660.03 6014411.19 392181.39 MWD+IFR-AK-CAZ-SC 15140.00 94.23 43.52 6774.06 - 6723.84 10640.07 3703.89 6014456.70 i 392225.93 ~ PROJECTED to TD Halliburton Company Survey Report Company: ConocoPhillips Alaska lnc. Date: 5/8/2007 Time: 14:41:54 Page: 1 I~ield7 Colville River Unit Co-ordiuate(NE)Reference: WeII: CD3-301, True North Site: Alpine CD3 Vertical (TVD) Re ference CD3-301 P61: 50.2 WeII: CD3-301. Section (VS) Refer ence: WeII. (O.OON,O.OOE,55.OOAzi) ~Vellpath: CD3-301PB1 Survey Calculation __ ~Icrhud: Minimum Curva __ - ture Ilh: Oracle -- Field: Colville River Unit - North Slope Alaska United States i Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 j Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 - WeII: CD3-301 Slot Name: Alpine CD3 ~ Well Position: +N/-S -14.54 ft Nort hing: 600387 4.12 ft Latitude: 70 25 10.338 N +E/-W -124.24 ft Easti ng : 388363.67 ft Longitude: 150 54 34.034 W Position Uncertainty: 0.00 ft Wellp ChtaWellp Chta D3-301PB1 Drilled From: CD3-301 j 501032054370 Tie-on Depth: 12044.53 ft Current Datum: CD3-301 PB1: Height 50.22 ft Above System Datum: Mean Sea Level Magnetic Data: 4/18/2007 Declination: 22.90 deg Field Strength: 57574 nT Mag Dip Angle: 80.77 deg ~ Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg ~ 36.72 0.00 0.00 55.00 I Survey Program for Definitive Wellpath Date• 5!8/2007 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 77.00 716.00 CD3-301 Gyro (77.00-716.00) (0 CB-GYRO-SS Camera based gyro single shot ~ 793.28 12044.53 CD3-301 Sperry (79 3.28-12044.5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 12044.53 14229.70 CD3-301 P B1 Schlumberger (12044 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC - - - Survey -- - ~Vlll heel Azieu !'Vll Sys 1~ll N/S 1?.i~~ MapN btapE Tool ft deg deg ft ft ft ft ft ft 36.72 0.00 0.00 36.72 -13.50 0.00 0.00 6003874.12 388363.67 TIE LINE 77.00 0.14 338.53 77.00 26.78 0.05 -0.02 6003874.17 388363.65 CB-GYRO-SS 170.00 0.29 347.24 170.00 119.78 0.38 -0.11 6003874.50 388363.56 CB-GYRO-SS 261.00 1.69 359.43 260.98 210.76 1.95 -0.18 6003876.07 388363.52 CB-GYRO-SS 353.00 2.93 3.65 352.91 302.69 5.65 -0.04 6003879.77 388363.71 CB-GYRO-SS 443.00 3.49 6.15 442.77 392.55 10.67 0.40 6003884.78 388364.23 CB-GYRO-SS 534.00 4.92 4.66 533.52 483.30 17.31 1.01 6003891.42 388364.94 CB-GYRO-SS 624.00 6.95 6.29 623.03 572.81 26.57 1.92 6003900.66 388365.99 CB-GYRO-SS 716.00 9.04 13.38 714.13 663.91 39.14 4.21 6003913.19 388368.46 CB-GYRO-SS 793.28 10.85 18.44 790.25 740.03 51.95 7.91 6003925.94 388372.36 MWD+IFR-AK-CAZ-SC 836.58 12.13 17.13 832.68 782.46 60.16 10.54 6003934.11 388375.11 MWD+IFR-AK-CAZ-SC I 932.09 15.59 14.15 925.40 875.18 82.20 16.64 6003956.06 388381.53 MWD+IFR-AK-CAZ-SC 1026.32 20.46 13.43 1014.98 964.76 110.52 23.56 6003984.26 388388.88 MWD+IFR-AK-CAZ-SC 1121.55 24.37 16.04 1103.00 1052.78 145.60 32.86 6004019.20 388398.70 MWD+IFR-AK-CAZ-SC I 1216.29 24.97 16.72 1189.09 1138.87 183.54 44.01 6004056.97 388410.42 MWD+IFR-AK-CAZ-SC 1311.56 26.27 16.51 1274.99 1224.77 223.01 55.79 6004096.26 388422.79 MWD+IFR-AK-CAZ-SC 1406.85 30.21 16.53 1358.92 1308.70 266.23 68.61 6004139.27 388436.25 MWD+IFR-AK-CAZ-SC 1501.43 34.13 12.02 1438.98 1388.76 315.02 80.91 6004187.87 388449.28 MWD+IFR-AK-CAZ-SC 1596.95 36.64 9.76 1516.85 1466.63 369.33 91.33 6004242.01 388460.50 MWD+IFR-AK-CAZ-SC 1691.99 40.23 9.27 1591.28 1541.06 427.59 101.08 6004300.11 388471.13 MWD+IFR-AK-CAZ-SC 1786.84 42.95 7.86 1662.22 1612.00 489.84 110.44 6004362.21 388481.41 MWD+IFR-AK-CAZ-SC 1881.91 44.71 7.28 1730.80 1680.58 555.10 119.10 6004427.33 388491.05 MWD+IFR-AK-CAZ-SC 1977.49 45.90 7.46 1798.02 1747.80 622.49 127.82 6004494.57 388500.77 MWD+IFR-AK-CAZ-SC 2072.75 47.72 6.36 1863.22 1813.00 691.43 136.17 6004563.38 388510.15 MWD+IFR-AK-CAZ-SC 2167.52 51.04 3.84 1924.92 1874.70 763.06 142.52 6004634.90 388517.57 MWD+IFR-AK-CAZ-SC ~ 2262.37 55.83 1.44 1981.41 1931.19 839.13 145.98 6004710.91 388522.17 MWD+IFR-AK-CAZ-SC 2358.22 58.34 0.68 2033.49 1983.27 919.58 147.46 6004791.31 388524.85 MWD+IFR-AK-CAZ-SC 2452.62 58.64 0.88 2082.83 2032.61 1000.05 148.55 6004871.75 388527.15 MWD+IFR-AK-CAZ-SC ~~ Halliburton Company Survey Report Company: ConocoPhillips Alaska lnc. Date: 5/8/2007 Iiiue: 14:41:54 Page: 2 Field: Co lville River Unit Co-ordinaYe (NE)Reference: Wetl: CD3-301 ,True North Site: Alpine GD3 Vertical (TVD) Reference: CD3-301 PB1: 50:2 Wetl: CD3-301 Sectio n (VS) Reference: Well (O.OON,O. OOE,55.OOAzi) Wellpath: CD3-301 PB1 Survey Cak ulatio u Method: Minimum C urv __ ature Db: Oracle Sunny b1D IncJ :~~im 'I'VD c_ vs TVll V/S E/W MapN MapE. Tool ft dey - deg ft ft ft ft ft ft 2548.03 58.23 359.97 2132.77 2082.55 1081 .34 149. 16 6004953. 02 388528. 97 MWD+IFR-AK-CAZ-SC 2643.50 58.08 359.99 2183.15 2132.93 1162 .44 149. 13 6005034. 10 388530. 15 MWD+IFR-AK-CAZ-SC ~ i 2738.58 59.05 0.77 2232.73 2182.51 1243 .56 149. 67 6005115. 20 388531. 91 MWD+IFR-AK-CAZ-SC ~ 2832.83 56.94 0.64 2282.68 2232.46 1323 .48 150. 66 6005195. 08 388534. 09 MWD+IFR-AK-CAZ-SC 2928.28 56.47 0.54 2335.08 2284.86 1403 .25 151. 48 6005274. 83 388536. 10 MWD+IFR-AK-CAZ-SC 3023.40 58.81 359.90 2385.99 2335.77 1483 .59 151. 78 6005355. 15 388537. 61 MWD+IFR-AK-CAZ-SC 3117.51 59.36 0.24 2434.34 2384.12 1564 .33 151. 88 6005435. 87 388538. 91 MWD+IFR-AK-CAZ-SC I 3189.07 58.46 2.02 2471.29 2421.07 1625 .60 153. 08 6005497. 11 388541. 03 MWD+IFR-AK-CAZ-SC 3261.56 57.97 1.64 2509.48 2459.26 1687 .19 155. 05 6005558. 65 388543. 92 MWD+IFR-AK-CAZ-SC 3358.27 60.36 1.99 2559.04 2508.82 1770 .18 157. 68 6005641. 59 388547. 79 MWD+IFR-AK-CAZ-SC 3453.47 60.97 2.34 2605.68 2555.46 1853 .11 160. 82 6005724. 46 388552. 17 MWD+IFR-AK-CAZ-SC 3548.83 59.97 2.45 2652.68 2602.46 1936 .01 164. 29 6005807. 29 388556. 88 MWD+IFR-AK-CAZ-SC 3645.02 59.62 0.89 2701.08 2650.86 2019 .10 166. 71 6005890. 33 388560. 54 MWD+IFR-AK-CAZ-SC 3740.29 59.13 0.95 2749.61 2699.39 2101 .07 168. 03 6005972. 26 388563. 08 MWD+IFR-AK-CAZ-SC 3835.55 57.93 0.94 2799.34 2749.12 2182 .31 169 .37 6006053. 46 388565. 64 MWD+IFR-AK-CAZ-SC ~ 3930.93 57.48 0.82 2850.30 2800.08 2262 .92 170 .61 6006134. 04 388568. 08 MWD+IFR-AK-CAZ-SC ~ 4026.16 56.64 1.36 2902.08 2851.86 2342 .83 172 .13 6006213. 91 388570. 79 MWD+IFR-AK-CAZ-SC 4121.12 56.49 1.82 2954.40 2904.18 2422 .04 174. 32 6006293. 08 388574. 18 MWD+IFR-AK-CAZ-SC 4216.14 58.34 353.66 3005.63 2955.41 2501 .93 171. 11 6006373. 00 388572. 16 MWD+IFR-AK-CAZ-SC 4307.27 60,76 354.72 3051.82 3001.60 2580 .08 163 .17 6006451. 25 388565. 39 MWD+IFR-AK-CAZ-SC 4406.20 59.86 355.78 3100.82 3050.60 2665 .72 156 .05 6006536. 98 388559. 55 MWD+IFR-AK-CAZ-SC 4501.56 58.47 356.53 3149.69 3099.47 2747 .42 150 .55 6006618. 74 388555. 28 MWD+IFR-AK-CAZ-SC 4596.23 57.97 356.34 3199.55 3149.33 2827 .74 145 .55 6006699. 12 388551. 48 MWD+IFR-AK-CAZ-SC 4691.75 57.12 357.98 3250.82 3200.60 2908 .24 141 .55 6006779. 66 388548. 68 MWD+IFR-AK-CAZ-SC I 4786.80 56.29 2.77 3303.01 3252.79 2987 .64 142 .06 6006859. 05 388550. 37 MWD+IFR-AK-CAZ-SC 4882.13 56.84 3.32 3355.54 3305.32 3067 .08 146 .28 6006938. 41 388555. 79 MWD+IFR-AK-CAZ-SC 4977.34 57.50 4.14 3407.16 3356.94 3146 .92 151 .49 6007018. 15 388562. 19 MWD+IFR-AK-CAZ-SC 5072.18 57.91 3.26 3457.83 3407.61 3226 .92 156 .66 6007098. 06 388568. 56 MWD+IFR-AK-CAZ-SC ~ 5167.63 59.60 4.26 3507.34 3457.12 3308 .34 162 .02 6007179. 39 388575. 13 MWD+IFR-AK-CAZ-SC I i 5262.94 58.77 4.59 3556.16 3505.94 3389 .95 168 .33 6007260. 89 388582. 66 MWD+IFR-AK-CAZ-SC 5358.19 56.58 5.10 3607.09 3556.87 3470 .15 175 .13 6007340. 96 388590. 65 MWD+IFR-AK-CAZ-SC 5453.46 56.43 4.83 3659.67 3609.45 3549 .30 182 .00 6007420. 00 388598. 71 MWD+IFR-AK-CAZ-SC 5548.84 56.28 4.72 3712.51 3662.29 3628 .43 188 .61 6007499. 01 388606. 50 MWD+IFR-AK-CAZ-SC 5643.88 56.24 5.21 3765.30 3715.08 3707 .16 195 .45 6007577. 63 388614. 52 MWD+IFR-AK-CAZ-SC 5739.06 55.73 5.07 3818.54 3768.32 3785 .74 202 .52 6007656. 08 388622. 76 MWD+IFR-AK-CAZ-SC 5834.54 54.77 5.24 3872.97 3822.75 3863 .87 209 .57 6007734. 09 388630. 98 MWD+IFR-AK-CAZ-SC 5929.69 54.32 5.14 3928.16 3877.94 3941 .06 216 .58 6007811. 16 388639. 14 MWD+IFR-AK-CAZ-SC 6025.10 55.75 6.16 3982.84 3932.62 4018 .86 224 .28 6007888. 84 388648. 01 MWD+tFR-AK-CAZ-SC 6120.25 57.92 7.57 4034.89 3984.67 4097 .93 233 .82 6007967. 75 388658. 72 MWD+IFR-AK-CAZ-SC 6215.62 58.18 7.62 4085.36 4035.14 4178 .15 244 .51 6008047. 78 388670. 61 MWD+IFR-AK-CAZ-SC 6310.62 58.32 6.93 4135.35 4085.13 4258 .28 254 .74 6008127. 75 388682. 04 MWD+IFR-AK-CAZ-SC 6405.31 58.69 5.29 4184.82 4134.60 4338 .56 263 .33 6008207. 88 388691. 83 MWD+IFR-AK-CAZ-SC 6501.26 57.87 3.56 4235.27 4185.05 4419 .92 269 .63 6008289. 14 388699. 34 i MWD+IFR-AK-CAZ-SC 6596.44 59.30 0.78 4284.88 4234.66 4501 .08 272 .69 6008370. 23 388703. 62 MWD+IFR-AK-CAZ-SC 6691.36 58.24 0.06 4334.10 4283.88 4582 .24 273 .29 6008451. 37 388705. 43 MWD+IFR-AK-CAZ-SC 6786.15 57.17 0.92 4384.74 4334.52 4662 .36 273 .97 6008531. 46 388707. 31 MWD+IFR-AK-CAZ-SC '; 6881.02 56.48 1.09 4436.65 4386.43 4741 .76 275 .37 6008610. 82 388709. 89 MWD+IFR-AK-CAZ-SC 6975.97 57.27 3.11 4488.54 4438.32 4821 .21 278 .29 6008690. 22 388714. 00 MWD+IFR-AK-CAZ-SC 7071.17 57.57 3.69 4539.81 4489.59 4901 .29 283 .04 6008770. 21 388719. 95 MWD+IFR-AK-CAZ-SC 7166.80 58.86 3.09 4590.18 4539.96 4982 .44 287 .85 6008851. 27 388725. 97 MWD+IFR-AK-CAZ-SC 7261.43 59.70 2.31 4638.52 4588.30 5063 .70 291 .68 6008932 .45 388731. 01 MWD+IFR-AK-CAZ-SC I 7356.27 59.08 0.29 4686.81 4636.59 5145 .29 293 .53 6009014 .01 388734. 09 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report L' Company: CanocoPhlllips Alaska Inc. Date: 5/8/2007 Time: 14:41:54 Ynge: 3 Field: Colville River Unit Co-a~dinate(NE)Iteference: Well: CD3-301, True North Site: Alpine CD3 Vertical (T3~D) Reference' CD3-301PB1: 50.2 Well: CD3-301 ,.Section (VS) Reference: Well (O.OON,O.OOE,55.OOAzi) Wellpath: CD3-301PB1 Survey Calculation Method: Minimum Curvature llb: Oracle ___ __ -- ~ Son~e~° 1iD Intl Azim TVD Sys'I"VD N/S I~:~W MapN MapE ` "loo! ft deg deg ft ft ft ft ft ft 7449.00 57.45 359.24 4735.59 4685.37 5224.15 293.22 6009092.86 388734.95 MWD+IFR-AK-CAZ-SC 7546.17 56.86 359.93 4788,29 4738.07 5305.79 292.62 6009174.48 388735.58 MWD+IFR-AK-CAZ-SC 7640.83 56.64 0.13 4840.19 4789.97 5384.95 292.66 6009253.63 388736.80 MWD+IFR-AK-CAZ-SC 7736.70 56.88 1.93 4892.75 4842.53 5465.11 294.11 6009333.76 388739.44 MWD+IFR-AK-CAZ-SC 7831.60 58.28 2.93 4943.62 4893.40 5545.15 297.51 6009413.72 388744.04 MWD+IFR-AK-CAZ-SC I 7927.31 58.95 4.12 4993.47 4943.25 5626.70 302.54 6009495.18 388750.29 MWD+IFR-AK-CAZ-SC 8022.48 58.35 3.65 5042.98 4992.76 5707.78 308.04 6009576.17 388757.01 MWD+IFR-AK-CAZ-SC ~ 8117.64 58.21 3.84 5093.02 5042.80 5788.56 313.33 6009656.85 388763.50 MWD+IFR-AK-CAZ-SC 8212.91 58.20 3.69 5143.21 5092.99 5869.36 318.65 6009737.55 388770.02 MWD+IFR-AK-CAZ-SC 8307.99 58.86 2.83 5192.85 5142.63 5950.32 323.26 6009818.43 388775.84 MWD+IFR-AK-CAZ-SC i 8403.08 58.93 1.91 5241.97 5191.75 6031.67 326.62 6009899.71 388780.42 MWD+IFR-AK-CAZ-SC 8497.85 58.18 0.65 5291.41 5241.19 6112.49 328.43 6009980.49 388783.44 MWD+IFR-AK-CAZ-SC 8592.76 57.02 0.27 5342.27 5292.05 6192.63 329.08 6010060.60 388785.29 MWD+IFR-AK-CAZ-SC 8687.74 56.61 0.38 5394.26 5344.04 6272.11 329.53 6010140.07 388786.92 MWD+IFR-AK-CAZ-SC 8783.73 57.38 1.04 5446.54 5396.32 6352.61 330.53 6010220.53 388789.13 MWD+IFR-AK-CAZ-SC 8878.15 58.92 0.98 5496.37 5446.15 6432.79 331.94 6010300.68 388791.74 MWD+IFR AK CAZ SC - - - 8972.98 59.21 1.03 5545.11 5494.89 6514.12 333.37 6010381.97 388794.38 MWD+IFR-AK-CAZ-SC 9068.60 58.43 1.18 5594.62 5544.40 6595.91 334.95 6010463.72 388797.18 MWD+IFR-AK-CAZ-SC 9163.29 58.82 2.62 5643.92 5593.70 6676.71 337.63 6010544.46 388801.07 MWD+IFR-AK-CAZ-SC ~ 9258.56 58.04 1.11 5693.80 5643.58 6757.83 340.27 6010625.53 388804.93 MWD+IFR-AK-CAZ-SC 9353.61 57.25 1.08 5744.67 5694.45 6838.11 341.81 6010705.77 388807.67 MWD+IFR-AK-CAZ-SC 9449.16 58.50 1.75 5795.48 5745.26 6919.00 343.81 6010786.61 388810.88 MWD+IFR-AK-CAZ-SC 9544.37 58.78 1.93 5845.03 5794.81 7000.26 346.42 6010867.82 388814.70 MWD+IFR-AK-CAZ-SC 9639.08 58.48 2.26 5894.33 5844.11 7081.07 349.38 6010948.57 388818.87 MWD+IFR-AK-CAZ-SC 9734.35 57.40 2.06 5944.90 5894.68 7161.76 352.42 6011029.19 388823.12 MWD+IFR-AK-CAZ-SC 9829.63 56.82 2.10 5996.64 5946.42 7241.71 355.32 6011109.09 388827.21 MWD+IFR-AK-CAZ-SC 9924.76 57.18 1.41 6048.45 5998.23 7321.46 357.77 6011188.78 388830.85 MWD+IFR-AK-CAZ-SC 10019.90 57.71 2.37 6099.64 6049.42 7401.60 360.41 6011268.87 388834.69 MWD+IFR-AK-CAZ-SC 10115.04 57.99 3.18 6150.27 6100.05 7482.06 364.31 6011349.25 388839.80 MWD+IFR-AK-CAZ-SC 10209.40 58.33 2.29 6200.05 6149.83 7562.12 368.14 6011429.25 388844.82 MWD+IFR-AK-CAZ-SC 10304.94 57.46 1.96 6250.83 6200.61 7643.00 371.14 6011510.06 388849.03 MWD+IFR-AK-CAZ-SC i 10400.17 57.75 3.55 6301.85 6251.63 7723.31 375.01 6011590.30 388854.09 MWD+IFR-AK-CAZ-SC 10495.53 61.38 6.09 6350.16 6299.94 7805.21 381.95 6011672.08 388862.26 MWD+IFR-AK-CAZ-SC j 10590.46 61.41 8.49 6395.61 6345.39 7887.87 392.52 6011754.56 388874.07 MWD+IFR-AK-CAZ-SC 10685.43 61.28 11.20 6441.16 6390.94 7969.97 406.77 6011836.44 388889.54 MWD+IFR-AK-CAZ-SC 10780.73 61.86 11.97 6486.53 6436.31 8052.07 423.60 6011918.27 388907.59 MWD+IFR-AK-CAZ-SC 10875.65 65.29 15.04 6528.77 6478.55 8134.69 443.48 6012000.57 388928.70 MWD+IFR-AK-CAZ-SC 10970.70 66.44 19.33 6567.65 6517.43 8217.53 469.11 6012083.01 388955.57 MWD+IFR-AK-CAZ-SC 11065.89 68.52 22.65 6604.12 6553.90 8299.60 500.62 6012164.59 388988.30 MWD+IFR-AK-CAZ-SC 11160.27 70.62 25.82 6637.07 6586.85 8380.22 536.93 6012244.66 389025.81 MWD+IFR-AK-CAZ-SC 11255.82 72.70 30.11 6667.14 6616.92 8460.29 579.46 6012324.07 389069.53 MWD+IFR-AK-CAZ-SC 11351.30 73.22 33.98 6695.13 6644.91 8537.65 627.89 6012400.69 389119.11 MWD+IFR-AK-CAZ-SC j 11446.48 74.94 36.35 6721.24 6671.02 8612.46 680.61 6012474.70 389172.93 MWD+IFR-AK-CAZ-SC 11541.44 75.96 38.01 6745.10 6694.88 8685.69 736.15 6012547.08 389229.56 MWD+IFR-AK-CAZ-SC 11636.91 75.77 41.57 6768.42 6718.20 8756.81 795.39 6012617.31 389289.85 MWD+IFR-AK-CAZ-SC 11731.66 76.60 45.66 6791.06 6740.84 8823.41 858.85 6012682.94 389354.29 MWD+IFR-AK-CAZ-SC 11827.04 77.48 48.58 6812.45 6762.23 8886.65 926.95 6012745.15 389423.33 MWD+IFR-AK-CAZ-SC 11921.81 79.58 51.77 6831.30 6781.08 8946.11 998.28 6012803.53 389495.53 MWD+IFR-AK-CAZ-SC 12016.90 84.07 52.41 6844.82 6794.60 9003.92 1072.52 6012860.23 389570.62 MWD+IFR-AK-CAZ-SC 12044.53 85.32 53.56 6847.37 6797.15 9020.49 1094.49 6012876.46 389592.83 MWD+IFR-AK-CAZ-SC 12144.49 93.07 59.64 6848.78 6798.56 9075.43 1177.83 6012930.15 389676.98 MWD+IFR-AK-CAZ-SC 12240.40 91.95 59.67 6844.58 6794.36 9123.84 1260.52 6012977.31 389760.38 MWD+IFR-AK-CAZ-SC 12334.32 91.47 60.16 6841.77 6791.55 9170.90 1341.75 6013023.14 389842.29 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Field. Colville River Unit ', Sitc: Aipinc CD3 ', Vi'ell: CD3-301 Wellpath: CD3-301 PB1 Survev - MD ____ Ltcl Azim _fFD ft deg. _ deg __ __ ft 12429.17 90.89 58.06 6839.82 12527.31 90.89 49.71 6838.29 12620.93 92.54 48.65 6835.49 12717.21 90.89 46.97 6832.61 12810.22 91.23 46.25 6830.89 12907.33 91.03 48.60 6828.97 13003.58 90.96 53.16 6827.30 13098.07 90.34 58.32 6826.23 13191.37 91.30 63.79 6824.89 13288.81 90.31 65.43 6823.52 13385.35 90.82 63.81 6822.57 13480.46 90.58 62.83 6821.41 13574.90 90.27 64.64 6820.71 13669.78 89.76 65.77 6820.68 13765.94 91.06 66.38 6820.00 13861.91 89.42 62.95 6819.59 13958.21 93.19 64.67 6817.40 14051.78 90.96 64.67 6814.01 14148.16 92.98 67.44 6810.70 14229.70 92.26 67.59 6806.97 14294.00 92.26 67.59 6804.44 Date: 5!8!2007 Timer 14:41:54 Pngc: a Co-ordinate(NE)Re4'erence: Well: CD3-301, True North Vertical ("1'VD) Reference: CD3-301 P61: 50.2 ', Section (VS) Reference: Well'(O.OON,O.OOE,55.OOAzi) Survey Calculation Itlethod: Minimum Curvature Db: Oracle ft ft ft ft - 6789. 60 ---- 9219. - 58 1423. 12 _ _ 6013070 .6 6788. 07 9277. 37 1502. 33 6013127. 1 6785. 27 9338. 54 1573. 14 6013187. 2 6782. 39 9403. 16 1644. 44 6013250. 8 6780. 67 9467. 05 1712. 02 6013313. 6 6778. 75 9532. 73 1783. 51 6013378. 3 6777. 08 9593. 43 1858. 15 6013437. 8 6776. 01 9646. 60 1936. 21 6013489 .8 6774. 67 9691. 74 2017. 82 6013533. 7 6773. 30 9733. 51 2105. 83 6013574. 22 6772. 35 9774. 89 2193. 05 6013614. 2 6771. 19 9817. 59 2278. 03 6013655. 7 6770. 49 9859. 38 2362. 71 6013696. 22 6770. 46 9899. 17 2448. 84 6013734. 71 6769. 78 9938. 16 2536. 73 6013772. 3 6769. 37 9979. 22 2623. 46 6013812 .1 6767. 18 10021. 70 2709. 83 6013853 .3 6763. 79 10061. 71 2794. 34 6013892. 0 6760. 48 10100. 79 2882. 36 6013929. 82 6756. 75 10131. 95 2957. 62 6013959. 8 6754. 22 10156. 44 3017. 02 6013983. MapF lunl ft 389924.38 MWD+IFR-AK-CAZ-SC 390004.43 MWD+IFR-AK-CAZ-SC I 390076.14 i MWD+IFR-AK-CAZ-SC 390148.39 MWD+IFR-AK-CAZ-SC 390216.91 MWD+IFR-AK-CAZ-SC 390289.37 MWD+IFR-AK-CAZ-SC 390364.91 MWD+IFR-AK-CAZ-SC 390443.75 MWD+IFR-AK-CAZ-SC 390526.02 MWD+IFR-AK-CAZ-SC 390614.64 MWD+IFR-AK-CAZ-SC ~ 390702.46 MWD+IFR-AK-CAZ-SC 390788.05 MWD+IFR-AK-CAZ-SC 390873.35 MWD+IFR-AK-CAZ-SC 390960.06 MWD+IFR-AK-CAZ-SC 391048.51 MWD+IFR-AK-CAZ-SC 391135.83 MWD+IFR-AK-CAZ-SC 391222.82 MWD+IFR-AK-CAZ-SC I 391307.92 MWD+IFR-AK-CAZ-SC 391396.50 MWD+IFR-AK-CAZ-SC i, 391472.22 MWD+IFR-AK-CAZ-SC 391531.97 PROJECTED to TD 0 9 9 4 9 0 7 6 7 8 0 8 4 2 5 4 44 Time Logs Da#e From To Dur S Cie th E: De th Phase Code Subcode T COM_____ - ----- 04/09/2007 12:00 00:00 12.00 805 2,220 SURFA DRILL DDRL P - - Drill 12 1/4" hole w/ motor f/ 805' to 2220' MD - 1956' ND ADT - 8.07 hrs. =ART - 3.94 hrs AST - 4.13 hrs. WOB 15/20 k RPM 50 GPM 600 @ 1760 psi String wt. - PU 135 SO 125 Rot 130 for ue on/off btm. - 8,000/5,500 ft/Ibs. 04/10/2007 00:00 08:15 8.25 2,220 2,898 SURFA DRILL DDRL P Drill 12 1/4" hole w/ motor f/ 2220' to 2898' MD - 2318' ND 08:15 09:00 0.75 2,898 2,898 SURFA RIGMN RGRP T Drag chain jumped drive sprocket - re air dra chain 09:00 12:00 3.00 2,898 3,001 SURFA DRILL DDRL P Drill 12 1/4" hole w/ motor f/ 2898' to 3001' MD - 2377' ND ADT - 7.55 hrs. =ART - 6.0 hrs AST - 1.55 hrs. WOB 15/30 k RPM 50 GPM 625 @ 2040 psi String wt. - PU 137 SO 125 Rot 130 for ue on/off btm. - 8,500/6,500 ft/Ibs. 12:00 15:30 3.50 3,001 3,243 SURFA DRILL DDRL P Drill 12 1/4" hole w/ motor f/ 3001' to 3243' MD - 2499' ND ADT - 3.29 hrs. =ART - 3.06 hrs AST - 0.23 hrs. WOB 15/30 k RPM 50 GPM 625 @ 2040 psi String wt. - PU 137 SO 125 Rot 130 for ue on/off btm. - 8,500/6,500 fUlbs. 15:30 16:30 1.00 3,243 3,243 SURFA DRILL CIRC P Circulate and condition mud - 650 gpm / 2140 psi / 60 rpm -Flow check well, static 16:30 20:30 4.00 3,243 893 SURFA DRILL WPRT P Wipe hole from 3243' to 893 - 600 m/ 1920 si / 60 r m 20:30 21:45 1.25 893 3,170 SURFA DRILL WPRT P Blew down top drive and RIH from 893' to 3,170'. 21:45 22:45 1.00 3,170 3,243 SURFA DRILL CIRC P Washed down to 3,243' worked pumps up to 600 gpm and circulated well clean. 22:45 00:15 1.50 3,243 2,410 SURFA DRILL TRIP P POOH on trip tank from 3,243' to 2,410'. 04/11/2007 00:00 01:45 1.75 2,410 167 SURFA DRILL TRIP P POOH from 2410' to 893' -flow check well, static. -POOH from 893' to 167' stand back hwd 01:45 04:30 2.75 167 0 SURFA DRILL PULD P Lay down jars and flex collars - download MWD - LD BHA -clear tools from ri floor 04:30 06:00 1.50 0 0 SURFA CASIN RURD P Change out bails - Ru fill-up tool and casin runnin a ui ment 06:00 06:30 0.50 0 0 SURFA CASINC SFTY P Held Safety and Opts meeting with rig team 3 Time Logs. -- ___ _- -- Date From To_ _ _Dur S De th E,_~th Phase Code__ Sub_code T COM 04/12/2007 00:00 03:15 3.25 0 0 SURFA WELCT ROPE P Continue testing BOPE -Pipe and Blind rams -choke, kill, manifold and surface safety valves 250/5000 psi - Tested pipe rams with 4" and 5" pipe. - Pull test plug and install wear bushin 03:15 03:45 0.50 0 0 SURFA DRILL PULD P Install drilling bails on top drive - RU 5" runnin tools 03:45 12:45 9.00 0 0 SURFA DRILL OTHR P Pick up and stand back 189 joints of 5"drill i e 12:45 14:15 1.50 0 0 SURFA RIGMN SVRG P Slip and cut drilling line -Service top drive and drawworks 14:15 14:30 0.25 0 0 SURFA DRILL OTHR P Stand back 4 stands of 5"drill pipe 14:30 17:30 3.00 0 1,872 SURFA DRILL PULD P Pick up Geopilot BHA. Shallow tested tools. 17:30 21:30 4.00 1,872 2,980 SURFA DRILL PULD P RIH picking up 72 Jts. DP from pipe shed. Tested Geo S an. 21:30 22:30 1.00 2,980 3,151 SURFA DRILL REAM P Washed down to TOC @ 3,151'. 22:30 00:00 1.50 3,151 3,155 SURFA CEME~ COCF P Drilled shoe track from 3,151' to 3,155'. 04/13/2007 00:00 01:45 1.75 3,155 3,243 SURFA CEME~ DRLG P Clean out cement, drill out shoe and rathole to 3243' - 600 gpm / 1870 psi / 60 r m 01:45 02:00 0.25 3,243 3,263 SURFA DRILL DDRL P Drill from 3243' to 3263' MD - 2510 TYD 02:00 02:15 0.25 3,263 3,263 SURFA CEME CIRC P Circulate BU for LOT - 500 gpm / 1450 si/50r m 02:15 03:00 0.75 3,263 3,263 SURFA CEME~ FIT P RU and perform PIT -observed LO @ 16.2 ppg EMW - RD and blow down lines 03:00 12:00 9.00 3,263 4,265 INTRM1 DRILL DDRL P Drill 8-3/4" hole w/GP f/ 3263' t/ 4265' MD, 3032' TVD ADT = 5.41 ECD 11.3 WOB = 5/15 K, RPM 150 / 650 GPM / 2040 psi String WT: PU 145 K, SO - 125 K, RW-135K Tor ue OnlOff Btm - 9,000/7,500 ft/Ibs 12:00 00:00 12.00 4,265 5,757 INTRM1 DRILL DDRL P Drill 8-3/4" hole w/GP f/ 4,265' t/ 5,757' MD, 3829' TYD ADT = 6.70 ECD 11.3 WOB = 15/20 K, RPM 150 / 650 GPM / 2410 psi String WT: PU 165 K, SO - 135 K, RW-150K Torque On/Off Btm - 10,500/10,000 ftllbs ~ __ . e ~ ~_ _..~~.~.~ ................~. ~~~ ~ ~~ ~~ 1 C~ Time Logs ~ Date From To _ Dur S Depth E. De th Phase Code Subcode T COM ' 04/14/2007 00:00 12:00 12.00 5,757 7,177 INTRM1 DRILL DDRL P Drill 8-3/4" hole w/GP f/ 5,757' t/ 7,177' MD, 4,596' TVD ADT = 7.57 ECD 11.08 WOB = 15/20 K, RPM 150 / 650 GPM / 2720 psi String WT: PU 213 K, SO - 137 K, RW-166K Torque On/Off Btm - 14,000/12,500 ft/Ibs 12:00 00:00 12.00 7,177 8,604 INTRM1 DRILL DDRL P Drill 8-3/4" hole w/GP f/ 7,177' t/ 8,604' MD, 5,348' TVD ADT = 7.64 ECD 11.1 WOB = 15/20 K, RPM 150 ! 650 GPM / 2640 psi String WT: PU 235 K, SO - 145 K, RW-175K Torque On/Off Btm - 16,500!14,500 ft/Ibs 04/15/2007 00:00 12:00 12.00 8,604 9,954 INTRM1 DRILL DDRL P Drill 8-3/4" hole w/GP f/ 8,604' t/ 9,954' MD, 6,065' TVD ADT = 7.78 ECD 10.92 WOB = 15/20 K, RPM 150 / 650 GPM / 2740 psi String WT: PU 263 K, SO - 150 K, RW-194K Torque On/Off Btm - 18,000/16,000 ft/Ibs 12:00 00:00 12.00 9,954 11,183 INTRM1 DRILL DDRL P Drill 8-3/4" hole w/GP f/ 9,954' t/ 11,183' MD, 6,645' TVD ADT = 7.84 ECD 10.92 WOB = 20/24 K, RPM 140 / 550 GPM / 2170 psi String WT: PU 240 K, SO - 170 K, RW - 175 K Torque On/Off Btm - 18,000/15,500 ft/Ibs 04/16/2007 00:00 10:15 10.25 11,183 12,076 INTRM1 DRILL DDRL P Dril18-3/4" hole w/GP f/ 11,183' U 12,076' MD, 6,850' TVD ADT = 7.43 ECD 11.14 WOB = 20/25 K, RPM 140 / 525 GPM / 2250 psi String WT: PU 250 K, SO - 163 K, RW - 202 K Torque On/Off Btm - 17,000/15,000 ft/Ibs 10:15 12:30 2.25 12,076 11,761 INTRM1 DRILL CIRC P Circulate and condition mud - 600 gpm / 2620 psi / 140 rpm -Set back 1 std/30 min. to 11,761' 12:30 15:30 3.00 11,761 10,145 INTRM1 DRILL TRIP P Wiper trip from 11,761' to 10,145' - 500 gpm / 1930 psi / 120 rpm - no roblems 15:30 16:45 1.25 10,145 12,076 INTRM1 DRILL TRIP P Flow check well, static -Blow down top drive - RIH from 10,145' to 12,047' - precautionarywash and ream from 12,047' to 12,076' ._~~ _ ~~~~ ~ ref 1~ Time Logs ___ Date From To Dur S. De th E. De th Phase Code Subcode T COM 04/16/2007 16:45 18:30 1.75 12,076 12,047 INTRM1 DRILL CIRC P Circulate and condition mud raised MW to 10.2 PPG - 600 gpm ! 2840 psi / 140 r m -Set back 1 std. 18:30 19:15 0.75 12,047 12,047 INTRM1 DRILL CIRC P Checked SPR with new MW. Spotted casin ills to bit. 19:15 23:00 3.75 12,047 9,289 INTRM1 DRILL TRIP P POOH with pump @ 3 BPM spotting casing pills from 12,047' to 10,240'. Continued POOH with um to 9,289'. 23:00 23:30 0.50 9,289 9,289 INTRM1 DRILL CIRC P Observed well. Pumped dry job. Blew down To drive and Geos an. 23:30 00:00 0.50 9,289 9,098 INTRMI DRILL TRIP P POOH on trip tank from 9,289' to 9,098'. 04/17/2007 00:00 08:00 8.00 9,098 808 INTRM1 DRILL TRIP P POOH on trip tank from 9090' to 808'. Flow check shoe static. 08:00 11:00 3.00 808 0 INTRM1 DRILL PULD P Laid down HWDP -Jars - NMFC's -Flt Sub. Plug in & Dwn load -Service GP & Break bit - LD MWD. 11:00 12:00 1.00 0 0 INTRM1 DRILL PULD P LD DP elev. & short bales -Drain stack - CO Junk Sub. 12:00 13:30 1.50 0 0 INTRM1 WELCT OTHR P Changed VBR rams to 7". Set test plug & test rams/doors to 250/5000 psi. Set CSG Wear Ring -Change Saver sub t/ XT-39. 13:30 14:30 1.00 0 0 INTRMI CASINC RURD P RU surface equipment to run 7" Csg - PJSM. 14:30 18:15 3.75 0 3,180 INTRM1 CASINC RNCS P RIH w/ 7" 26# L-80 BTCM Csg t/ 3180' as follows: Ray Oil Tools Silver Bullet FS - 1 jt - Haliburton FC - 74 jts. First 4 jts Baker Loc with centralizers on #1 - 15. 18:15 18:45 0.50 3,180 3,180 INTRM1 CASINC CIRC P Circu Csg Vol -Stage pumps up to 5 bpm @ 310 psi -PUW = 135#, SOW = 125#. 18:45 21:45 3.00 3,180 6,328 INTRM1 CASINC RNCS P Continue RIH w/75jts of 7" 26# L-80 BTCM cs from 3180' to 6328'. 21:45 22:30 0.75 6,328 6,328 INTRM1 CASINC CIRC P CBU -Stage pumps up to 5 bpm @ 540 si -PUW = 195#, SOW = 135#. 22:30 00:00 1.50 6,328 7,169 INTRM1 CASINC RNCS P Continue RIH with 7" csg from 6328' to 7169'. PUW = 225#, SOW = 150#. 04/18/2007 00:00 03:30 3.50 7,169 10,146 INTRM1 CASINC RNCS P Ran 70 Jts 7" 26# L-80 BTCM casing to 10,146'. 03:30 05:00 1.50 10,146 10,146 INTRM1 CASINC CIRC P CBU Staged pumps up to 5 BPM. FCP 510 si. 05:00 07:30 2.50 10,146 12,062 INTRM1 CASINC RNCS P Ran 84 Jts 7" 26# L-80 BTCM casing to 12,025'. Total of 284 Jts ran. Made up landing Jt and Landed casing @ 12,062'. FC @ 11,977 and FS@ 12,060' MD. 07:30 08:15 0.75 12,062 12,062 INTRM1 CASINC RURD P Rigged down Franks tool and RU cement head. 08:15 11:00 2.75 12,062 12,062 INTRM1 CEME~ CIRC P Circulated lowering MW to 9.9 PPG. Staged pumps up to 7.5 BPM. Worked pipe 20' stroke. Up wt 320 K Down wt. 165 K. FCP @ 7.5 BPM 700 si. ~~ ~ ~~~ ~ F~ac~~ £~ t~f 14 ~__ C~ Time Logs _ _ __ _ _ Date Frorn To Dur S. De th E. De th Phase Code Subcode T COM 1 - 04l18/2007 - - 11:00 - - 12:30 1.50 12,062 0 INTRM1 -- CEME DISP P PJSM on cementing -Cemented 7" csg as follows: Pumped 5 bbls CW-100 -Test lines to 3700 psi - Pumped 15 bbls CW-100 @ 3bbls/min @ 180 psi -Mixed & pumped 40 bbls 10.5 ppg MudPush @ 5 bbls/min @ 260 psi -Dropped btm plug -Mixed & pumped 30.23 bbls 15.8. ppg Tail slurry (class G w/ additives) @ 5 bbls/min @ 300 psi -Dropped top plug w/ 20 bbls water f/Dowel! -switched to rig pumps & displaced cmt w/ 438.7 bbls 9.9 ppg LSND mud @ 7.5 bbls./min @ 700 psi for first 420 bbls slowed pumps to 4 bbls/min @ 430 psi for last 18.7 bbls -Bumped plug w/ 930 psi - CIP @ 12:30 hrs. Checked floats OK -Full returns throughout job - Reciprocated pipe for first 420 bbls of displacement -landed pipe when um s were slowed to 4 bbls/min. 12:30 13:30 1.00 0 0 INTRM1 CASIN DHEQ P Rigged up and tested casing to 3,500 si for 30 min. 13:30 15:30 2.00 INTRMI CASIN( RURD P LD Csg Equip, Bales & Land jt. Pull Csg wear ring. FMC set PO and test U5000 si. 15:30 16:30 1.00 INTRM1 WELCT OTHR P Change top set rams from 7" t/ VBR's. 16:30 17:00 0.50 INTRM1 RIGMN SVRG P Service Rig 17:00 19:00 2.00 INTRM1 WELCT OTHR P RU to test 4" Dart & TIW Vlv's, 4.5" Top set BOP Rams & Ram Doors - 250/5000 si. 19:00 20:00 1.00 INTRM1 DRILL OTHR P Install Wear bushing, Short Bails, Elevators. 20:00 00:00 4.00 INTRM1 DRILL OTHR P PJSM - LD 5" DP mouse hole (135 jts) 04/19/2007 00:00 01:45 1.75 0 0 INTRM1 DRILL PULD P PJSM - LD 5"drill pipe from derrick in the mousehole. 01:45 02:30 0.75 0 0 INTRMI DRILL RURD P Picked up SLB surface equipment from i e shed. 02:30 08:00 5.50 0 0 INTRM1 DRILL PULD P Continue to LD 5" DP from derrick in the mousehole. 08:00 11:15 3.25 0 0 INTRM1 DRILL DHEQ P Tested SLB tools in the pipe shed. 11:15 12:00 0.75 0 40 INTRM1 DRILL PULD P Picked up SLB Powerdrive and made u bit. Perform shallow hole test. 12:00 14:30 2.50 40 40 INTRM1 DRILL PULD T Power Drive failed. LD & PU backup power drive. Failed test. Conclude ma netic interference. 14:30 15:15 0.75 40 40 INTRM1 DRILL PULD P PU BHA, MU bit. 15:15 16:00 0.75 40 40 INTRM1 DRILL SFTY P PJSM on installing radioactive material. Install & MU. 16:00 17:00 1.00 40 401 INTRM1 DRILL PULD P Continue with PU BHA. ~~. ~ _~.~ ~ ~, e l~a~~ 7 z~f ~1~ Time Logs f Date From To Dur S De th E_ Depth Phase Code Subcode T COM_______ _ 04/19/2007 17:00 17:30 0.50 401 872 INTRM1 DRILL TRIP P PU 4" DP f/shed f/ 401' t! 872'. 17:30 18:15 0.75 872 872 INTRM1 DRILL OTHR P Shallow test MWD tools -Blow Down TD. 18:15 20:00 1.75 872 2,775 INTRM1 DRILL TRIP P Continue RIH PU 4" DP f/ 872' t/ 2775'. 20:00 21:00 1.00 2,775 2,775 INTRM1 RIGMN SVRG P PJSM -Cut 60' Drilling line. 21:00 00:00 3.00 2,775 6,581 INTRM1 DRILL TRIP P Cont PU 4" DP f/shed. Fill every 20 stds f/ 2775' t/ 6581'. 195 ~ts . 04/20/2007 00:00 05:30 5.50 6,581 11,823 INTRM1 DRILL TRIP P Continue PU 4" DP f/shed. Fill every 20 stds f/ 6581' t/ 11,823'. 05:30 06:30 1.00 11,823 11,972 INTRM1 DRILL DDRL P MU Top Drive, Wash & Ream to FC @ 11,972'. Estimated TOC @ 11,930'. 230 GPM, 60 RPM. 06:30 08:45 2.25 11,972 11,973 INTRM1 DRILL DDRL P Drill through Float Collar. 08:45 09:45 1.00 11,972 12,059 INTRMI DRILL DDRL P Clean out shoe track dwn to FS @ 12,059'. 09:45 10:30 0.75 12,059 12,061 INTRM1 DRILL DDRL P Drill through Float Shoe. 10:30 11:00 0.50 12,061 12,096 INTRM1 DRILL DDRL P Wash dwn to 12,076'. Drill 20' new hole to 12,096'. ADT = 0.17 WOB = 7/12 K, RPM 60 / GPM 231 / 2100 psi String WT: PU 215 K, SO - 135 K, RW-172K Torque On/Off Btm - 14,000/13,000 fUlbs 11:00 12:00 1.00 12,096 12,059 INTRM1 DRILL OTHR P CBU -Pull up into csg & blow down TD. 12:00 12:45 0.75 12,059 12,059 INTRM1 DRILL OTHR P RU & Perform LOT to 11.7 ppg -Rig Down. 12:45 14:30 1.75 12,059 12,059 PROD1 DRILL CIRC P Displace mud with 8.9 ppg Flo-pro. 14:30 00:00 9.50 12,059 12,790 PROD1 DRILL DDRL P Drill 6-1/8" hole w/Periscope f/ 12,096' t/ 12,790' MD - 6,828' TVD ADT = 6.68 ECD 10.64 WOB = 5/8 K, RPM 120 / 231 GPM / 2110 psi String WT: PU 208 K, SO - 140 K, RW-171 K Torque On/Off Btm - 14,000/12,500 ft/Ibs 04/21/2007 00:00 12:00 12.00 12,790 13,642 PROD1 DRILL DDRL P Drill 6-1/8" hole w/ SLB PowerDrive w/Periscope f/ 12,790' t/ 13,642' MD - 6,821' TVD ADT = 8.36 ECD 10.64 WOB = 7/12 K, RPM 120 / 220 GPM / 2150 psi String WT: PU 215 K, SO - 137 K, RW - 172 K Torque On/Off Btm - 15,000/12,500 ft/Ibs ~ mm Pac;~ i3 taf 1~ • Time Logs ~ Date From To Dur ___S Depth E. Depth Phase Code Subcode T COM____ j 04/22/2007 20:30 00:00 3.50 401 0 PROD1 DRILL PULD X PJSM - SB HWDP & NMFC -Remove RA source & LD tool - CO BHA -SLB MWD Plu in to u load/download. 04/23/2007 00:00 00:45 0.75 0 170 PROD1 DRILL PULD X Uploaded MWD & Calibrate depth for SLB tools. Made up Bit, NMFC's, (Pulled corrosion ring), HWDP, and Jars. 00:45 01:00 0.25 170 170 PROD1 RIGMN SVRG P RIH w/1 std 4" DP -Serviced top drive and function tested ann, top & btm rams. 01:00 02:15 1.25 170 2,275 PROD1 DRILL TRIP X RIH to 2275' -fill pipe -shallow tested tools. 02:15 08:45 6.50 2,275 13,832 PROD1 DRILL TRIP X RIH to 13,832' filling pipe every 20' stds. MU TD. 08:45 09:30 0.75 13,832 13,850 PROD1 DRILL TRIP X FiII pipe -Wash down & ream to 13,850'. Survey & Download data to tool. 09:30 14:00 4.50 13,850 13,880 PROD1 DRILL KOST X Trenching per DD f/ 13,850' t/ 13,880'. 231 GPM, 130 RPM. String Wt: PU 210 - SO 142 -Rot - 172 14:00 00:00 10.00 13,880 13,900 PROD1 DRILL KOST X ** Kickoff for Sidetrack @ 13,880'.*" Time Drill 6-1/8" hole w/SLB PowerDrive/Persicope f/ 13,880' U 13,900' TVD = 6.819' ADT = 7.4 hrs ECD = 1022 WOB = 0/3 K, RPM 130 / 231 GPM / 1920 psi String WT: PU 210 K, SO - 143 K, RW-172K Torque On/Off Btm - 11,000/11,000 ft/Ibs 04/24/2007 00:00 03:00 3.00 13,900 13,916 PROD1 DRILL DDRL X Time drill f/ 13,900' to 13,916' MD RPM 130 GPM 230 1970 si 03:00 12:00 9.00 13,916 14,277 PROD1 DRILL DDRL X Drill 6 1/8" horizontal section w/ PD/periscope f/ 13,916' to 14,277' MD 6803' TVD ADT - 8.15 hrs. ECD - 10.64 ppg WOB 5/10 RPM 120 GPM 230 @ 2060 psi String wt. PU 220 SO 130 Rot 172 Torque on/off btm. -14,500 / 12,500 ft Ibs 12:00 12:30 0.50 14,277 14,294 PROD1 DRILL DDRL X Drill 6 1/8" horizontal section w/ PDlperiscope f/ 14,277' to 14,294' MD 6804' TVD ADT - .5 hrs ECD - 10.65 ppg WOB 5/10 k RPM 120 GPM 231 @ 2060 psi String wt. PU 210 RPM 120 Rot 172 Torque on/off btm. - 14,500/ 12,500 ft/Ibs. ~ i Time Loos Date From To Dur S. De th E. De th Phase Code Subcode T COM 04/24/2007 12:30 00:00 11.50 14,294 14,900 PROD1 DRILL DDRL P Drill 6 1/8" horizontal section f/ 14,294' to 14,900' MD 6788' TVD ADT 7.75 hrs ECD 19.77 ppg WOB 7/12 k RPM 120 GPM 223 @ 2100 psi String wt. PU 217 SO 120 Rot 168 Torque on/off btm. - 15,500/13/500 ft/Ibs 04/25/2007 00:00 04:45 4.75 14,900 15,140 PROD1 DRILL DDRL P Drill 6 1/8" horizontal section f/ 14,900' to 15,140' MD 6774' TVD ADT - 4.44 hrs ECD - 10.65 ppg WOB 10/15 k RPM 120 GPM 230 @ 2170 psi String wt. PU 215 SO 130 Rot 170 Torque on/off btm. - 14,500/11,500 fUlbs 04:45 07:00 2.25 15,140 14,661 PROD1 DRILL TRIP P POOH f/ 15,140' to 14,900' w/ pump - Circ for trip 210 gpm @ 1910 psi w/ 100 rpm -Std back 1 std every 30 mins. to 14,661' loss rate up to 60 bbls/hr -Spot 35 bbl LCM pill @ 14,661' 07:00 09:15 2.25 14,661 13,330 PROD1 DRILL TRIP P POOH backreaming w/ pump f/ 14,661' to 13,330' - 200 gpm @ 1770 siw/90r m 09:15 11:00 1.75 13,330 13,125 PROD1 DRILL TRIP P Mad pass f/ 13,330'to 13,125' @ 200'/hr w/ 200 gpm @ 1720 psi w/ 120 m 11:00 12:00 1.00 13,125 12,994 PROD1 DRILL TRIP P Continue POOH backreaming w/ pump f/ 13,125' to 12,994' w/ 200 gom @ 1710 psi w/ 90 rpm Lost 131 bbls FloPro ast 12 hrs. 12:00 15:00 3.00 12,994 11,990 PROD1 DRILL TRIP P Continue POOH backreaming w/ pump f! 12,994' to 11,990' w/ 200 gpm @ 1600 psi w/ 90 rpm -Made Mad pass f/ 12,435' to 12,100' 200'/hr 15:00 16:30 1.50 11,990 11,990 PROD1 DRILL OTHR P Flow check well @ 7" csg -static - monitorwell for static loss rate for 15 mins. No static loss - Circ btms up 202 gpm 1630 psi w/ 50 rpm -Hole clean on btms u shakers 16:30 17:00 0.50 11,990 11,513 PROD1 DRILL TRIP P Flow check well -static -POOH with um 3 b m, 740 si to 11,513'. 17:00 19:00 2.00 11,513 11,513 PROD1 DRILL CIRC P Flow check well -static - PJSM. Displace well with 9.2 ppg Brine @ 202 GPM, 50 RPM, 1380 si. 19:00 00:00 5.00 11,513 4,843 PROD1 DRILL TRIP P Flow check well after 9.2 brine circulated -static. Blow down TD and POOH on TT f! 11,513' t/ 4,843. 04/26/2007 00:00 01:30 1.50 4,843 377 PROD1 DRILL TRIP P Continue to POOH on TT f/ 4843' to 377' 01:30 03:00 1.50 377 0 PROD1 DRILL PULD P Std. back jars & HWDP - LD MWD/Perisco a/Power Drive 03:00 04:15 1.25 0 0 COMPZ DRILL OTHR P Clear floor (housekeeping) RU to run liner - PJMS Time Logs Date From To Dur S De th E De th Phase Code Subcode T COM 04/26/2007 04:15 07:30 3.25 0 3,200 COMPZ CASINC RUNL P Run 4 1/2" 12.6# L-80 SLHT Slotted/blank liner as follows: Baker V set shoe - 1 jt slot - 5 jts. blank - 1 jt. slot - 2 jts. blank - 9 jts. slot - 3 jts. blank - 2 jts, slot - 3 jts. blank - 50 jts. slot - 4 'ts. blank 07:30 08:00 0.50 3,200 3,200 COMPZ CASIN RUNL P MU liner hanger assembly -Mix & s of Pal Mix 08:00 08:30 0.50 3,200 3,200 COMPZ CASINC RUNL P MU XO - RIH w/ 1 std DP -Break circ 08:30 13:30 5.00 3,200 12,005 COMPZ CASINC RUNL P RIH w/ liner on 4" DP to 12,005' (56' f! 7" shoe - PU wt 200 SO wt. 150 13:30 14:00 0.50 12,005 12,005 COMPZ CASINC CIRC P Pump DP volume 4 BBLSlmin @ 420 si -Blow DownTD 14:00 16:00 2.00 12,005 15,125 COMPZ CASINC RUNL P Continue RIH w/ liner f/ 12,005' to 15,125'. U wt 225, Dwn wt 140. 16:00 17:00 1.00 15,125 15,125 COMPZ CASINC OTHR P Drop setting ball & pump to seat - Pressure up to 2000 psi to set liner hanger -Increase pressure to 3000 psi to Set Packer -Increase to 4000 psi to release from liner. 17:00 18:00 1.00 15,125 15,087 COMPZ CASINC DHEO P Rig up & test annulus to 3500 psi for 30 min. Blow dwn choke & kill. POOH to 15,087'. 18:00 19:30 1.50 15,087 15,087 COMPZ CASINC CIRC P PJSM -Spot 27 bbls Inhbited brine from liner top to _ 10,700' @ 2 bpm, 130 si. Flow check well static. 19:30 00:00 4.50 15,087 1,450 COMPZ RPCOh TRIP P POOH on TT from 15,087' to 1,450'. 04/27/2007 00:00 00:30 0.50 1,450 0 COMPZ RPCOti TRIP P Continue POOH on TT from 1,450 t/ surface 00:30 01:00 0.50 0 COMPZ RPCOh PULD P Change out elevators to 3-1/2" - LD Baker settin tools. 01:00 01:15 0.25 COMPZ RPCOh OWFF P Loss while POOH w/ TT of 4 bph. Monitor well -Observe fluid loss. 01:15 01:30 0.25 COMPZ RPCOh OTHR P Pull wear ring -Drain stack. 01:30 07:30 6.00 COMPZ WELCT BOPE P Set test plug - RU and run hole fill to annulus while testing BOPE. Test BOPE with 4-1/2" TJ. Ann Preventer 250 psi low / 3500 psi high. All other tests 250 psi low / 5000 psi high. Tested Manifold valves #1 - 16, Auto & Manual IBOP, Manual choke & kill, HCR choke & kill, Top & Btm Pipe rams, Blind rams, Dart & TIW valves (XT-39), Blow Dwn. Derrick Inspection com leted Burin testin . 07:30 09:00 1.50 COMPZ RIGMN' SVRG P Keep hole full on TT - CO Elevators to 4". RIH with 1 std to MU TD. PJSM to cut & slip DL (double cut). Serviced TD. 09:00 14:00 5.00 COMPZ RPCOh OTHR P LD 4" DP via mousehole WO service hand due to weather. 14:00 14:30 0.50 COMPZ RPCOh PULD P RU to run 4-1/2" Tbg ~. ~~® ~ ~ ~ ~ m. .--_~ g ~~acg~ 1 ~ rz` 14 i • Time Logs _ ._ _ __ __ Data From To Du_r_____,S De th E_ Depth Phase Code__ _Subcode T COM - -- _ ~ 04/27/2007 14:30 14:45 0.25 COMPZ RPCOh SFTY P PJSM to discuss RIH w/ 4-1 /2" Tbg 14:45 23:00 8.25 0 9,576 COMPZ RPCOh RCST P RIH with Upper Completion 4-1/2" 12.6# L-80 IBTM Tbg as follows: Baker Bullet Seal Assembly w/locator and WLEG assembly - pup jt - 26 jts tbg - XN Npl - 2 jts - pup jt -Camco 4-1/2" GLM w/3000 psi annular SOV - pup jt - 36 jts tbg - pup jt -Camco 4-1/2" GLM w/DV - pup jt - 108 jts - pup jt - Camco GLM w/DV - pup jt - 65 jts tbg - pup jt - 4-1 /2" Camco BAL-O Npl w/Dumm PO 2.5" ID . 23:00 00:00 1.00 9,576 9,576 COMPZ RPCOh OTHR P PU Camco Bal-O Npl - MU Dual control lines, purge w/hydraulic fluid & test. 04/28/2007 00:00 00:15 0.25 9,576 9,576 COMPZ RPCOh RCST P MU control lines to SSSV -Test lines to 5000 si 00:15 04:30 4.25 9,576 11,847 COMPZ RPCOh RCST P Continue running 4 1/2" completion f/ 9576' to 11847' -Space out w/ 1 jt tbg & 1 std 4" DP -Confirm seal assembly into seal bore while idling um - 04:30 06:00 1.50 11,847 11,847 COMPZ RPCO CIRC P Pull back to above liner top -Spot 40 bbls 9.2 inhibited brine 06:00 08:00 2.00 11,847 11,883 COMPZ RPCOti RCST P Pull out & std back 1 std 4" DP & 1 jt. 4 1/2" tbg used for space out - PU pup jt - 2 jts 4 1/2" tbg - MU tbg hanger- MU control & balance lines through hanger & test connections -Land tbg w/ tail @ 11,894.79' -Locator spaced @ 2.18' above liner top -Top of liner @ 11,882.60'. Total of 293 jts ran and 63 bands used for dual CL. 08:00 09:30 1.50 0 0 COMPZ RPCOh OTHR P RILDS - LD landing jt. A -Set TWC - MU landing jt. B -Rig & attempt to test hanger seals (metal to metal) - Han er seals failed to test 09:30 15:00 5.50 COMPZ RPCOh OTHR T BOLD - LD landing jt B -Pull TWC - MU Landing Jt A -Attempt to pull hanger -Well back flowing out of tbg - MU TD -Observed well -Fluid dropping in annulus -Mix & pump dry job -Pull out & change out tbg hanger ( elstemer seals) -reconnect control & balance lines & test to 5000 psi - Reland tbg - RILD - LD landing jt A - set TWC -- MU Landing jt B - RU & test hanger seals to 5000 psi OK - LD landin 't B 15:00 15:30 0.50 COMPZ RPCOh OTHR P LD tbg equipment & perform house kee in on ri floor. 15:30 17:00 1.50 COMPZ RPCOI~ NUND P PJSM - ND BOPE - CO Svr Sub to 4-1/2" IF 17:00 20:00 3.00 COMPZ RPCO6 OTHR P NU Tree & test to 5000 psi. Test Camco Balance & Control lines to 5000 si -bleed down to 0 si. • _' Time Logs Date From To Dur S De th E. De th Phase Code Subcode T COM 04/28/2007 20:00 21:15 1.25 COMPZ RPCOh OTHR P MU Lubricator & FMC pull TWC. Drop Ball & Rod. RU Hardline. 21:15 21:30 0.25 COMPZ RPCOh SFTY P PJSM to discuss pressure test & um in schedule. 21:30 22:45 1.25 COMPZ RPCOI~ DHEQ P Test lines to 4000 psi.- Pressure up tbg to 3500 psi & test for 30 mins - Bled tbg to 2000 psi -Pressure up on 4 1/2" x 7"annulus to 3500 psi & test for 30 mins. - Bled Annulus to 0 psi, Bled Tb to 0 si. 22:45 00:00 1.25 COMPZ RPCOh CIRC P Pump down annulus and sheared valve @ 3150 psi. Tbg came up to 200 psi.- Line up to tbg -pump down tbg through shear valve in GLM w/ 9.2 ppg inhibited brine taking returns form annulus to its 04/29/2007 00:00 01:30 1.50 0 0 COMPZ RPCOh FRZP P Dowell pumped 176 BBLS of 9.2 ppg Inhibited Brine @ 4.5 bpm 2000 psi followed b 193 BBLS of diesel FP. 01:30 03:30 2.00 0 COMPZ RPCOh OTHR P Blow down lines - RD hard lines, manifold, and clear rig floor. FMC PU Lubricator & set BPV. Secure well. 03:30 16:00 12.50 COMPZ DRILL PULD P PJSM - LD 4" DP from Derrick via mousehole to shed. 16:00 17:00 1.00 DEMOB MOVE DMOB P Prep for move to CD2. Rig released @ 1700 hrs. _ e® ~ ~~~ fa of 1~4._) i r „ . . Liner Detail ~~~ I~~Q~1 1~~~~ 4 1/2" Slotfecf and Blank L/ner Well: CD3-301 Date: 4!25/2007 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Top of Liner Hanger @ 11882.60 Seal Bore Extension 16.27 11882.60 Baker "HRD" ZXP Liner Top Packer w/ HD 9.55 11898.87 Baker "DG" 5" x 7" Flex Lock Hanger. 5.92 OD x 4.40 lD 5.37 11908.42 Pup - 4-1/2", 12.6#, L-80, 4 1/2" Hyril 521 pin 4.55 11913.79 XO - 41/2" Hydril 521 box x SLHT pin 1.73 11918.34 Jts 77 to 80 4 Jts 4-1/2", 12.6#, L-80, SLHT BLANK PIPE 161.52 11920.07 Jts 27 to 76 50 Jts 4-1/2", 12.6#, L-80, SLHT SLOTTED LINER 1991:73 12081.59 Jts 24 to 26 3 Jts 4-1/2", 12.6#, L-80, SLHT BLANK PIPE 122.41 14073.32 Jts 22 to 23 2 Jts 4 1/2" 12.6# L-80 SLHT SLOTTED LINER 80.04 14195.73 Jts 19 to 21 3 Jts 4 1/2" 12.6# L-80 SLHT BLANK LINER 119.31 14275.77 Jts 10 to 18 9 Jts 4 1/2" 12.6# L-80 SLHT SLOTTED LINER 360.57 14395.08 Jts 8 to 9 2 Jts 4 1/2" 12.6# L-80 SLHT BLANK LINER 79.93 ~ 14755.65 Jts 7 to 7 1° Jts 4 1/Z" 12.6# L-80 SLHT SLOTTED LINER 40.00 14835.58 Jts 2 to 6 5 Jts 4 1/2" 12.6# L-80 SLHT BLANK LINER 201.64 14875.58 Jts 1 1 Jts 4 112" 12.6# L-80 SLHT SLOTTED LINER 41.70 15077.22 Baker V set shoe 1.80 15118.92 41/2" liner shoe @ 15120.72 7" csg shoe @ 12,062' ___ TD of 6 1/8''.hole =15;140.00' Remarks: Run-N-Seat pipe dope Up Wt -230 k Dn Wt -140 k Supervisors: D. Mickey / N. Woods • • __ . ALPINE ~ ~. { ~ Canac~sPhillps Alaskal, Irnc. GD3-301 _ _ APL 501032054300 __ _ _ Well L e: PROD TUBING SSSV Type: WRDP Orig 4/29/2007 (32-11895, Com letion: OD:4.5o0, Annular Fluid: Last W/O: ID:3.958) ~. _ ~ ~ Reference L 36' RKB Ref L Date: Last Ta : TD: 15122 ftK6 Last Tag Date' Max Hole Angle: 0 deg r? Casing String -ALL STRINGS ,;, ,.. ~~escription ~ Size ~ Top ~ Bottom ~ 1 LOCATOR (1167x-11880, OD:5.750) PACKER (11899-110, OD:6.540) CD3-301 TS: C/O, Pull Ball & Rod I LINER SLOTTED 4.500 I 11883 I 15122 I 15122 I 12 RO I L-80 I SLHT ~: - . __ - - Tubing Strin -TUBING ---- ; .. Size To Bottom TVD 1IUt Grade Thread ~ ' 4.500 32 _11895 11895 12.60 L-80 IBTM Perforations Summary Interval TVD Zone Status Ft 5P F Date T e Comment 12081 -14073 12081 - 14073 1992 32 4/25/2007 SLOTS Alternating slotted/solid °~ i e, slots 2 1/4" x 1/8" 14196 - 14276 14196 - 14276 80 32 4/25/2007 SLOTS Alternating slotted/solid ! i e, slots 2 1/4" x 1/8" ~ 14395 - 14756 14395 -14756 361 32 4/25/2007 SLOTS Altemating slotted/solid i e, slots 2 1/4" x 1/8" ' ; `: 14836 - 14876 14836 - 14876 40 32 4/25/2007 SLOTS Altemating slotted/solid i e, slots 2 1/4" x 1/8" - - 15077 - 15119 15077 - 15119 42 32 4/25/2007 SLOTS Alternating slotted/solid pipe. slots 2 1/4" x 1/8" iGas Lift Mandrels/Valves St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Mfr Run Cmnt 1 4926 4926 CAMCO KBG-2 GLV 1.0 BK-5 0.250 2201 4/29/2007 ~ ~ ( 2 9263 9263 CAMCO KBG-2 GLV 1.0 BK-5 0.250 2208 4/29/2007 3 10732 10732 CAMGO KBG-2 OV LO BEK 0.438 0 4/29/2007 Other (plugs, equip., etc.) -COMPLETION ~~ De th TVD T 3 DeSCri tion ID 31 31 HANGER FMC TUBING HANGER 4.500 ~ ~ 2306 2306 SSSV BAL-O NIPPLE w/4.5"WRDP-2 S/N HSS-1984/30/2007 2.125 10828 10828 NIP HES XN NIPPLE 3.725 11879 11879 LOCATOR BAKER LOCATOR 0.000 I I 11880 11880 WLEG/ SEAL WLEG w/SEALS ASSEMBLY "EXTENDS 12' INTO SLOTTED LINER" 3.940 I I I ,L 1 1 Other I mss, equip., etc.) -LINER DETAIL De th TVD T e Descri tion ID 11899 11899 PACKER BAKER'HRD' ZXP LINER TOP PACKER 4.970 11908 11908 HANGER BAKER'DG' FLEX LOCK HANGER 4.400 15119 15119 SHOE BAKER SHOE 3.958 ~ - Re: FW: CD3-301 sidetrack ~ i Subject: Re: FW: CD3-301 sidetrack From: Thotr~as Maunder <tom_maunder~admin.state.ak.tts> Date: Tue, 24 Apr 2007 07:32:44 -0800 To: ".fohi~son. Fern" ~~ ~"er~~.J~~hns~~nc"u>,canocop~illips.eom=~ Vern, Thanks for the plot. Your proposed naming convention is correct. Call or message with any questions. Tom Maunder, PE AOGCC Johnson, Vern wrote, On 4/24/2007 7:23 AM: ~~~ - Tom- this was the original message. When I created the PDF, it automatically added the word "visio" to .the file name. Let me know if your are unable to read the file. Vern -----Original Message----- *From: * Johnson, Vern *Sent: * Monday, April 23, 2007 3:45 PM *To: * 'Thomas Maunder' *Cc: * Alvord, Chip; Noel, Brian; Galiunas, Elizabeth C; Steve Davies *Subject: * CD3-301 sidetrack Tom, We made the decision yesterday to open hole sidetrack CD3-301, the well currently being drilled with Doyon 19. We drilled out of zone and were not able to get back into quality Kuparuk sand, so the drilling assembly was tripped for a new rotary steerable tool and a new bit. Please see the attached schematic which provides details on the depths of the well. Since we plan to run a slotted liner in the lateral, the "abandoned" section of the hole will not be lined and hence prone to collapse. I propose we call the "abandoned" section CD3-301PB1 with API suffix 70, and the hole that we continue to drill today be called CD3-301 api -00. Call me when you get a chance and we can discuss. Vern «Visio-CD3-301 well naming tenative.pdf» 1 of 1 4/24/2007 7:33 AM CD3-301 Proposed Namina ~b~-~~~ VTJ 04/23/07 9-5/8" Casing 3423' MD Drilled, surveyed & logged by Sperry Drilling Services Drilled, surveyed & logged by Schlumberger Drilling and Measurements 7" Casing 12062' MD Sidetrack point TD CD3-301 P61 +/-13880' MD 14294' MD API -70 04/23/2007 04(22(2007 TD CD3-301 Proposed +/-15000' MD API -00 04hoc/2007 Plugging Not Necessary for the Qannik Interval in CD3-301 • i Subject: Plubging Not Necessaryfor the Qannik Interval in CD3-301 From:. Stephen Davies <steve_davies@admin.state.ak.us> Date: Mon, I6 Apr 2007 ] 5:49:35 -0900 ~~~ °-~ ~-.~ To: "Knock, Dou~~l~is G" -~~lou~~.knock~rrcotlocophillips.co~7~.-:. C'C: "Johnson, `ern" Vern..lohnsonruconocophiilips.cum=~, "~1~ie5s, .IC)RU~~N F'. <-JOR[~~~N.F ~~~'ie.ss~~t~conocohhillips.com ~. tom i7~aun~ier<<~'a~lmin.state.ak.u Doug, The hydrocarbon-bearing zones are sufficiently thin and the hole angle of 58 degrees is sufficiently small to make plugging unnecessary for the Qannik interval of CRU CD3-301. Please call me if you have any questions or need additional information. Steve Davies AOGCC 793-1224 Knock, Douglas G wrote: «cd3-301 _gannik.ppt» Steve, Attached is the log model evaluation of the Qannik interval in the CD3-301 well we are now drilling. Total net pay is 4.2 feet and is broken into 1.8 feet of pay in the upper lobe and 2.4 feet in the lower lobe. Similar to most of the offset wells, a calcite cemented interval reduces pay in the upper lobe. We view 5 feet of continuous or near continuous pay as a development minimum and therefore would opt not to cement the Qannik in CD3-301. Thanks for your prompt response. Doug Knock 1 of 1 4/16/2007 4:02 PM C D3-301 Log model cutoffs: Sw <= 55 Phit >= 18 Netpay = 4.2 ft Upper lobe = 1.8 ft Lower lobe = 2.4 ft • ~7 ~yt~~T n~ ~r~+ ~y Chip Alvord WNS Drilling Team Lead ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, AK 99510-0360 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Colville River Field, Fiord Oil Pool, CRU CD3-301 ConocoPhillips (Alaska), Inc. Permit No: 207-023 Surface Location: 3897' FNL, 680' FEL, Sec. 5, T12N, RSE, UM Bottomhole Location: 3876' FNL, 5073' FEL, Sec. 28, T13N, RSE, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval 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. The decision as to whether or not the Qannik sandstone contains a significant hydrocarbon accumulation that must be cemented per 20 AAC 25.030(d)(5) must be made in conjunction with AOGCC technical staff. When logging information is available, please have your engineer contact the Commission. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authori.~es 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). / ~Zar~l~ !~-~ DATED this fJ day of~~e~.r~, 2007 • SARAH PALIAI, CsOVERAIOR cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ ~ RECEIVED STATE OE ALASKA I~ FEB 1 4.2007 ALASKA OIL AND GAS CONSERVATION COMMISSION ~ PERMIT TO DRILL ~l~~Alaska Oil & Gas Cons. Commission 20 AAC 25.005 Anchorage 1 a. Type of Work: Drill /^ Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil 0 Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone ^ Single Zone Q 1 c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: CD3-301 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 14862' ND: 681 T `` 12. Field/Pool(s): Colville River Field 4a. Location of Well (Governmental Section): Surface: 3897` FNL, 680' FEL, Sec 5, T12N, R5E, UM 7. Property Designation: ADL 372105, 364472, 364471 Fiord Oil Pool Top of Productive Horizon: 248' FNL, 2179' FEL Sec 32, T13N; R5E; UM 8. Land Use Permit: LAS2112 13. Approximate Spud Date: 311!2007 Total Depth: 3876' FNL, 5073' FEL SeC28, T13N, R5E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 16,000' from CRU Boundry - 4b. Location of Well (State Base Plane Coordinates): Surface: x- 388363.67 y- 6003874.1 Zone- 4 10. KB Elevation (Height above GL): 37' RKB feet 15. Distance to Nearest Well within Pool: Fiord 5: 1429' at 13836' MD , 16. Deviated wells: Kickoff depth: 300' ft. Maximum Hole Angle: 90° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC zs.os5) Downhole: 3084 psig - Surface: 2402 psig ' 18. Casing Program S ecifications Setting Depth Quantity of Cement Size p Top Bottom c. f, or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 24" 16" 62.5# H-40 Welded 77 37 37 114 114' pre-installed 12.25" 9-5,`8" 40# L-80 BTC 2998 37 37 3035 2500 552 ASL & 230 sx 15.8 ppg 8.75" 7" 26# L-80 BTCM 11927 37 37 11964 6816 306 sx 15.8G & 168 sk 15.8G for Qannik 6.125" 4.5" 12.6# L-80 IBTM 11769 32 32 11801 6799 Tbg 6.125" 4.5" 12.6# L-80 IBTM 3052 11801 6799 14853 6817 SiottedlBlank Liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^ BOP Sketch^ Drilling Program^ Time v. Depth f^ Shallow Hazard Analysis Q Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Progr ~ 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact L. Galiunas Printed Name C. Alvord Title WNS Drilling Team Lead Signature ~ Phane ZGS_G IZa Date L ~(~~~7 1 Commission Use Only a Permit to Drill Number: Zd7 Q 2,~ API Num/ber: 2 50- / 0,,,,7 ~~Sy,'~'QQ Permit Approval Date: t . O See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: ~r~ Samples req'd: Yes ^ No ~ log req'd: Yes ^ No [+~ Other: 35C~C.~ QS~ r-.i ~\ ~vwL ~7V R ~.~-- H2S measures: Yes ^ No ^v' Direction req'd: Yes [vYNo ^ ~~v~~~.~~:.v~ ao~~~as.c~~5 C~.~C~-> Q HE COMMISSION DATE: e.7~~~~ MISSIONER • • ConocoPhillips Alaska, Inc. Post Office Box 100360 ~~ Anchorage, Alaska 99510-0360 ~QI'1QCQ~'1~~~~~JS Telephone 907-276-1215 February 9, 2007 EDEIVED Alaska Oil and Gas Conservation Commission 333 West 7tn Avenue, Suite 100 F~~ 1 4 2007 Anchorage, Alaska 99501 Alaska Oil & Gas Cons, Commission Re: Application for Permit to Drill CD3-301 Anchorage Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore producer well from the Fiord CD3 drilling pad. The intended spud date for this well is 3-1-2007 It is intended that Doyon Rig 19 be used to drill the well CD3-301 will be drilled to penetrate the Kuparuk reservoir horizontally. After setting 7" intermediate casing, the horizontal section will be drilled and the well completed as slotted liner producer. At the end of the rig work program, the well will be flowed back to mitigate reservoir damage. The well will then be hooked up to begin production. _ If the Qannik interval is interpreted as a significant hydrocarbon bearing zone., it will be isolated with cement after setting 7" casing with the use of a stage tool. Current evidence indicates that the gas migration on CD3-107 is not from the C30 (but another formation below the C30), therefore a waiver for the diverter requirement is requested. This will be the Stn well on the Fiord pad and there has been no indication of gas or shallow gas hydrates while drilling surface. -~ ~~"~ 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. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program. 4. A proposed completion diagram. 5. A drilling fluids prograrn summary. 6. Pressure information as required by 20 ACC 25.035 (d)(2). 7. Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the 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 2~i.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Riser setup If you have any questions or require further information, please contact Liz Galiunas at 265- 6247, or Chip Alvord at 265-6120. • Sincerely, Liz Galiunas Drilling Engineer Attachments cc: CD3-301 Well File /Sharon Allsup Drake Chip Alvord Liz Gaiiunas Vern Johnson Jack Walker Jordan Wiess Lanston Chin ATO 1530 ATO 1577 ATO 1704 ATO 1702 ATO 1740 ATO-1782 Kuukpik Corporation • • • CD3-301 Drilling Hazards Summary (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1 /4" Hole / 9-5/8" Casin Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuous) durin interval. Well Collision Low G ro sin le shots, travelin c tinder dia rams Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Increased mud weight Surface Formations >2000' ND Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low densi cement slurries 8-3/4" Hole / 7" Casin Interval Event Risk Level Miti ation Strate Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations Check for flow during connections and if needed, >2000' TVD increase mud wei ht. 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, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. Abnormal Reservoir low Well control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low HZS drills, detection systems, alarms, standard well control ractices, mud scaven ers 6-1 /8" Hole /Horizontal Production Hole Event Risk Level Miti ation Strate Lost circulation moderate 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 ORIGINAL Fiord: CD3-301 Procedure 1. Move on Doyon 19. ~ • 2. Rig up riser, dewater cellar as needed. 3. Drill 12-'/<" hole to the surface casing point as per the directional plan. (Directional/MWD). 4. Run and cement 9-5/8" surface casing. 5. Install and test BOPE to 5000 psi. 6. Pressure test casing to 2500 psi. 7. Drill out 20' of new hole. Perform leak off test. 8. Pick up and run in hole with 8-3/4" drilling BHA. 9. Drill 8-3/4" hole to intermediate casing point in the Kuparuk reservoir sand. (LWD Program: GR/RES/PWD) 10. Run and cement 7" casing as per program. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 11. ROPE test to 5000 psi. 12. Displace well to Flo-pro drilling mud. 13. Pick up 6-1/8" drilling assembly. 14. Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD). 15. Circulate the hole clean and pull out of hole. 16. Run lower completion with slotted liner, liner hanger, and liner top packer. Set hanger. and packer and pull out of the hole. 17. Run 4-'/2, 12.6#, L-80 IBT Mod tubing with DB Nipple, gas lift mandrels, XN nipple, and seal assembly. Sting into seal bore assembly, space out, land hanger. 18. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 19. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 20. Drop ball and test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. Shear out shear valve in bottom GLM to circulate tubing to diesel to freeze protect the well. 21. Set BPV and secure well. Move rig off. ~RI~INAL C Well Proximity Risks: • Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD3-301 is the nearest to the CD3-302PB1/PB2 with 13.9' well to well separation at 547.8' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Kuparuk reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumpina Operations: Incidental fluids developed from drilling operations on well CD3-301 will be injected into a permitted annulus on CD3 or the class 2 disposal well on CD1 pad. The CD3-301 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 1500' TVD. The known significant hydrocarbon zones are the Kuparuk reservoir. There will be more than 500' of cement fill above the top of the Kuparuk per regulations. If the Qannik interval is determined to be significant, it will be isolated with cement as well. Upon completion of CD3-301 form 10-403, Application for Sundry Operations -Annular Disposal, will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 9-5/8" 40 L-80 3 BTC-Mod 3090 psi 2626 psi 5750 psi 4888 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4.599 psi 7,240 psi 6,154 psi nRIG!NAL • • DRILLING FLUID PROGRAM SPUD to 9-5/8"surface casing oint -12 %4' Intermediate hole to 7" casing point - 8'/z" Production Hole Section - 6 1/8" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.0-9.3 ppg PV 10 - 25 10 -15 YP 20 - 60 15 - 25 25 - 30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 - 15 10 minute gels <18 12 - 20 API Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 8.5 - 9.0 9.0 - 10.0 9.0 - 9.5 KC L 6 Surface Hole: A standard high viscosity fresh water /gel spud mud is recommended for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel /polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section The horizontal production interval will be drilled with a M-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with ± 30PPB calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. ORIGINAL • CD3 - 301 Fiord Kuparuk Revised Producer Completion 2-13-07 16" Insulated Conductor to 114' 4'/2' 12.6 ppf L-80 IBT Mod Tubing 3.813" DB Landing Nipple 9-5/8" 40 ppf L-80 BTCM Surface Casing 3223' MD / 2500' TVD Cement to +/- 5765' 1 MD / 3846' TVD Qannik interval top +/- 6265' MD / 4111' TVD Stage cementing too' +/- 6803' MD / 4396' TVD Top of cement \ 10360' MD / 6280' TVD Top Reservoir at +/- Kuparuk 11937' MD / 6814' TVD Sperry Sun Directional Plan WP8 01/17/07 Upp er Completion: Top MD ND Item 1) Tubing Hanger 32' 32' 2) 4-%' 12.6 #/ft IBT-Mod Tubing 3) Camco DB nipple (3.813") 2284' 2000' 4) 4-%z' 12.6 #/ft IBT-Mod Tubing 5) Camco KBG-2 GLM (DRIFT ID 3.833") 4922' 3400' 6) 4-'/" 12.6 #/ft IBT-Mod Tubing 7) Camco KBG-2 GLM (DRIFT ID 3.833") 9265' 5700' 8) 4-'/" 12.6 #lft IBT-Mod Tubing 9) Camco KBG-2 GLM (DRIFT ID 3.833") 10718' 6457' With DCk-2 shear out valve (pinned for 3000 psi) 10) 4-%2' 12.6 #/ft IBT-Mod Tubing (2) 11) HES "XN" (3.725 Min ID")- 64° inc 10818' 6502' 12) 4-'/2' 12.6 #/ft IBT-Mod Tubing 13) BOT bonded seal assembly w/ half mule shoe 11793' 6796' Stung into seal bore extension 3' off top of ZXP at 11801' Lower Completion: Top MD TVD Item 14) Seal Bore Extension 11789' 6796' 15) Baker ZXP Liner top packer 11804' 8798' 16) Baker 5" x 7" Flexlock Liner Hanger 11814' 8799' 18) Crossover 4.5" Hyd 521 X 4.5" SLHT 19) 4-'/", 12.6 #/ft, SLHT Tubing +/_ 3 jts 20) 4-'/" 12.6 #/ft, SLHT liner w/blank across shale and slots across sand 21) Baker Shoe 14853' 6817' 9 ~ ~"~ J S CD3-301 PRESSURE INFORMATION (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 lbs. / al Pore pressure si ASP Drilling si 16 114 / 114 10.9 52 53 9 5/8 3035 / 2500 14.5 1131 1635 7" 11964 / 6816 16.0 3084 2402 N/A 14862 / 6817 16.0 3084 N/A • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1 ]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) = 1131 - (0.1 x 2500') = 881 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1] D _ [(14.5 x 0.052) - 0.1] x 2500 = 1635 psi OR ASP =FPP - (0.1 x D) = 3084 - (0.1 x 6816) = 2402 psi Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 3084 - (0.1 x 6817') = 2402 psi • r Cementing Program: 9 5/8" Surface Casing run to 3223' MD / 2500' TVD. Cement from 3223' MD to 2723' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2723' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1263' MD). Lead slurry: (2723'-1504') X 0.3132 ft3/ft X 1.5 (50% excess) = 572.7 ft3 below permafrost 1504' X 0.3132 ft3/ft X 4 (300% excess) = 1884.2 ft3 above permafrost Total volume = 572.7 + 1884.2 = 2456.9 ft3 => 552 Sx @ 4.45 ft3/sk System: 552 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOWI D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1 % 5002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 11964' MD / 6816' TVD First Stage: Cement from 11964' MD to 10360' MD with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Tail: (11964' -10360') X 0.1503 ft3/ft X 1.4 (40% excess) = 337.5 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 337.5 + 17.2 = 354.7 ft3 => 306 Sx @ 1.16 ft3/sk System: 306 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk Second Stage: Cement from ports in a TAM port collar set 500' below the K2 interval to +/- 500' above the K2 interval with Class G + additives @ 15.8 ppg. Assume 40% excess annular volume Lead: (6803'-5765') X 0.1503 ft3/ft X 1.4 (40% excess) = 218.4 ft3 annular vol. Total Volume = 218.4 ft3 => 186 Sk @ 1.17 ft3/sk System: 168 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% 5002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk ' By Weight Of mix Water, all other additives are BWOCement ~lr`~f~t ~~ __E~'~ . , ~ ., . _ .~ ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: .1/30/2007 Time: 11:09:50 Page: I Field: Colville River Unit Co-ordinate(NE) Reference: Well: Plan: CD3-301,: True North + Site: Alpine CD3 Vertical (TVD) Reference: Planned Doyon 19 49:8 Well: Plan: CD3-301 Section (VS) Reference: Well (O.OON,ll.00E,55:00Azi) Wellpath: Plan: CD3-301 Survey Calculation Method: Minimurn'Curvature Dbc Oracle Plan: CD3-301wp04 Date Composed: 1/17/2007 Version: 8 Principal: Yes Tied-to: From Well Ref. Point Field: Colville River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 ' Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model bggm2006 Site: Alpine CD3 Site Position: Northing: 6003886.80 ft Latitude: 70 25 10.481 N From: Map Fasting: 388488.10 ft Longitude: 150 54 30.391 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -0.86 deg Well: Plan: CD3-301 Slot Name: Alpine CD3 Well Position: +N/-S -14.54 ft Northing: 6003874.12 ft ~ Latitude: 70 25 10.338 N +E/-W -124.24 ft Fasting : 388363.67 ft ~ Longitude: 150 54 34.034 W Position Uncertainty: 0.00 ft Wellpath: Plan: CD3-301 Drilled From: Well Ref. Point Tie-on Depth: 36.30 ft Current Datum: Planned Doyon 19 Height 49.80 ft '' Above System Datum: Mean Sea Level Magnetic Data: 2/3/2005 Declination: 23.81 deg Field Strength: 57520 nT Mag Dip Angle: 80.71 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.30 0.00 0.00 55.00 Survey Program for Definitive Wellpath Date: 2/3/2005 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft Plan Section Information MD ft Incl deg Azim deg TVD ft +N/-S ft +E!-W ft 36.30 0.00 0.00 36.30 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 800.00 12.50 10.00 796.04 53.50 9.43 1300.00 27.26 18.41 1265.03 216.37 55.26 2383.71 58.02 1.86 2055.02 930.49 151.15 10346.67 58.02 1.86 6272.96 7681.03 370.43 11964.12 85.00 55.23 6816.80 8929.32 1116.17 12130.79 90.00 55.23 6824.07 9024.24 1252.91 .14862.64 90.26 55.23 ~ 6817.80 10582.20 3496.95 DLS Build Tarn deg/100ft degl100ft deg/100ft 0.00 0.00 0.00 0.00 0.00 0.00 2.50 2.50 0.00 3.00 2.95 1.68 3.00 2.84 -1.53 0.00 0.00 0.00 3.50 1.67 3.30 3.00 3.00 0.00 0.01 0.01 0.00 TFO Target deg 0.00 0.00 10.00 15.00 -26.71 0.00 73.23 CD3-301wp04 Heel 0.00 0.00 CD3-301wp04 Toe ORIGINAL Q °s °n 4 8 O '~ e 0 ~°-. 3 ~ ~ ° VS Q z a VJ ~ 4 ~' '~ 4 iq ~ ~; ti ~~'~` a ~ ~ ~ 4 Q ~ ° M 50 M ~! ~~ a a r+i o a r+i aq ~ a p'~W °; o °; ~~~~ AR~1 ~~Ob ~~ a ea ai eib ~~. . ~~ 4 U e 0 0 a .r ~g ~i~511 Y~`:;3' ~_ ~'I 3 '' M rt ..7 M Yi a a x M a ° W ca O n m 5a m A m a ra ti oa ~ a 0 {50'9 f~ "~ + .~-~ cn ~ .-i a m A o .~Fa ..15p ~~ ~~~aa ~~ .. ~~ '~ F I o, ~' ~ o m 50 m a , cn . ~ A ~ " m ivy A a~ ~ t ~ ~ ~' ~• a ~ cn o ~ o a P4 ~ ~~ ~ ~ p ii ~ U o~ - - H Pu4 P~7 w o v ~~ M M A ~ - ,~ cs cs ~~ ~b _ r __. F v ~ _.. a °O~ _.~ R ~ o -- o +0 o 04 Mo .. ._ 0 A m ° e °o ~ °c. w 0 0 a aU ~ 4 y ~ O 9 ... ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Ina Date:. 1!30/2007 Time: 11:09:50 Page: 2 Field: Colville River Unit Co-ordinate(NE) Reference: Well: Plan: GD3-301, True North Site: Alpine CD3 Vertical (1'VD) Reference: Planned Doyon 19 49.8 Well: Plan: CD3-301 Section (VS) Reference: Well (O.OON,O.OOE,55:OOAzi) Wellpath: Plan: CD3-301 Survey Caiculapon Method: 'Minimum Curvature Db: .Oracle Survey MD Inc! Azim TVD Sys TVD N/S E/W MapN MapE DLS VS Comore t ft ,deg deg ft ft ft ft ft ft deg/100ft ft 36.30 0.00 0.00 36.30 -13.50 0.00 0.00 6003874.12 388363.67 i 0.00 0.00 100.00 0.00 0.00 100.00 50.20 0.00 0.00 6003874.12 388363.67 0.00 0.00 200.00 0.00 0.00 200.00 150.20 0.00 0.00 6003874.12 388363.67 0.00 0.00 300.00 0.00 0.00 300.00 250.20 0.00 0.00 6003874.12 388363.67 0.00 0.00 KOP; 2.5 DLS, 3 400.00 2.50 10.00 399.97 350.17 2.15 0.38 6003876.26 388364.08 2.50 1.54 500.00 5.00 10.00 499.75 449.95 8.59 1.51 6003882.68 388365.31 2.50 6.17 600.00 7.50 10.00 599.14 549.34 19.31 3.40 6003893.37 388367.36 2.50 13.86 700.00 10.00 10.00 697.97 648.17 34.29 6.05 6003908.31 388370.23 2.50 24.62 800.00 12.50 10.00 796.04 746.24 53.50 9.43 6003927.47 388373.90 2.50 38.41 Build; 3 DLS, 80 ' 900.00 15.42 12.92 893.08 843.28 77.12 14.29 6003951.01 388379.11 3.00 55.94 1000.00 18.36 14.93 988.76 938.96 105.30 21.32 6003979.08 388386.56 3.00 77.86 1100.00 21.32 16.39 1082.81 1033.01 137.96 30.51 6004011.60 388396.23 3.00 104.12 1200.00 24.29 17.52 1174.99 1125.19 175.02 41.83 6004048.48 388408.11 3.00 134.65 1300.00 27.26 18.41 1265.03 1215.23 216.37 55.26 6004089.63 388422.15 3.00 169.37 1400.00 29.97 15.71 1352.81 1303.01 262.16 69.25 6004135.19 388436.83 3.00 207.10 1500.00 32.72 13.42 1438.21 1388.41 312.51 82.30 6004185.34 388450.62 3.00 246.66 1600.00 35.51 11.46 1520.99 1471.19 367.28 94.34 6004239.92 388463.49 3.00 287.94 1700.00 38.33 9.74 1600.93 1551.13 426.32 105.36 6004298.78 388475.39 3.00 330.84 1800.00 41.17 8.23 1677.80 1628.00 489.48 115.32 6004361.78 388486.29 3.00 375.22 1900.00 44.03 6.88 1751.40 1701.60 556.57 124.20 6004428.73 388496.17 3.00 420.98 2000.00 46.90 5.66 1821.53 1771.73 627.42 131.97 6004499.45 388505.00 3.00 467.98 2100.00 49.79 4.56 1887.99 1838.19 701.83 138.61 6004573.74 388512.75 3.00 516.10 2200.00 52.68 3.54 1950.60 1900.80 779.60 144.10 6004651.41 388519.40 3.00 565.20 2300.00 55.58 2.60 2009.19 1959.39 860.51 148.43 6004732.24 388524.94 3.00 615.15 2383.71 58.02 1.86 2055.02 2005.22 930.49 151.15 6004802.17 388528.70 3.00 657.52 Sail; 58° for 796 ' 2400.00 58.02 1.86 2063.65 2013.85 944.30 151.60 6004815.97 388529.36 0.00 665.81 2500.00 58.02 1.86 2116.62 2066.82 1029.08 154.35 6004900.69 388533.38 0.00 716.69 2600.00 58.02 1.86 2169.59 2119.79 1113.85 157.10 6004985.40 388537.40 0.00 767.57 2700.00 58.02 1.86 2222.56 2172.76 1198.63 159.86 6005070.12 388541.42 0.00 818.45 2800.00 58.02 1.86 2275.53 2225.73 1283.40 162.61 6005154.84 388545.44 0.00 869.33 2900.00 58.02 1.86 2328.50 2278.70 1368.18 165.36 6005239.55 388549.46 0.00 920.21 3000.00 58.02 1.86 2381.47 2331.67 1452.95 168.12 6005324.27 388553.48 0.00 971.09 3034.99 58.02 1.86 2400.00 2350.20 1482.61 169.08 6005353.91 388554.89 0.00 988.89 9 5/8" 3100.00 58.02 1.86 2434.44 2384.64 1537.72 170.87 6005408.98 388557.50 0.00 1021.97 3200.00 58.02 1.86 2487.41 2437.61 1622.50 173.63 6005493.70 388561.52 0.00 1072.85 3300.00 58.02 1.86 2540.38 2490.58 1707.27 176.38 6005578.42 388565.54 0.00 1123.73 3400.00 58.02 1.86 2593.35 2543.55 1792.05 179.13 6005663.13 388569.57 0.00 1174.61 3500.00 58.02 1.86 2646.31 2596.51 1876.82 181.89 6005747.85 388573.59 0.00 1225.49 3600.00 58.02 1.86 2699.28 2649.48 1961.59 184.64 6005832.57 388577.61 0.00 1276.37 3700.00 58.02 1.86 2752.25 2702.45 2046.37 187.40 6005917.28 388581.63 0.00 1327.25 3800.00 58.02 1.86 2805.22 2755.42 2131.14 190.15 6006002.00 388585.65 0.00 1378.13 3900.00 58.02 1.86 2858.19 2808.39 2215.92 192.90 6006086.71 388589.67 0.00 1429.01 4000.00 58.02 1.86 2911.16 2861.36 2300.69 195.66 6006171.43 388593.69 0.00 1479.89 4100.00 58.02 1.86 2964.13 2914.33 2385.47 198.41 6006256.15 388597.71 0.00 1530.77 4200.00 58.02 1.86 3017.10 2967.30 2470.24 201.16 6006340.86 388601.73 0.00 1581.66 4300.00 58,02 1.86 3070.07 3020.27 2555,01 203.92 6006425.58 388605.75 0.00 1632.54 4400.00 58.02 1.86 3123.04 3073.24 2639,79 206.67 6006510.30 388609.78 0.00 1683.42 4500.00 58.02 1.86 3176.01 3126.21 2724.56 209.43 6006595.01 388613.80 0.00 1734.30 4600.00 58.02 1.86 3228.98 3179.18 2809.34 212.18 6006679.73 388617.82 0.00 1785.18 4700.00 58.02 1.86 3281.95 3232.15 2894.11 214.93 6006764.44 388621.84 0.00 1836.06 4800.00 58.02 1.86 3334.92 3285.12 2978.88 217.69 6006849.16 388625.86 0.00 1886.94 4900.00 58.02 1.86 3387.89 3338.09 3063.66 220.44 6006933.88 388629.88 0.00 1937.82 5000.00 58.02 1.86 3440.86 3391.06 3148.43 223.19 6007018.59 388633.90 0.00 1988.70 M • ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska na Date: 1/30/2007 Tune: 11:09:50 Page: 3 Field: Colville River Unit Co-ordinate(NE) Reference: Well: Plan: CD3-301, True North Site: Al pine CD3 Vertical (TVD) Reference: Planned Doyon 19 49. 8 Well: Plan: C D3-301 Section (V5) Reference: WeIF (O.OON,O.OOE,55.OOAzi} Wellpath: Plan: CD3-301 SnrveyCalcnlationMethod: Minimum Curvature 1)b: Oracle Survey MD Intl Azim TVD Sys TVD N/S E/W MapN MapE DLS V5 Comme t ft deg deg ft ft ft ft ft ft deg/100ft ft 5100 .00 58. 02 1.86 3493 .83 3444. 03 3233 .21 225 .95 6007103. 31 388637. 92 0.00 2039 .58 5200 .00 58. 02 1.86 3546 .80 3497. 00 3317 .98 228 .70 6007188. 02 388641. 94 0.00 2090 .46 5300 .00 58. 02 1.86 3599. 76 3549. 96 3402 .75 231 .46 6007272. 74 388645. 96 0.00 2141 .34 5400 .00 58. 02 1.86 3652. 73 3602. 93 3487 .53 234 .21 6007357. 46 388649. 99 0.00 2192 .22 5500 .00 58. 02 1.86 3705. 70 3655. 90 3572 .30 236 .96 6007442. 17 388654. 01 0.00 2243 .10 5600 .00 58. 02 1.86 3758 .67 3708. 87 3657 .08 239 .72 6007526. 89 388658. 03 0.00 2293 .98 5700 .00 58. 02 1.86 3811 .64 3761. 84 3741 .85 242 .47 6007611. 61 388662. 05 0.00 2344 .86 5800 .00 58. 02 1.86 3864 .61 3814. 81 3826 .63 245 .23 6007696. 32 388666. 07 0.00 2395 .74 5900 .00 58. 02 1.86 3917 .58 3867. 78 3911 .40 247 .98 6007781. 04 388670. 09 0.00 2446 .62 6000 .00 58. 02 1.86 3970 .55 3920. 75 3996 .17 250 .73 6007865. 75 388674. 11 0.00 2497 .50 6100 .00 58. 02 1.86 4023. 52 3973. 72 4080 .95 253 .49 6007950. 47 388678. 13 0.00 2548 .38 6200 .00 58. 02 1.86 4076. 49 4026. 69 4165 .72 256 .24 6008035. 19 388682. 15 0.00 2599 .26 6300 .00 58. 02 1.86 4129 .46 4079. 66 4250 .50 258 .99 6008119. 90 388686. 17 0.00 2650 .14 6400 .00 58. 02 1.86 4182 .43 4132. 63 4335 .27 261 .75 6008204. 62 388690. 19 0.00 2701 .02 6500 .00 58. 02 1.86 4235 .40 4185. 60 4420 .04 264 .50 6008289. 34 388694. 22 0.00 2751 .90 6600 .00 58. 02 1.86 4288 .37 4238. 57 4504 .82 267 .26 6008374. 05 388698. 24 0.00 2802 .78 6700 .00 58. 02 1.86 4341 .34 4291. 54 4589 .59 270 .01 6008458. 77 388702. 26 0.00 2853 .66 6800 .00 58. 02 1.86 4394. 31 4344. 51 4674 .37 272 .76 6008543. 48 388706. 28 0.00 2904 .54 6900 .00 58. 02 1.86 4447. 28 4397. 48 4759 .14 275 .52 6008628. 20 388710. 30 0.00 2955 .42 7000 .00 58. 02 1.86 4500. 25 4450. 45 4843 .92 278 .27 6008712. 92 388714. 32 0.00 3006 .30 7100 .00 58. 02 1.86 4553. 21 4503. 41 4928 .69 281 .03 6008797. 63 388718. 34 0.00 3057 .18 7200 .00 58. 02 1.86 4606. 18 4556. 38 5013 .46 283 .78 6008882. 35 388722. 36 0.00 3108 .06 7300 .00 58. 02 1.86 4659 .15 4609. 35 5098 .24 286 .53 6008967. 06 388726. 38 0.00 3158 .94 7400 .00 58. 02 1.86 4712. 12 4662. 32 5183 .01 289. 29 6009051. 78 388730. 40 0.00 3209 .82 7500 .00 58. 02 1.86 4765. 09 4715. 29 5267 .79 292. 04 6009136. 50 388734. 43 0.00 3260 .70 7600 .00 58. 02 1.86 4818. 06 4768. 26 5352 .56 294. 79 6009221. 21 388738. 45 0.00 3311 .58 7700 .00 58. 02 1.86 4871. 03 4821. 23 5437 .33 297. 55 6009305. 93 388742. 47 0.00 3362 .46 7800 .00 58. 02 1.86 4924. 00 4874. 20 5522 .11 300. 30 6009390. 65 388746. 49 0.00 3413 .34 7900 .00 58. 02 1.86 4976 .97 4927. 17 5606 .88 303 .06 6009475. 36 388750. 51 0.00 3464 .22 8000 .00 58. 02 1.86 5029 .94 4980. 14 5691 .66 305 .81 6009560. 08 388754. 53 0.00 3515 .10 8100 .00 58. 02 1.86 5082 .91 5033. 11 5776 .43 308 .56 6009644. 79 388758. 55 0.00 3565 .98 8200 .00 58. 02 1.86 5135. 88 5086. 08 5861 .20 311. 32 6009729. 51 388762. 57 0.00 3616 .87 8300 .00 58. 02 1.86 5188. 85 5139. 05 5945 .98 314. 07 6009814. 23 388766. 59 0.00 3667 .75 8400 .00 58. 02 1.86 5241. 82 5192. 02 6030 .75 316. 82 6009898. 94 388770. 61 0.00 3718 .63 8500 .00 58. 02 1.86 5294. 79 5244. 99 6115 .53 319 .58 6009983. 66 388774. 63 0.00 3769 .51 8600 .00 58. 02 1.86 5347. 76 5297. 96 6200 .30 322 .33 6010068. 38 388778. 66 0.00 3820 .39 8700 .00 58. 02 1.86 5400 .73 5350. 93 6285 .08 325 .09 6010153. 09 388782. 68 0.00 3871 .27 8800 .00 58. 02 1.86 5453. 70 5403. 90 6369 .85 327. 84 6010237. 81 388786. 70 0.00 3922 .15 8900 .00 58. 02 1.86 5506. 66 5456. 86 6454 .62 330. 59 6010322. 52 388790. 72 0.00 3973 .03 9000 .00 58. 02 1.86 5559. 63 5509. 83 6539 .40 333. 35 6010407. 24 388794. 74 0.00 4023 .91 9100 .00 58. 02 1.86 5612. 60 5562. 80 6624 .17 336. 10 6010491. 96 388798. 76 0.00 4074 .79 9200 .00 58. 02 1.86 5665. 57 5615. 77 6708 .95 338. 86 6010576. 67 388802. 78 0.00 4125 .67 9300 .00 58. 02 1.86 5718. 54 5668. 74 6793 .72 341 .61 6010661. 39 388806. 80 0.00 4176 .55 9400 .00 58. 02 1.86 5771. 51 5721. 71 6878 .49 344 .36 6010746. 11 388810. 82 0.00 4227 .43 9500 .00 58. 02 1.86 5824. 48 5774. 68 6963 .27 347. 12 6010830. 82 388814. 84 0.00 4278 .31 9600 .00 58. 02 1.86 5877. 45 5827. 65 7048 .04 349. 87 6010915. 54 388818. 87 0.00 4329 .19 9700 .00 58. 02 1.86 5930. 42 5880. 62 7132 ,82 352. 62 6011000. 25 388822. 89 0.00 4380 .07 9800 .00 58. 02 1.86 5983. 39 5933. 59 7217 .59 355. 38 6011084. 97 388826. 91 0.00 4430 .95 9900 .00 58. 02 1.86 6036. 36 5986. 56 7302 .36 358. 13 6011169. 69 388830. 93 0.00 4481 .83 10000 .00 58. 02 1.86 6089. 33 6039. 53 7387 ,14 360 .89 6011254. 40 388834. 95 0.00 4532 .71 10100 .00 58. 02 1.86 6142. 30 6092. 50 7471 .91 363 .64 6011339. 12 388838. 97 0.00 4583 .59 10200 .00 58. 02 1.86 6195. 27 6145. 47 7556 .69 366 .39 6011423. 83 388842. 99 0.00 4634 .47 ORIGINAL ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska lnc. Date: 1/30/2007 Time: # 1:09:50 Page: 4 Field: Colville River Un it Co-ordinate(NE) Reference: Well: Plan: CD3-301, True North Site:. Alpine CD3 Vertical (TVD) Reference: Planned Doyon 19 49. 8 Well: Plan: C D3-301 Section (VS) Reference: WeII (O.OON,O.OOE,55.OOAzi) Wellpath: Plan: C D3-301 Survey Calculation Method: Minimum Curvature Dbi Orate Survey MD Incl AZi m TVD Sys TVD N/S E/W MapN MapE DLS VS Comme t ft deg deg ft ft ft ft ft ft deg/100ft ft 10265 .19 58. 02 1 .86 6229 .80 6180. 00 7611 .95 368 .19 6011479. 06 388845. 61 0.00 4667 .64 Top HRZ 10300 .00 58. 02 1 .86 6248 .24 6198. 44 7641 .46 369 .15 6011508. 55 388847. 01 0.00 4685 .35 10346 .67 58. 02 1 .86 6272 .96 6223. 16 7681 .03 370 .43 6011548. 09 388848. 89 0.00 4709 .10 Build; 3.5 DLS 10400 .00 58. 57 3 .96 6300 .99 6251. 19 7726 .33 372 .74 6011593. 35 388851. 87 3.50 4736 .97 10500 .00 59. 70 7 .81 6352 .30 6302. 50 7811 .69 381 .55 6011678. 56 388861. 96 3.50 4793 .15 10600 .00 60. 95 11 .58 6401 .82 6352. 02 7897 .31 396 .20 6011763. 94 388877 .88 3.50 4854 .26 10700 .00 62. 29 15 .25 6449 .37 6399. 57 7982 .86 416 .62 6011849. 17 388899 .58 3.50 4920 .06 10800 .00 63. 73 18 .83 6494 .76 6444. 96 8068 .03 442 .75 6011933. 93 388926 .98 3.50 4990 .31 10900 .00 65. 26 22 .32 6537 .83 6488. 03 8152 .50 474 .48 6012017. 91 388959. 97 3.50 5064 .75 11000 .00 66. 86 25 .73 6578 .42 6528. 62 8235 .95 511 .70 6012100. 79 388998. 43 3.50 5143 .11 11100 .00 68. 54 29 .05 6616 .38 6566. 58 8318 .07 554 .27 6012182. 26 389042. 21 3.50 5225 .08 11200 .00 70. 28 32 .29 6651 .56 6601. 76 8398 .56 602 .02 6012262. 02 389091. 16 3.50 5310 .37 11300 .00 72. 07 35 .47 6683 .83 6634. 03 8477 .12 654 .78 6012339. 78 389145. 09 3.50 5398 .65 11400 .00 73. 92 38 .57 6713 .07 6663. 27 8553 .45 712 .36 6012415. 23 389203. 80 3.50 5489 .59 11500 .00 75. 81 41 .62 6739 .18 6689. 38 8627 .27 774 .54 6012488. 11 389267. 06 3.50 5582 .87 11600 .00 77. 74 44 .62 6762 .06 6712. 26 8698 .31 841 .08 6012558. 13 389334. 66 3.50 5678 .12 11700 .00 79. 71 47 .58 6781. 61 6731. 81 8766 .29 911 .74 6012625. 04 389406. 32 3.50 5774 .99 11800 .00 81. 69 50 .50 6797 .78 6747. 98 8830 .96 986 .26 6012688. 59 389481. 79 3.50 5873 .13 11900 .00 83. 70 53 .39 6810 .49 6760. 69 8892 .09 1064 .35 6012748. 54 389560. 78 3.50 5972 .16 11964 .12 85. 00 55 .23 6816 .80 6767. 00 8929 .32 1116 .17 6012784. 98 389613. 15 3.50 6035 .96 CD3-301wp04 H 12000 .00 86. 08 55 .23 6819 .59 6769. 79 8949 .72 1145 .56 6012804. 94 389642. 83 3.00 6071 .73 12100 .00 89. 08 55 .23 6823 .82 6774. 02 9006 .69 1227 .62 6012860. 67 389725. 73 3.00 6171 .63 12130 .79 90. 00 55 .23 6824 .07 6774. 27 9024 .24 1252 .91 6012877. 84 389751. 27 3.00 6202 .41 Deep pt; 6824' T 12200 .00 90. 01 55 .23 6824 .06 6774. 26 9063 .72 1309 .76 6012916. 46 389808 .71 0.01 6271 .63 12300 .00 90. 02 55 .23 6824 .04 6774. 24 9120 .75 1391 .90 6012972. 25 389891 .69 0.01 6371 .63 12400 .00 90. 03 55 .23 6824 .01 6774. 21 9177 .78 1474 .05 6013028. 04 389974. 67 0.01 6471 .63 12500 .00 90. 04 55 .23 6823 .95 6774. 15 9234 .80 1556 .19 6013083. 83 390057. 65 0.01 6571 .62 12600 .00 90. 05 55 .23 6823 .88 6774. 08 9291 .83 1638 .34 6013139. 62 390140. 63 0.01 6671 .62 12700 .00 90. 05 55 .23 6823 .80 6774. 00 9348 .86 1720 .48 6013195. 41 390223. 61 0.01 6771 .62 12800 .00 90. 06 55 .23 6823 .69 6773. 89 9405 .89 1802 .62 6013251. 20 390306. 59 0.01 6871 .62 12900 .00 90. 07 55 .23 6823 .57 6773. 77 9462 .92 1884 .77 6013306. 99 390389. 57 0.01 6971 .62 13000 .00 90. 08 55 .23 6823 .43 6773. 63 9519 .95 1966 .91 6013362. 78 390472. 55 0.01 7071 .62 13100 .00 90. 09 55 .23 6823 .28 6773. 48 9576 .98 2049 .06 6013418. 57 390555 .53 0.01 7171 .62 13200 .00 90. 10 55 .23 6823. 11 6773. 31 9634 .01 2131 .20 6013474. 36 390638 .51 0.01 7271 .62 13300 .00 90. 11 55 .23 6822. 92 6773. 12 9691 .04 2213 .34 6013530. 15 390721. 49 0.01 7371 .62 13400 .00 90. 12 55 .23 6822 .71 6772. 91 9748 .07 2295 .49 6013585. 94 390804. 47 0.01 7471 .62 13500 .00 90. 13 55 .23 6822 .49 6772. 69 9805 .10 2377 .63 6013641. 73 390887. 45 0.01 7571 .62 13600 .00 90. 14 55 .23 6822 .25 6772. 45 9862 .13 2459 .78 6013697. 52 390970. 43 0.01 7671 .61 13700 .00 90. 15 55 .23 6822 .00 6772. 20 9919 .16 2541 .92 6013753. 31 391053. 41 0.01 7771 .61 13800 .00 90. 16 55 .23 6821 .73 6771. 93 9976 .19 2624 .06 6013809. 10 391136. 39 0.01 7871 .61 13900 .00 90. 17 55 .23 6821 .44 6771. 64 1.OOe04 2706 .21 6013864. 89 391219. 37 0.01 7971 .61 14000 .00 90. 18 55 .23 6821 .13 6771. 33 1.OOe04 2788 .35 6013920. 68 391302 .35 0.01 8071 .61 14100 .00 90. 19 55 .23 6820. 81 6771. 01 1.01 e04 2870 .49 6013976. 46 391385. 33 0.01 8171 .61 14200 .00 90. 20 55 .23 6820 .47 6770. 67 1.02e04 2952 .64 6014032. 25 391468. 31 0.01 8271 .61 14300 .00 90. 21 55 .23 6820 .12 6770. 32 1.02e04 3034 .78 6014088. 04 391551. 29 0.01 8371 .61 14400 .00 90. 22 55 .23 6819 .74 6769. 94 1.03e04 3116 .92 6014143. 83 391634. 27 0.01 8471 .60 14500 .00 90. 23 55 .23 6819 .35 6769. 55 1.03e04 3199 .07 6014199. 62 391717. 25 0.01 8571 .60 14600 .00 90. 24 55 .23 6818 .95 6769. 15 1.04e04 3281 .21 6014255. 41 391800. 23 0.01 8671 .60 14700 .00 90. 25 55 .23 6818 .52 6768. 72 1.04e04 3363 .35 6014311. 20 391883 .21 0.01 8771 .60 14800 .00 90. 26 55 .23 6818 .08 6768. 28 1.05e04 3445 .50 6014366. 99 391966 .19 0.01 8871 .60 14862 .64 90. 26 55 .23 6817 .80 ' 6768. 00 1.05e04 3496 .95 6014401. 94 392018. 18 0.01 8934 .24 CD3-301wp04 T ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 1/30/2007 Time: 11x09:50 Page: 5 Field: Colville. River Unit Co-ordinate(NE) Reference: Well: Plan: CD3-301, Tnae North Site:. Alpine CD3 Vertical (T'VD) Reference: Planned Doyon 19 49.8 Well: Plan: CD3-301 Section (VS) Reference: Well (O.OON,O.OOE,55.OQAzi) Wellpath: Plan: CD3-301 Survey Calculation Method: Minimum Curvature. Db: Oracle: Targets Map Map <-- Latitude ---> <- Longitude .Name Description TVD +N/-S +E/-W Northing Eastiag 'Deg :vIin Sec Deg Min Sec Dip. Dir. ft ft ft ft ft CD3-301wp04 Heel 6816.80 8929.32 1116.17 6012784.98 389613.15 70 26 38.155 N 150 54 1.264 W CD3-301wp04 Toe 6817.80 10582.20 3496.95 6014401.94 392018.18 70 26 54.403 N 150 52 51.345 W Annotation MD TVD ft ft 300.00 300.00 KOP; 2.5 DLS, 300' MD 800.00 796.04 Build; 3 DLS, 800' MD 2383.71 2055.02 Sail; 58° for 7962' 3034.99 2400.00 9 5/8" csg; 2400' TVD 10346.67 6272.96 Build; 3.5 DLS 11964.12 6816.80 7" csg; 11964' MD, 6816' TVD 12130.79 6824.07 Deep pt; 6824' TVD 14862.64 6817.80 TD Casing Points MD TVD Diameter Hole Size Name ft ft in in 3034.99 2400.00 9.625 12.250 9 5/8" 11964.12 6816.80 7.000 8.750 7" 14862.64 6817.80 6.125 6.125 6 1/8" Open Hole Formation s MD .TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 10265.19 6229.80 Top HRZ 0.00 0.00 ORIGINAL ConocoFhillips Alaska, Inc. Anticollision Report Company: ConocoFhillips Alaska Inc. Date: 1!29/2007 Time::: 17:11:59 Page: 1 Field: Colville River Unit Reference Site: Alpine CD3 Co-ordinate(NE) Reference: Wefl: Plan: CD3-301, True North Reference Well: Plan: CD3-301 Vertical ('TVD) Reference: Planned Doyon 19 49.8 `' Reference Wellpath: 'Plan: CD3-301 Db: `Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: CD3-301wp04 & NOT PLANNED P Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 36.30 to 14862.64 ft Scan Method: Trav Cylinder No rth Maximum Radius: 1682.63 ft Error Surface: Ellipse + Casing Casing Points MD TVD Diameter Hole Size Name ft ft in in 3034.99 2400.00 9.625 12.250 9 5/8" 11964.12 6816.80 7.000 8.750 7" 14862.64 6817.80 6.125 6.125 6 1/8" Open Hole Plan: CD3-301wp04 Date Composed: 1/ 17/2007 Version: 6 Principal: Yes Tied-to: From Well Ref. Point Summary <------------ Offset Wellpath -~ -------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft Alpine CD3 CD3-108 CD3-108 V14 13025.63 14825.00 151.77 164.77 -13.00 FAIL: Major Risk Alpine CD3 CD3-109 CD3-109 V5 1644.18 1725.00 130.22 25.99 104.22 Pass: Major Risk Alpine CD3 CD3-110 CD3-110 V11 1826.31 1875.00 90.19 31.74 58.45 Pass: Major Risk Alpine CD3 CD3-111 CD3-111 V7 324.49 325.00 202.39 6.41 195.98 Pass: Major Risk Alpine CD3 CD3-111 CD3-111 L1 V1 324.49 325.00 202.39 6.41 195.98 Pass: Major Risk Alpine CD3 CD3-112 CD3-112 V3 275.49 275.00 219.21 5.07 214.14 Pass: Major Risk Alpine CD3 CD3-302 CD3-302P61 V11 547.84 550.00 13.86 9.77 4.10 Pass: Major Risk Alpine CD3 CD3-302 CD3-302P62 V6 547.84 550.00 13.86 9.77 4.10 Pass: Major Risk Alpine CD3 CD3-302 Plan: CD3-302 VO Plan: 547.84 550.00 13.86 9.88 3.99 Pass: Major Risk Alpine CD3 CD3-307 CD3-307 V4 591.92 600.00 118.89 11.21 107.68 Pass: Major Risk Alpine CD3 CD3-307 Plan: CD3-107 V4 Plan: 591.92 600.00 118.89 11.21 107.68 Pass: Major Risk Alpine CD3 CD3-307 Redundant: CD3-107wp0 3 639.76 650.00 120.63 12.42 108.21 Pass: Major Risk Alpine CD3 CD3-307 Redundant: CD3-107wp0 5 591.92 600.00 118.89 11.32 107.57 Pass: Major Risk Alpine CD3 Plan: CD3-106 Plan: CD3-106 V2 Plan: 908.59 925.00 29.46 19.68 9.78 Pass: Major Risk Alpine CD3 Plan: CD3-303 Plan: CD3-303 V5 Plan: 570.62 575.00 37.79 11.38 26.41 Pass: Major Risk Alpine CD3 Plan: CD3-303 Plan: CD3-303PB1 V2 PI 570.62 575.00 37.79 11.27 26.52 Pass: Major Risk Alpine CD3 Plan: CD3-304 Plan: CD3-304 V3 Plan: 593.89 600.00 57.32 11.81 45.51 Pass: Major Risk Alpine CD3 Plan: CD3-305 Plan: CD3-205 V1 Plan: 543.79 550.00 70.25 9.72 60.53 Pass: Major Risk Alpine CD3 Rig: CD3-113 Plan: CD3-113 V4 Plan: 420.20 425.00 241.65 9.01 232.64 Pass: Major Risk Alpine CD3 Rig: CD3-113 Plan: CD3-113P61 V5 PI 420.20 425.00 241.65 9.01 232.64 Pass: Major Risk Alpine CD3 Rig: CD3-113 Rig: CD3-113P61 V8 419.95 425.00 241.39 8.21 233.18 Pass: Major Risk Alpine Satellites Fjord 5 Fjord 5 PB1 V1 13738.21 6875.00 1316.92 173.12 1143.80 Pass: Major Risk Alpine Satellites Fjord 5 Fjord 5 V1 13838.63 6875.00 1429.91 177.15 1252.76 Pass: Major Risk GRAM ORIGINAL C7 ConocoPhillips Alaska, Inc. Anticollision Report Company:. ConocoPhiilipsAlaska Inc. Date: 1/29/2007 Time: 17:14:06 Page:. 1 Field: Colville River. Unit , Reference Site: Alpine CD3 Co-ordinate(NE) Reference: Well: Plan: CD3-301, True North Reference WeB: Plan: `CD3-307 Vertical (TVD) Reference:. Planned Doyon 19 49.8 Reference Wellpath: Plan: CD3-301 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: CD3-301wp04 & NOT PLANNED P Interpolation Metho d: MD Interval: 25.00 ft Error Modet: ISCWSA Ellipse Depth Range: 36.30 to 14862.64 ft Scan Method: Trav Cylinder No rth Maxunum Radius: 1682.63 ft Error Surface: Ellipse + Casing Casing Points MD TVD Diameter Hole Size Name ft ft in in 3034.99 2400.00 9.625 12.250 9 5/8" 11964.12 6816.80 7.000 8.750 7" 14862.64 6817.80 6.125 6.125 6 1/8" Open Hole Plan: CD3-301wp04 Date Composed: 1/ 17/2007 Version : 6 Principal: Yes Tied-to: From Well Ref. Point Summary < - Offset Wellpath --> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft $ ft ft ft Alpine CD3 CD3-108 CD3-108 V14 1305.43 1350.00 54.41 0.00 54.41 Pass: Minor Risk Alpine CD3 CD3-109 CD3-109 V5 1644.18 1725.00 130.22 25.99 104.22 Pass: Major Risk Alpine CD3 CD3-110 CD3-110 V11 1826.31 1875.00 90.19 31.74 58.45 Pass: Major Risk Alpine CD3 CD3-111 CD3-111 V7 324.49 325.00 202.39 6.41 195.98 Pass: Major Risk Alpine CD3 CD3-111 CD3-111L1 V1 324.49 325.00 202.39 6.41 195.98 Pass: Major Risk Alpine CD3 CD3-112 CD3-112 V3 275.49 275.00 219.21 5.07 214.14 Pass: Major Risk Alpine CD3 CD3-302 CD3-302PB1 V11 547.84 550.00 13.86 9.77 4.10 Pass: Major Risk Alpine CD3 CD3-302 CD3-302P62 V6 547.84 550.00 13.86 9.77 4.10 Pass: Major Risk Alpine CD3 CD3-302 Plan: CD3-302 VO Plan: 547.84 550.00 13.86 9.88 3.99 Pass: Major Risk Alpine CD3 CD3-307 CD3-307 V4 591.92 600.00 118.89 11.21 107.68 Pass: Major Risk Alpine CD3 CD3-307 Plan: CD3-107 V4 Plan: 591.92 600.00 118.89 11.21 107.68 Pass: Major Risk Alpine CD3 CD3-307 Redundant: CD3-107wp0 3 639.76 650.00 120.63 12.42 108.21 Pass: Major Risk Alpine CD3 CD3-307 Redundant: CD3-107wp0 5 591.92 600.00 118.89 11.32 107.57 Pass: Major Risk Alpine CD3 Plan: CD3-106 Plan: CD3-106 V2 Plan: 908.59 925.00 29.46 19.68 9.78 Pass: Major Risk Alpine CD3 Plan: CD3-303 Plan: CD3-303 V5 Plan: 570.62 575.00 37.79 11.38 26.41 Pass: Major Risk Alpine CD3 Plan: CD3-303 Plan: CD3-303P61 V2 PI 570.62 575.00 37.79 11.27 26.52 Pass: Major Risk Alpine CD3 Plan: CD3-304 Plan: CD3-304 V3 Plan: 593.89 600.00 57.32 11.81 45.51 Pass: Major Risk Alpine CD3 Plan: CD3-305 Plan: CD3-205 V1 Plan: 543.79 550.00 70.25 9.72 60.53 Pass: Major Risk Alpine CD3 Rig: CD3-113 Plan: CD3-113 V4 Plan: 420.20 425.00 241.65 9.01 232.64 Pass: Major Risk Alpine CD3 Rig: CD3-113 Plan: CD3-113P61 V5 PI 420.20 425.00 241.65 9.01 232.64 Pass: Major Risk Alpine CD3 Rig: CD3-113 Rig: CD3-113PB1 V8 419.95 425.00 241.39 8.21 233.18 Pass: Major Risk Alpine Satellites Fjord 5 Fjord 5 P61 V1 13738.21 6875.00 1316.92 173.12 1143.80 Pass: Major Risk Alpine Satellites Fjord 5 Fjord 5 V1 13838.63 6875.00 1429.91 177.15 1252.76 Pass: Major Risk GRAM 0 0000 _ 10^~ ooo non onhee - M~ a°n on nh o~~~r~0~'r9~i n° ~ _ _ ~nh.Y.Y .ti.a n.y .~.y .r.r .-~.r.yn ~ - ~~oo oo o000 - b - - _- _ SS~p3, ~ ~ _ -~ .-~.-i l` mil- t- -- - - - ~'-~ ~ ~ - _ _+ . . %' ' _ - t f /r; -~~ ~ - _ - _ I I ~ - e ~ .°~ - n -- ~ ~ A ~~ ~r \' - 4°M1 _ Y~...~5- o - -_-- ' o 0 o e ~ o~ e e -•-' , _ _ n ti ° :r n - ~ _ _ is __fY p~ ! Fd V oeeee yo^~ ooe eo ononn on oo r M ran M1,-i'-I r-1 r-In rlrl rl rlrl i-1,-1 .-1~~ ~~~~ ~~ ICI ~ ~ ~ ooo oeeee ee ee f~~ e inn on on en eenon no no e n ,a nnh on nh oonnM1~~~~ ,r p Ri .r.a .r.y n~ ,~ Fa ~ _ ~ _ ~ ~ ~, s _ - ~t ~ = _ - ~~S __ U~~pp Y~ }~ . 4 4 4 P . __ - _ y 7 44444E ._ ~ xr`.s #.a ~` "'fir _ _~ G I~^~1 ~ x" ~ -:Y a~~ i' ' ~` -~ _ I I I I I I I I I I I I ~ M y ,~~ rf r. ,,i,s~~ ~'sc ~+ - ~ .~r ~ ~ :tit X .t -- ~ _ _ °' r ______. ... ... ~~ f ~~` ~ it .. ~ 1; __ A ~' _____________ - R ~ ~~~~~~~~~~~~~ h °n .°-. h .y .ti .+ 3 1 Closest in POOL Closest Approac h: Reference Well: CD3-301wp04 Plan Offset Well: Fjord 5 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Incl. Subsea N(+)/S(-) View VS Meas. Ind. Subsea N(+)/S(-) View VS Min. Dist. ? Depth Angle TRUE Azi. TVD E(+)/W(-) (55°) Comments Depth Angle TRUE Azi. TVD E(+)/yt/(_) (55°) Comments POOL Min Distance POOL Min Distance (1429.71 ft) in POOL (1429.71 ft) in POO (11964 - 14862 MD) t (11964 - 14862 MD) ~ Fjord 5 (6725 - 6780 CD3-301wp04 Plan 1429.71 13836 90.16 55.23 6770.992 6013830 391167.2 7907.969 TVDss) 6864 1.24 153.24 6739.22 6012646 391967.7 723.87 (6725 - 6780 TVDss) losest Approac h: Reference Well: CD3-301wp04 Plan Offset Well: CD3 -108 Coords. - Coords. - ASP ASP D ctr-ctr Meas. Incl. Subsea N(+)/S(-) View VS Meas. Ind. Subsea N(+)/S(-) View VS in. Dist. Depth Angle TRUE Azi. TVD E(+)/W(-) (55°) Comments Depth Angle TRUE Azi. TVD E(+)/W(-) (55°) Comments POOL Min Distance POOL Min Distance (3907.84 ft) in POOL (3907.84 ft) in POOL (11964 - 14862 MD) t (11964 - 14862 MD) t CD3-108 (6725 - 6780 CD3-301wp04 Plan 3907.84 13136 90.1 55.23 6772.585 6013440 390586.3 7207.976 TVDss) 18836 103.9 322.9 6783.64 6016681 388403.3 7220.21 (6725 - 6780 TVDss) Closest Approac h: Reference Well: CD3-301wp04 Plan Offset Well: CD3 -109 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Incl. Subsea N(+)/S(-) View VS Meas. Incl. Subsea N(+)/S(-) View VS Min. Dist. _ Depth Angle TRUE Azi. TVD E(+)/W(-) (55°) Comments Depth Angle TRUE Azi. TVD E(+)IW(-) (55°) Comments POOL Min Distance POOL Min Distance (4704.33 ft) in POOL (4704.33 ft) in POOL (11964 - 14862 MD) t (11964 - 14862 MD) t CD3-109 (6725 - 6780 CD3-301wp04 Plan 4704.33 r 7 11964 85 55.23 6766.179 6012786 389613.8 6036.196 TVDss) 9036 63.92 3.38 6781.07 6008370 391234.6 4899.25 (6725 - 6780 TVDss) .~": ;,tea:. r~ CD3-301wp04 POOLSummary.xls 1/30/2007 11:07 AM • • CD3-301 Surface Location: F ,,,:. ....... _~~.,,.,_.._.. ... ..._ _ .....~....... ___..,.. _, _.._ 4. CPAI Coordinate ~anverter from: _ Gatum: tJ.vD27 Region: alasf:a >~" LatikudelLongitude Decimal Degrees ~~ ' f' UTM Zone: ~~ ~" South I +:- State Plane Zane: 4 ~ Units: us-ft f _ Starting Coordinates: - - X: 388363.67 Y: F003474.12 Ta Datum: NAD27 Region: alaska . C LatibadelLongitude Decimal Degrees ~` UTM Zone: True ~ South {" State Plane Zane: ~q ~ Units: ,as-ft . r` Legal Description (NAD27 only) Legal Description _ - _ __ Township: 012 N Range: 005 E + Meridian: U Seckion:~~ FPlL 3857.6297 FEL 680.40807 CD3-301wp04 7" casing point: r ~ CPAt Coordinate Conv¢rt¢r From: _. ___. _ ___ ___- Datum: NAD27 . Region: alaska . ' f`' LatitudelLongitude Decirc~al Degrees C UTM Zane:3 ~"- South t+ State Plane Zone: 4 . Units: us-ft . ~' , . -Starting Coordinates: _ _ __ X: 389613.00 Y: 60127"05.00 - T o: _ __ . _ _ _ _ Datum: fk,yD27 ~ Region: alaska C LakitudelLongikude Decimal Degrees T UTM Zone: True ~`- South C Skate Plane Zone: 4 ~ Units: us-ft fi Legal Description (NAD27 only) LegalDescription _.- _ Township: 013 N Range: 005 E . Meridian: U ~~ Section: 32 FNL 24°.36180 FEL . 2178.5440 '?RIGINAL • • CD3-301w 04 Toe: ,.-- ~ CPki Coordinate Converter ~rt~~~ -From: - _ _ __ _ ---- -- - _ __- _ - Datum: No,D~7 Region: alaska + <- LatitudelLongitude Decimal Degrees ~~ ~" UTM Zone: ~-- ~"" South C.` State Plane Zone: 4 + Llnits: us-ft + r.'- - - -Starting Coordinates: - - - - - 39201g.U0 Y: F0144L12.00 To: _ _._ ___ _._- ---__._. - ----_-- Datum: PJAD27 Region: .alaska + t"' LatitudelLongitude perirc~al Degrees _~~~ ?~ UTM Zone: Tnae ~ Soukh !`- State Plane Zone: 4 I_Inits: us-ft f: Legal Description (NAD27 nnlyl -Legal Description _ Township: 013 hJ Flange: 005 E Meridian: LI Section:. zg FNL 3876.1516 FEL + 50722144 'R161NAL Re: CD3-301 Subject: Re: CD3-301 From: Thomas Maunder <tommaunder~~admin.state.ak.us> Date: Wed, 14 Mar ?007 09:45:37 -0800 To: "Galianas, Elizabeth C" <Elizah~th.('.Gatiunas cc;conocophillips.com> Thanks Liz. We will move the permit forward. Tom Maunder, PE AOGCC Galiunas, Elizabeth C wrote, On 3/14/2007 9:38 AM: Tom, Please release this permit now to be completed Thanks, Liz Galiunas Drilling Engineer Alpine Drilling Team Office: (907)-265-6247 Cell: (907)-441-4871 c~ `Q~'~S vJfe~`rc h¢(~CUC eJ A Q ~ ~~ ~Q t~c~w~~fcc-S~Cs~'SJ-~C~~ ~~~t~C.SS~~K~ .1..res ~ ~~ 510 Qe.S®~~ ~G-V'i ~~ ~SS~h W i'~U~Z3-v~lt~ ~ C~SC~.SS~c~f~~~'~SS~'~' Sc -----Original Message----- ~~~~~~~~~~ ~ G`~vJ ~~ ., _ om: T omas Maunder ~;a~~t~;:t:;m maunderw:=~,~,it.:~n_.s~at.e.ak,_~, =~ , ZP~~ O~c'~4 ~c~c~4lS ~~ Se Friday, February 23, 2007 8:58 AM Q To: liunas, Elizabeth C ``__ Subjec Re: CD3-301 ~ w~ ~ ,~ C~ Y q Liz, 7]j ~~ Thanks for the iscussion. I believe m uest' ns are answered. ids Call or message with ny questions. Tom Maunder, PE AOGCC What is the stat on the Kuukpik internal a royal? Our review of the rmit is on hold until w hear regarding Kuukpik. Galiunas, Elizabeth C wrote, On 2/ /2007 9:10 AM: Tom, I apologize for this f low up taking o long. The summary of why we co Jude the C30 is n the sour migration during t well control event d ing the operations on CD3 07/107. For further oper Tonal attached word d ument which was sent to the ate following is our ~e of the gas cut and pull details see the on January 6, 2007. To clarify,~t/he mud log for this year is going tome on CD3-114. We '; did amine the mud logs for the two closest exploration wells a found not ~ g indicating on where the gas could have come from. rior to cutting the casing, the outer annulus had diesel and water plus X800 psi of gas. When the casing cutter was run in the hole, the outer 1 of 3 3/14/2007 9:45 AM Re: CD3-301 • Subject: Re: CD3-301 From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Fri, 23 Feb 2007 08:57:58 -0900 To: "Galiun@ Elizabeth C" <Elizabeth.C.Galiunas@conocophillips.com> Liz, Thanks for the discussion. I believe my questions are answered. What is the status on the Kuukpik internal approval? Our review of the permit is on hold until we hear regarding Kuukpik. Call or message with any questions. Tom Maunder, PE AOGCC Galiunas, Elizabeth C wrote, On 2/22/2007 9:10 AM: Tom, I apologize for this follow up taking so long. The following is our summary of why we conclude the C30 is not the source of the gas migration during the well control event during the cut and pull operations on CD3-307/107. For further operational details see the attached word document which was sent to the state on January 6, 2007. To clarify, the mud log for this year is going to be on CD3-114. We did examine the mud logs for the two closest exploration wells and found nothing indicating on where the gas could have come from. Prior to cutting the casing, the outer annulus had diesel and water plus 800 psi of gas. When the casing cutter was run in the hole, the outer annulus was bleed off, leaving the annulus under balanced. Once the 7" casing was cut with the mechanical cutter the rig attempted to circulate around the 7" X 9 5/8" annulus. The 7" casing was packed off above the cut (in the 100' of open annulus below the surface shoe) and would not circulate. Eventually, in trying to circulate around the cut, the formation broke down, the well took 15 bbls of fluid, with no returns up the annulus. We believe that due to the under balanced annulus gas entered the wellbore in from a small sand below the cut. The reasons for this include: 1. Once we increased our mud weight to 10.7ppg, the well would appear dead for 30 minutes, then slowly the pressure would increase. If the gas were from the C30 right below the shoe, the higher mud weights would have killed the outer annulus and would have provided sufficient over balance to prevent gas influx. 2. Once we kicked off the cement plug, the mud weight was lowered to 10 ppg with the well static on connections and no other indications of an over pressured zone. We have concluded in the future for doing any cut and pull casing operations, while running in with the casing cutter, heavy fluid should be bull headed down the outer annulus at the highest rate under the pressure limitations. Another option would be to circulate out the fluid on the outer annulus against choke pressure to keep the shoe pressure constant, like a well control operation, instead of bleeding off the pressure to zero. The average pressure outer annulus recorded from pressure transmitters on the CD3 wells for the past 8 weeks is as follows: CD3-107 490 psi (before rig moved on) CD3-108 470 psi CD3-109 670 psi CD3-110 600 psi CD3-111 680 psi 1 of 2 2/23/2007 8:58 AM Re: CD3-301 Let me know if you would :Like any more information. Liz Galiunas Drilling Engineer Alpine Drilling Team Office: (907)-L65-6247 Ce11: (907)-441-4871 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@adrnin.state.ak.us] Sent: Thursday, February 15, 2007 7:22 AM To: Johnson, Vern; Galiunas, Elizabeth C Cc: Alvord, Chip Subject: CD3-301 Vern and Liz, I am reviewing the permit application for this well. Mention is made of the well control event on CD3-307/CD3-107 while pulling the 7" casing. It is CPAI's belief that the gas source is the C30 and not related to the shallower sections which will be drilled to set the surface casing. In earlier messages I believe it was mentioned that CPAI might have a gas analysis and you should also have a mud log from the redrilled 8-1/2" hole of CD3-107. I would appreciate receiving some of this additional information. My reason is with regard to waiving the diverter on CD3-301. I am inclined to agree with CPAI's statements, however I believe it prudent to have this additional information. One other item to include is any monitoring information on the outer annuli of wells at CD3. Has the rig seen anything unusual on the wells? I have not received any notice from Problem Wells. Thanks in advance for the information. Call or message with any questions. Tom Maunder, PE AOGCC 2 of 2 2/23/2007 8:5.8 AM ~ ~ Doyon 19 2/6/07 Mr. Jeff Jones, This note is an attempt to summarize our phone conversation earlier this evening. The rig is beginning re-drill operations on CD3-107. A bridge plug was set in the 7" casing @ 3240' followed by a pressure test to 3500 psi for 30 minutes. The well was displaced to 9.6 kcl brine from this depth to surface. Ran in hole with casing cutter to 3193', 800 psi on 9 5/8" x 7" annulus was bled off to an open top tank - 0 psi, annulus static. The 7' casing was cut @ 3193'MD / 2528' TVD (100' below 9 5/8" casing shoe) pressure on 9 5/8" annulus still 0 psi. Closed annular preventor and attempted to circulate up annulus, lost 15 bbls to hole with no returns on 9 5/8" x 7" annulus. Pulled up to 3026' planning a second cut. Prior to cut, 240 psi observed on 9 5/8" x 7" annulus at wellhead. Closed annular preventor and opened up annulus to open top tank. Displaced annulus with 9.6 ppg brine. The 9 5/8" x 7" annulus was closed and pressure built to 140 psi, Opened annular preventor and observed slight flow up 7" x 4" annulus. Closed annular preventor and displaced drill pipe and 9 5/8" x 7" annulus with 9.8 ppg mud taking returns to open top tank. Mud returns to open top tank were gas cut to 8.8 ppg. Well was shut in and circulating lines rigged up from 9 5/8" x 7" annulus to the rig's choke manifold. Pressure on 9 5/8" x 7" annulus was 40 psi, drill pipe 20 psi. Circulated out gas cut mud through choke, shut in well and monitored pressure -pressures stabilized at 50 psi on the drill pipe and 100 psi on the 9'518 X 7'` arinulus, 40 psi on the 7`' x 4" annulus. ~ . ; The rig is currently performing well kill operations with 10.7 ppg mud. Please contact me if you have any further questions. David P. Burley ConocoPhillips Drilling Supervisor Doyon 19 670-4300 Office 670-4350 Rig floor ~J SHARON K. Alf_SUP-DRAKE ~ C©NOCOPHILLIPS ATO 1530 700 G ST. ANCHORAGE AK 995U1 ORDER OFE ~ ~~~~ 1 ~i Q~ /-f ~., 1168 a 3 ~ ~.~ ~ DATE ~~~ P~/~ ~ ~~r~1551/441 CZ~ CC $ /OC> C~C~ 00~-COLLARS LJ ~ FwuF~ JPMarganChase ~ j Valid Up To 5000 Dollars JPMorgan Chase Bank, N.A. Columbus, OH -, MEMO - -- ~d?-_- ~~ ~ - ~; ~:0441155LL~;528747L907927n' ~~ L168 • • TRAYSI~IITTAL LETTER CI~ECKLIST `YELL r'AIVIE (i~l~ ~-b~ ~3D 1 PTD# Z~ 7- ~ 23 Development Service Exploratory Stratigraphic Test Yon-Conventional Wel! Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK I ADD-ONS T _ TEXT FOR APPROVAL LETTER Vb'HAT ~ (OPTIONS) APPLIES L I MliLTi LATERAL ~ The permit is for a new wellbore segment of existing ~ ~ well , ([F last two digiu API b in .Permit No. , API No. 50- - - . a er num , ,' between 60-69) re ; f !Production should continue to be reported as a function of the original AP[ number stated above. PILOT HOLE i [n accordance with 20 AAC 2~.00~(~, all records, data and logs i ~ acquired for the pilot hole must be clearly differentiated in both ;well name ( PH) and API number ~ ' (50- - -_~ from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC 'EXCEPTION ~ 23.0». Approval to perforate and produce / infect is contingent upon issuance of a conservation order approving a spacing j I exception. assumes the ~ liability of any protest to the spacing exception that may occur. ' ,DRY DITCH ~ AI( dry ditch sample sets submitted to the Commission must be in ; SA!~IPLE I no greater than 30' sample intervals from below the permafrost or i from where samples are first caught and 10' sample intervals j through target zones. ~ Please note the following special condition of this permi*_: Non-Conventional i production or production testing of coal bed methane is not allowed ;Well ~ for (name of welll until after jCom,~anv Name) has designed and '. implemented a water wel[ testing program to provide baseline data ' j on water quality and quantity. 1Com~anv Name) must contact the 'Commission to obtain advance approval of such water well testing j ~ program. ~ Rev: [ '2~i06 C: `jody`,transmittal_checklist • • ~^ N ~ ~ ; ~ N .y ~~ ~ ~ ~ ~ : c ° : ~ ¢ ~;: :~ • o ~; o' : : : ~ o' ~: : I a' ~ v , : c. °: c. ~ ~ , ~ . ~ ~ ~ ~ ~ a Q N J• O. d p OQ O. fQ °. (6• m 0 y a ~ c ~ p~ c. ~ N, ~ > ?~~ ~ ~ ~ ~ ~ ~ • ~ ~ v N. ~ ~ O. T ti op ~ U: ~ '~~ ~ ~ : N m ~ a0~ X N. . : ~' : ' s. 3, .. ~, c c of p o ~ a ° c: c' aY c. d a> N2' ~ I ` u. I O ~ c' ' ur : ui c ~~ ~: Z' c. ~ F- ° ~ M p: N' ~: I ~ O o m' ~ ° o' ~ : : Q . ii. of y' d N ~ ~ ~ N m. o, °~ o, ° ~~ ~ ~ 4 a: N c N' T c f6' J J ~ , ~~ M' O' p~ , p.. ~ p~ 3' ~ ~ . ~ ~ ~ ~ ~ ~ ~ ~ ~~ N~ O~ 4 c. ~ N d~ ~ : a ~: N O: W ~ N ~~ ~ d N• ~~ N N• N• O . ,t a ~: c: c: c O: d o: o. p• m: -Q: X ~ ~ ~ y: N (0 ~ J l6 (6 (0 fl+ w' a' C' Q L' ~~ ql O' d ~ ~ it ~ ~ ' N ~ ,t: J• c' c' c. N. ~ ~ ~ ~ ~ ~ : ~~ ~ ~~ 'x: ~: •X, ~~ ~ ~ ~: C• O. p. Z ~ O, p: O, O. O' ~~ ~ ~ ~ °~ C: O. ~ m ~ O: >: f0~ ~ Q. ~ ~ N• O' X' °~ w ~ U~ U U U. a~' z, a' ~ ~ a. p. ~' ~' _, z. w. z, a , N~ N~ N~ N~ ~ ~ ~ ~ U} ~ N~ ~ N~ N~ ~ ~ N~ VD UD f/n ~ ~ ~ ~ N ~ ~ a a; a; a N~ N~ ~ a a~ ~ o ~ o UY N~ m a~ N: N~ a a~ a m N: Ub N: m m m N: ~ a~ O a N~ ~ ~ a; a a ~, d : : ~, >-, >-: ~: ~, ~, >-~ >-~ : : ~, ~, ~, ~. ~ : ~ Z, Z, Z, : >-, Z, ~, : Z, Z, : ~, ~, : Z, ~, Z, ~, : : ~, ~, ~, : , : ~, Z, Z, : ~, ~', : Z, Z, Z T M ~ ~ p: o: ; ~ T. : . x N ~ c' I O N ~ ~ ~ ~ ~ ~ ~ N. .O 3i ~: : II ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 3, i ~ O' ~ ~ ~ ~ C ~ ~ ~ . j. G O: N. N' LL ~i ~ U 't ~ ~ Q ~ f6. 7 ~ U ~ ~ ~1 ~ ~ ~ ~, N i 1 - 'C~ ~ ~ `°, • O~ ~ 'C~ ~ ~ .-~ N ,~ i C ~ f/1 f6 : C N, y: N 1 W ~ 07 3, "' .~ p. ~ f6 0 N: ~ M: ! - ~i V 7 y O N: U C O ~ ' Q ~ 3 ~ ° a: N~ ' N: ~ ~ ~ ~ ~ ~ ~ c _~ ~, ~, ~ ~ ar io . : ~~ >. ~p w O~ O , a: 4 ' 3: N. O ~ v' ~ ~ ' o: t. ~ ~ m .g E m' , : . o ~.,y ~ u'r a O ' ~ a' ~ v°i ~ ' vi ' ° i U W I Z ~ ~ ~ ~ ~ ~ ~ .a. ~~ OS p a' : N. ~ ~ °: N. ;O~ N~ v tD N. y ' o .N: ~ ,, >: w. ~ ~ ~ c ~~ ~~ • ~ O) C. C y, >: m. ' O y c Q °: O. O y: a. ~ N, ~ ~ ~ ~' ~ : ' O ~~, ~ C' ~ N N C• ~: ' N N ° O. O. Di 0: ~ D7 J I ~ J r ~ ~ ~ ~ ~, O ~, O _ a: a 7 ,C, C E O' a' r J . N. C7 N O ~ ~~ ~ c c: ~ 3' O . N, ~, ~ '"" ' c ~ (6' Q U, N Y ~ _ p ~ C. N. O N d O N• N t ~ N' ~. J. O c p ~ Y :: w-. ~ U ~ U f0~ N N ~ °~ a' it O, U O O 7, d U' Q: : N O. dj~ d. ~ .Q~ 3~ f0 > f6' ~' Y N t/1 J N ~ ~ N. p. .O N N C: c: 7 7 O p w ~ a ~ m ~ ~ G : Y ~' a. O N' (6. C (6 O' Q. ~~ ~~ (`~ N. ~ a O: T OD O• N' N .N m , • a v~ N~ 3 C U i a ~ °: m. c, a. • m ~ o u ; ,a. . m. fl, ~ o, ~_ t d °?. ~3 ~3 n a ° m' ° m a. E a' ~ a~ N' ~; ' ~: c ° o ~ ~ ~.-, m: ._: a>: M. m N: ~: °i N' ~, ° a~ . d d 3 °~ N' w ° ~ 3 ° ~ ~ . o c E w o o a O a -°: ~: °: c: ._: : `°: ~ `°. ~: o: > : a' ~: m •~ a a ~ O ~ m' ~: .. o ~: o: c' ~ ~ ~: o o: ~.: °: o' c. ° o ~: ~ o' N ' a Q n m: m' ~ o: o. o: rn c 0 a. d .c, Z N: ~ ~•-' a~ U ° ° w (0' ' ' ~ ' ' O' d N: d d N N. Q ul~ y: d ~': N: U, d d ~: -~ a O ' -a N ' ' ~ ~ U N 3' ~ y C O d o: ~: ~: o, o, ~ ~ ~ ~ or .~ !~ co y; r- c: N: of d m m m ~ ~ ° O ~ of >, 2. ° y, v ~N, ,o. a a N Q ~ _ N. ~ d fl. N. N, a~' a~~ J+ y' ~ m 3, C, a' 03 O' C 0' • 8* N' ~ C' ~ N' ~' a' OQ ~: ~' °: U O' V' N' .N.~ ~' :p N~ ii („) m' ~: _: -o: ~. y: ~: a m. -o. m. ° m. v' c' °, .n. n: o s. c c a ~: w' ar ~ ~ U. ~ ~, ~ in' ' a' >o ? ~ . w ' s. ar ,~ 3. N ~ o: N, ' °: o: ~; m. n. c ~ c m. ~ c: c, o: ~ m. O ~ Z ° ~ °. 3. w: c v m. ° m. U ~ m. ~ m. ° `o' o U °' E m: v ° a~ 3 w 'a' >' o, ~ m ~ m ° _ - y m a - _ ~, ° o' ~' a ~ m a ~: -_, c. v - ° .~ cu rn i °: a~' m ° ~ c ~ O o; ~, -°; -°' -°; •~; •f6' ~; ~: a ° a~, ~ ~ ' ~ '' '' 3' °c' ~' ~ ~ a~i' °1 w; w, ~ 3: N' °: ' °- ~, a' ~ -~~. Y , •~ °~ ` ' `6 °' ° ~' -°0 ' a 4 4 a ; m m 3: ~ o o' ~ ~; ~' ~; m a '~ o ~ c' O; O; ~ °' d ~ ~ ~; ~' .~: `6 o ~ >, ~ m a i a ~ ~' J ~' ~' ~ ~-; ~ ~ a; a o O ~ ~; a; a; z; , v; cn ~ ~ v . c~ a ~; a ~; - , m m ~ `~' ~; ~' ~ o a a i, <n cn v U m . , : ~ ~ , , , , , , , , , . , ~ , , ~ ~ ~ , , , , .~ ~- O N M ct __-____- O CO f~ W O W ~ ~ ~ _. ~- ~ ~~ ~ ~~ N _-- ~ N - N N _ M~ N N __. __ u•> CO f~ W N N N N ___.___ O O ~ N M M _ _- N M V M M_,M ~ C° M M -- -_. h eD M M_ O _M (rJ U ~ O O O N C H O O C ~' N ! " ~ ~ ... ~ w N 0 V U O N a ~ ~ ~ ~ N ~I, C ~ N r N o , ~~ H I 1 ^~ ~ J N ~ C • a I~ i N ~ a ~ ! ~ ~ -° a O O U W a ~ d a ~ c~ i w d a w ~ ° ~ d w acn s ~ Well History File APPENDIX Information of detailed nature that is not particulariy germane to the Welf Permitting Process but is part of the history file. To improve the readability of the Wetl History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. r~ cd3-301.tapx Sperry-Sun Drillin services LIS Scan Uti~ity $Revision: 3 $ LisLib $Revision: 4 $ Tue Jun 19 15:38:18 2007 Reel Header Service name .............LISTPE Date . ...................07/06/19 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date . ...................07/06/19 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. Physical EOF Comment Record TAPE HEADER Colville River Fiord MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 W-0004925845 E. QUAM D. BURLEY SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD ~~ Scientific Technical services Scientific Technical Services CD3-301 501032054300 ConocoPhillips Alaska, Inc. Sperry Drilling Services 19-JUN-07 5 12 5 E 1382 680 50.22 13.50 Page 1 ~o'~ ~, oa3 ~~s~~ • 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: cd3-301.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.750 9.625 3232.0 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 WELL SECTION WAS DRILLED TO THE INTERMEDIATE CASING POINT. MWD SERVICES FOR THE PRODUCTION SECTION WILL BE PROVIDED BY A DIFFERENT CONTRACTOR. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), GEOPILOT ROTARY-STEERABLE BHA (GP) WITH AT-BIT GAMMA (ABG), AND PRESSURE WHILE DRILLING (PWD). 6. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 7. MWD RUNS 1,2 REPRESENT THE INTERMEDIATE SECTION OF WELL CD3-301 WITH API#: 50-103-20543-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12076'MD/6850'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. File Header Service name... .......STSLIB.001 Service SUb Level~Name... version Number. ........1.0.0 Date of Generation.......07/06/19 Maximum Physical Record..65535 Page 2 r~ U cd3-301.tapx File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPD RPM RPS RPX FET ROP 1 clipped curves; all bit runs merged. .5000 START DEPTH 3206.0 3220.0 3220.0 3220.0 3220.0 3220.0 3232.0 STOP DEPTH 12038.5 12030.5 12030.5 12030.5 12030.5 12030.5 12076.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 2 3206.0 12076.0 REMARKS: MERGED MAIN PASS. 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 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MwD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 3206 12076 7641 17741 3206 RPD MwD OHMM 0.24 2000 7.50185 17622 3220 Page 3 Last Reading 12076 12030.5 i cd3-301.tapx • RPM MWD OHMM 0.21 2000 6.25214 17622 3220 12030.5 RPS MWD OHMM 0.44 2000 5.41617 17622 3220 12030.5 RPX MWD OHMM 0.75 1660.57 5.18616 17622 3220 12030.5 FET MWD HOUR 0.15 59.79 0.582804 17622 3220 12030.5 GR MWD API 52.53 415.97 127.785 17666 3206 12038.5 ROP MWD FT/H 7.55 509.36 192.093 17689 3232 12076 First Reading For Entire File..........3206 Last Reading For Entire File...........12076 File Trailer Service name... .......STSLIB.001 service sub Level Name... Version Number. ........1.0.0 Date of Generation.......07/06/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/19 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 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 CODE START DEPTH STOP DEPTH GR 3206.0 12038.5 RPD 3220.0 12030.5 RPM 3220.0 12030.5 RPS. 3220.0 12030.5 RPx 3220.0 12030.5 FET 3220.0 12030.5 RoP 3232.0 12076.0 LOG HEADER DATA DATE LOGGED: 16-APR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12076.0 TOP LOG INTERVAL (FT): 3243.0 BOTTOM LOG INTERVAL (FT): 12076.0 BIT ROTATING SPEED (RPM): Page 4 • cd3-301.tapx HOLE INCLINATION (DEG MINIMUM ANGLE: 54.3 MAXIMUM ANGLE: 85.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 134745 EWR4 ELECTROMAG. RESIS. 4 121079 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 3232.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.80 MUD VISCOSITY (S): 45.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 600 FLUID LO55 (C3): 3.4 RESISTIVITY (oHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.520 72.0 MUD AT MAX CIRCULATING TERMPERATURE: .820 140.0 MUD FILTRATE AT MT: 1.350 72.0 MUD CAKE AT MT: 1.250 72.0 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 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 RoP MwD020 FT/H 4 1 68 28 8 First Last Page S cd3-30 1.tapx Name service unit Min Max Mean Nsam Reading Reading DEPT FT 3206 12076 7641 17741 3206 12076 RPD MwD020 OHMM 0.24 2000 7.50185 17622 3220 12030.5 RPM MwD020 oHMM 0.21 2000 6.25214 17622 3220 12030.5 RPS MWD020 OHMM 0.44 2000 5.41617 17622 3220 12030.5 RPX MWD020 OHMM 0.75 1660.57 5.18616 17622 3220 12030.5 FET MwD020 HOUR 0.15 59.79 0.582804 17622 3220 12030.5 GR MwD020 API 52.53 415.97 127.785 17666 3206 12038.5 ROP MWD020 FT/H 7.55 509.36 192.093 17689 3232 12076 First Reading For Entire File..........3206 Last Reading For Entire File...........12076 File Trailer Service name... .......sTSLI6.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/19 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/06/19 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOwN Comments .................STS LIS writing Library. Reel Trailer Service name .............LISTPE Date . ...................07/06/19 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF End Of LIS File writing Library. Page 6 scientific Technical Services scientific Technical Services
