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206-173
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/16/10 Inspector: Bob Noble Operator: CPA Well Name: CD4-213 Oper. Rep: Rich Ligenza PTD No.: 2061730 • Oper. Phone: 670-4220 Location Verified? Yes Oper. Email: If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 04/01/08 Date AOGCC Notified: 09/14/10 Sundry No.: 308-052 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 0 Photos Taken? Yes IA 0 OA 320 SCONE° AUG 1 4 2015 Condition of Wellhead: The wellhead location was veridied with the use of a plot plan.Wellhead looked to be in good working condition.All lines were blinded with gauges.2"of clean H2O in welded steel cellar box.Wellhouse was removed for near by well work.Rich told me that a wellhouse will be installed to protect the wellhead. Condition of Surrounding Surface The pad condition looked to have good clean gravel. Location: Follow Up Actions None Needed: Attachments: Photos(3) REVIEWED BY: Insp.Supry Comm PLB 09/2010 2010-0916_Suspend_CRU_CD4-213_bn.xlsx Suspended Well Inspection—CRU CD4-213 PTD 2061730 Photos by AOGCC Inspector B. Noble 9/16/2010 • I r ilkOkue (11 Mar In' •II!• e 1 Mr NJ ■ r I a MN 0111.1Pr r wM IimmirAmmilirr I_ I r - 1-4111111111!_l_ "IP 21111111111Mfr- 1111 I left T.,simmilielisol • in 11111. MI --I 4414 • - 2010-0916_Suspend_CRU_CD4-213 photos.docx Page 1 of 2 . . - --.0111111ii 0 1 111110".5".. 41 .. ' _ sir-, It 1 ,,„,.. v F., i II - . 114F,..-- -- , 41 I; ' 1 1 : .. i , Nei: .-- '5411.11111s _ ...11 -at, •121 iii.1: ! j i as . awes tall —- – - -- ..ugg NI 1 rim Sim I EN 1 - .P---- _.--r : or 1, • wir,op7.--44 oh - __ t., • re !HON I PA I1.11 I I I- -------- .....,- .. ._ I -1 - IMPIP.r 'Alum a I 1 r r--- -ow, MO IC 00!i it. i 0 _ 10 Nal F11 t 111111bmomm lir amoin v i Apirmammss—rer I VIlili nineeln~ ' - •-•.lior.. ....-- * Allt...444,.........." • „., , 7•Aleht...,--"..".". ........,.....,.....,.. -, .. ••.- ,.., • - . ', ,.i•,:;*2( , "VIP ,'''....t '; ,- -.%.•,14.1. - •-- . ...WI- • 44 - .. NItir: i . i -1AVVA 110001. - ...i:14 Akif?Vs - --- . 2010-0916_Suspend_CRU_CD4-213_photos.docx Page 2 of 2 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ©~- ~ ~ Well History File Identifier iin done Two-sided III II~IIIIIIII IIIII ^ Rescan Needed III II~IIIIIII IIIIII Orgam g c ~ ^ RE CAN DI AL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. I ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~s~ Pro "ect Proofin II I II II'I I I III I I III ! g BY: Maria Date: ~ /s~ Scannin Pre aration ,_~ x 30 = + ~ =TOTAL PAGES g p / (Count does not include cover sheet) BY: Maria Date: (~ I ~ ~D ~s~ Production Scanning Stage 1 BY: Stage 1 BY: Page Count from Scanned File: ~ (Count does include cover eet) Page Count Matches Number in Scanning Preparation: YES NO Maria Date: ~ ' D ~s~~ If NO in stage 1, page(s) discrepancies ere found: YES NO Maria Date: ~siu a ^i n u~ it i i m Scanning is complete at this point unless rescanning is required. Rescanned III IIIIIIIIIII IIIII BY: Maria Date: ~s~ Comments about this file: Quality Checked !II IIIIII III II'I III 10/6/2005 Well History File Cover Page doc RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 3 0 2013 WELL COMPLETION OR RECOMPLETION REPORT ANDA - CCla.Well Status: Oil ❑ aSPLUG El ❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory LI GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑J StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: May 6,2012 206-173/311-309/312-006 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 December 26,2006 50-103-20540-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 2942'FNL,303'FEL,Sec.24,T11N,R4E, UM January 3,2007 CD4-213 Top of Productive Horizon: 8.KB(ft above MSL): 36'RKB 15.Field/Pool(s): 305'FNL,3132'FEL,Sec.25,T11N,R4E,UM GL(ft above MSL): 55'AMSL Colville River Field Total Depth: 9.Plug Back Depth(MD+TVD): 305'FNL,3132'FEL,Sec.25,T11N, R4E, UM 2339'MD/2119'TVD Nanua-Nanuq Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-377941 y- 5957470 Zone-4 8305'MD/6191'TVD ADL 380077,384209,380075 TPI: x-375070 y- 5954875 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-375070 y- 5954875 Zone-4 none 380077 18.Directional Survey: Yes ❑ No O 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1547'MD/1500'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD none 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" 62.58# H-40 36' 114' 36' 114' 24" pre-installed 9.625" 40# L-80 36' 2713' 36' 2389' 12.25" 349 sx AS Lite,234 sx Class G 7" 26# L-80 36' 8295' 36' 6201' 8.75" 187 sx LiteCRETE,287 sx Class G 24.Open to production or injection? Yes ❑ No ❑✓ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) na none 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes❑ No Q DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED cement plug @ 2403-2980' 308 sx Class G SCM4 ED MAY 2 7 2014 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) not applicable . plugged and suspended Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No 0 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 RBC=MS MAY 2 2 20140 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original only 4 j 29. GEOLOGIC MARKERS(List all formations and ma, encountered): 30. FORMATION TESTS NAME MD TVD Well tested? El Yes Q 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 1547' 1500' needed,and submit detailed test information per 20 AAC 25.071. C-30 2747' 2414' C-20 3284' 2808' K-3 4692' 3841' K-2 5040' 4095' Nanuq 8206' 6191' N/A Formation at total depth: Nanuq 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Scott Brunswick @ 263-4349 Email: Scott.A.Brunswickconocophillips.com Printed Name G. L.Alvord Title: Alaska Drilling Manager Signature AL Phone 265-6120 Date 5(26 3 //// ���� INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 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 10/2012 G.L.Alvord Alaska Drilling Manager Drilling&Wells RECEIVED P.O.Box 100360 Ire" Anchorage,AK 99510-0360 ConocoPhiHips AUG 3 0 2013 Phone: 907-265-6120 AOGCC August 28, 2013 AOGCC Commissioner 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Subject: Revised Completion Report for CD4-213 and CD4-213A Dear Commissioner: Attached for your review are the revised completion reports for CD4-213 and CD4- 213A. We have updated the geologic markers as requested. The core analysis is being handled by another department. We will not include the daily operations summary or the directional survey with this submittal because we have already sent these documents. If you have any questions, please feel free to call me at anytime. Sincerely, /4La- G. L. Alvord Alaska Drilling Manager CPAI Drilling GLA/SB/skad • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION a ❑ ❑ h ❑ OR RECOaMPLETIOuNen REPORT'AND LOG la.Well Status: Oil ❑ 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service El Stratigraphic Test 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: May 6,2012 .206-173/311-309&312-006 - 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 December 26,2006 50-103-20540-00. 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 2942'FNL, 303'FEL,Sec.24,T11 N, R4E, UM January 3,2007 CD4-213 Top of Productive Horizon: 8. KB(ft above MSL): ,46 KBt ` ,5.Field/Pool(s): 305'FNL,3132'FEL,Sec.25,T11 N, R4E,UM GL(ft above MSL): 55'AMSL Colville River Field Total Depth: 9.Plug Back Depth(MD+TVD): 305'FNL,3132'FEL,Sec.25,T11 N, R4E, UM 2339'MD/2119'TVD Nanuq-Nanuq Oil Pool., 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: . Surface: x-377941 y- 5957470 Zone-4 8305'MD/6191'ND ADL 380077,384209,380075 TPI: x-375070 y- 5954875 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-375070 y- 5954875 Zone-4 none 380077 18.Directional Survey: Yes ❑ No 0 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1547'MD/1500'ND 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD none not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.58# H-40 36' 114' 36 114' 24" pre-installed 9.625" 40# L-80 36' 2713' 36' 2389' 12.25" 349 sx AS Lite,234 sx Class G 7" 26# L-80 36' 8295' 36' 6201' 8.75" 187 sx LiteCRETE,287 sx Class G 24.Open to production or injection? Yes ❑ No El If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) na none ECEIV ED 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED JUL 2 3 2012 cement plug @ 2403'-2980' 308 sx Class G AOGGC 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) not applicable plugged and suspended Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. psi 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No El Sidewall Cores Acquired? Yes ❑ No Q 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 NU�� d Z�J1B scow {RBDMS JUL 2 5 2012 Ageir, CONTINUED ON REVERSE 1 Submit original onl Form 10-407 Revised 12/2009 a /_ / i_1(1/1� Y G to- 28. GEOLOGIC MARKERS(List all formations and ma encountered): 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 1547' 1500' needed,and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: none 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: co Brunswick @ 263-4349 L-41, G Ltu&V4S FOR- Printed Name G.L.Alvord Title: Drilling Manager Signature f Phone 265-6120 Date 7/20/12 265-6120 / Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 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 • • ConocoPhiflips Time Log & Summary We/Mew Web Reporting Report Well Name: CD4-213 Rig Name: DOYON 19 Job Type: DRILLING SIDETRACK Rig Accept: 5/28/2012 12:00:00 AM Rig Release: 7/1/2012 11:59:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/30/2012 24 hr Summary Rig was released f/CD3-127 @ 1800 hrs 4-30-2012. Ball mill moved off CD3,moved to CD4 pad and out of the way-on location @ 2230 hrs. Moved pipe shed away from the rig.Moved pits and motors away from rig. Skid rig floor off cantilever(approx 30'). Note:Camp was moved&on location @ approx 1700 hrs 4-30-2012. 18:00 00:00 6.00 MIRU MOVE MOB P Rig released from CD3-127 on 4-30-12 at 1800 hours-Ball mill moved off CD3 @ 1930 hrs,moved to CD4 pad and out of the way-on location @ 2230 hrs. Moved pipe shed away from the rig. Moved pits and motors away from rig.Skid rig floor off cantilever(approx 301 Note:Camp was moved&on location @ approx 1700 hrs 4-30-2012. 05/01/2012 Moved pit,motor complexes,pipe shed&Sub base f/CD3 to CD4-Spotted pit&motor complexes-Spot sub onto CD4-213 00:00 00:00 24.00 MIRU MOVE MOB P Moved pit,motor complexes,pipe shed&sub base f/CD3 to CD4-213- Spot pit&motor complexes- Spotted sub base over well 05/02/2012 Skid floor-Mate up pits/motor complexes-spot ball mill&pipe shed-Pull BPV- Circ out freeze protect diesel-set BPV-ND tree-set blanking plug-NU BOPE stack-Begin testing BOPE 00:00 01:00 1.00 0 0 MIRU MOVE MOB P Move over and spot Sub on CD4-213. 01:00 01:30 0.50 0 0 MIRU MOVE RURD P Lower and set feet, lower and secure windwalls. 01:30 02:30 1.00 0 0 MIRU MOVE RURD P PJSM and skid floor to drilling position. 02:30 03:30 1.00 0 0 MIRU MOVE MOB P PJSM and spot pits and motor complexes. 03:30 05:00 1.50 0 0 MIRU MOVE RURD P PJSM, RU service lines, take on diesel& water to rig, rig on Highline power @ 0400 hours, Rig acceptance 0400 hrs 5/2/2012 05:00 06:00 1.00 0 0 SLOT RPCOM RURD P Install double valve on upper annulus and work platform on tree-RU high pressure lines from annulus to tiger tank 06:00 07:15 1.25 0 0 SLOT RPCOM RURD P RU kill manifold and lines on floor, RU hardline to upper annulus at wellhead, RU bleed lines to waste tank in cellar Page 1 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:15 08:00 0.75 0 0 SLOT WHDBO PRTS P PJSM-Fill lines to tiger tank with water-Pressure test lines to 1000 psi-blow down lines IA=0 psi OA=450 psi 08:00 08:30 0.50 0 0 SLOT WHDBO PRTS P RU and test hardline to annulus to 2000 psi-Blow down lines **Rig Electrician tested gas alarms 08:30 09:15 0.75 0 0 SLOT WHDBO PRTS P Pumped down annulus-tested casing and BPV in direction of flow to 2000 psi for 10 minutes-blow down lines 09:15 10:00 0.75 0 0 SLOT WHDBO RURD P PJSM,pull tree cap,and rig up FMC lubricator 10:00 10:30 0.50 0 0 SLOT WHDBO PRTS P Test lubricator @ 2000 psi,for 5 min -attempt to pull BPV 10:30 12:45 2.25 0 0 SLOT WHDBO OTHR T Continued to pull BPV-BPV release from tubing profile threads-working to pull through master valve on tree- FMC tech reviewed difficulty with his town support-gradually able to manually work BPM above master valve with spanner wrench on lubricator rod-closed master valve and backed off tree cap coupling on lubricator-attached a tugger to lubricator and pulled BPV through swab valve-LD lubricator 12:45 13:15 0.50 0 0 SLOT WHDBO RURD P Install tree cap adapter-RU hardline to tree cap and manifold 13:15 13:30 0.25 0 0 SLOT WHDBO PRTS P Pressure test lines(tubing side)to 2000 psi for 5 minutes 13:30 14:15 0.75 0 0 SLOT RPCOM CIRC P PJSM, Displace diesel w/50 bbls fresh water w/safe surf-o, 121 bbls 9.6 ppg brine, FCP=7.0 BPM/ 1480 PSI-blow down lines 14:15 14:45 0.50 0 0 SLOT RPCOM OWFF P Monitor well static for 30 minutes 14:45 15:15 0.50 0 0 SLOT WHDBOTHGR P Install BPV into tubing hanger 15:15 15:45 0.50 0 0 SLOT WHDBO PRTS P Pump down annulus and test BPV in direction of flow to 1000 psi for 10 minutes 15:45 16:15 0.50 0 0 SLOT RPCOM RURD P RD kill manifold and hardlines 16:15 17:15 1.00 0 0 SLOT WHDBO NUND P PJSM-ND tree,install FMC blanking plug 17:15 19:45 2.50 0 0 SLOT WHDBO NUND P PJSM on NU BOPE-NU BOPE- grease choke manifold for BOP test 19:45 00:00 4.25 0 0 SLOT WHDBO BOPE P PJSM on Ru to test-Tested BOPE as follows:w/4"test jt.tested Annular to 250&2500 psi-Tested upper pipe rams,TD IBOP's, Floor safety&dart valves,Choke&kill line valves,Choke manifold valves# 1,2,5,7,10,11,12,13,14,15,&16 to • 250&3500 psi Page 2 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code -Subcode T Comment 05/03/2012 24 hr Summary Finish test BOPE-Pull&LD 4 1/2"kill string-RIH&set CIBP @ 2980'-test to 2500 psi-POOH w./DP& setting tool 00:00 07:30 7.50 0 0 SLOT WHDBO BOPE P Cont.testing BOPE-Tested choke manifold valves#3,4,6,8,9-HCR Wit choke-4"Demco on kill line- VI? manual kill&choke valves-Lower pipe rams w/4"test jt to 250&3500 psi-Performed accumulator recovery test(function remote BOP control panel in boiler room)Attempt to test blind rams(door seal leaking)- replaced seal and tested Blind rams 250/3500 psi-Tested annular preventer 250/2500 and Upper& lower pipe rams 250/3500 w/3 1/2" &4 1/2"test joints-Performed flow through tests on Super choke and manual choke 500 psi to 1000 psi- John Crisp(AOGCC)waived witnessing tests-pull test plug- blow down lines 07:30 08:15 0.75 0 0 SLOT WHDBOTHGR P Pull FMC blanking plug, pull BPV. 08:15 08:45 0.50 0 0 SLOT RPCOM RURD P PJSM-RU to pull 4-1/2"tubing kill string. 08:45 09:00 0.25 0 0 SLOT RPCOM SFTY P Held PJSM on hazards associated with laying down tubing 09:00 09:45 0.75 0 0 SLOT WHDBO OTHR P MU landing jt.A into tubing hanger- BOLDS 09:45 10:15 0.50 0 2,270 SLOT RPCOM PULD P Unseat tubing hanger w/92K- monitor well,static-Pull hanger to rig floor 90K PUW-LD LJ and hanger 10:15 13:30 3.25 2,270 0 SLOT RPCOM PULD P POOH with Kill string from 2270'- laid down 56 joints of 4 1/2"tubing& wleg 13:30 14:15 0.75 0 0 SLOT RPCOM RURD P Rig down tubing tongs-clean up rig floor 14:15 14:30 0.25 0 0 SLOT WHDBO OTHR P Install FMC wear ring into wellhead (7")ID. 14:30 14:45 0.25 0 0 SLOT CSGRC'RURD P Change elevators to 4" 14:45 16:30 1.75 0 895 SLOT CSGRC'TRIP P MU Baker"N-1"Bridge plug-RIH picking up 4"drill pipe to 895' 16:30 17:00 0.50 895 895 SLOT CSGRC'SVRG P Service Drawworks and Iron roughneck 17:00 19:15 2.25. 895 2,982 SLOT CSGRC'TRIP P Cont. RIH w/Bridge plug f/895'to 2982'(picking up 4"DP f/pipe shed) -PU wt 110 SO wt. 105 19:15 19:45 0.50 2,982 2,980 SLOT CSGRC'OTHR P Drop 1 7/16"ball-Pressure up to 800 psi to set bridge plug-bleed pressure to 200 psi-PU to 130 k- � Observed shear-Set back down w/ 5 k to verify plug set(Top of plug @ 2980') 19:45 20:15 0.50 2,980 2,963 SLOT CSGRC'RURD P LD 1 jt. DP to 2963'-Blow down TD- RU to pressure test bridge plug Page 3 of 58 • • Time Logs Date From To Dur S.Depth E. Death Phase Code Subcode T Comment 20:15 20:30 0.25 2,963 2,963 SLOT CSGRC'PRTS P Pressure test casing&bridge plug to 2500 psi for 10 mins. 20:30 21:00 0.50 2,963 2,963 SLOT CSGRC'RURD P Bleed off pressure-Blow down lines -Break out head pin,valves&hose 21:00 21:30 0.50 2,963 2,963 SLOT CSGRC'CIRC P Circ&wt up to 9.8 ppg brine 21:30 21:45 0.25 2,963 2,963 SLOT CSGRC'OTHR P Blow down TD-fill TT w/9.8 ppg brine 21:45 22:00 0.25 2,963 2,963 SLOT CSGRC'OWFF P Flow ck well-static 22:00 00:00 2.00 2,963 0 SLOT CSGRC'TRIP P POOH w/DP&bridge plug setting tool-LD XO&setting tool 05/04/2012 Change out ULDS-Test-MU casing cutter-RIH cut 7"casing @ 2642'-Circ-POOH-MU spear-Pull& LD 60 jts+cut-off jt 7"csg 00:00 00:15 0.25 0 0 SLOT CSGRC'PULD P Clear tools from floor 00:15 01:00 0.75 0 0 SLOT WHDBO SEQP P PJSM-Drain stack-Pull wear ring and set upper test plug and change out one LDS identified as bad when backed out prior to pulling tubing hanger-Pressure test replacement LDS 250/3500 psi-Pull test plug- set wear ring(7"ID.) 01:00 01:30 0.50 0 40 SLOT CSGRC'PULD P PJSM-MU Baker 7"casing cutter assembly onto 1 jt.of 4"drill pipe 01:30 03:15 1.75 40 2,980 SLOT CSGRC'TRIP P RIH with casing cutter-tagged top of bridge plug @ 2980' PUW 110K SOW 105K 03:15 03:30 0.25 2,980 2,946 SLOT CSGRC'CIRC P Establish circulating rates/ pressures-3.8 bpm/600 psi-5.0 bpm/1000 psi-Pull up and locate casing collar with cutter blades @ 2946' 03:30 03:45 0.25 2,946 2,968 SLOT CSGRC'CIRC P RIH to put cutter on depth @ 2968' obtain SPP's-20 spm/70 psi-30 spm 280 psi OA pressure=320 psi 03:45 04:00 0.25 2,968 2,968 SLOT CSGRC'CPBO P Cut 7"casing at 2968'- 3.8 bpm/ 630 psi/80 rpm @ 6K ft/lbs torque- observed pressure drop to 150 psi 04:00 04:15 0.25 2,968 2,968 SLOT CSGRC'SFTY P Pre-job Safety and Opts meeting on displacing out freeze protection diesel-OA pressure=350 psi 04:15 04:30 0.25 2,968 2,968 SLOT CSGRC'CIRC P Close top pipe rams-open annulus return line to tiger tank-Attempted to establish circuation up 9 7/8 x 7" annulus-pumped 1 bpm/1020 psi for 8 blls pressure increased to 1230 psi-unable to establish circulation- bleed off stand pipe-2 bbls back to trip tank 04:30 04:45 0.25 2,968 2,968 SLOT CSGRC'CIRC P Opened rams-observed slight fow- circulate BU-5.0 bpm @ 300 psi- Brine wt.9.8 ppg 04:45 05:00 0.25 2,963 2,963 SLOT CSGRC'OWFF P Pulled up 5'to 2963'-Monitored 7" annulus-slight flow-at times static Page 4 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 05:45 0.75 2,963 2,963 SLOT CSGRC'CIRC P Circulate and check fluid wt.'s-4 bpm/700 psi(knives closed)-Brine wt. in&out @ 9.8 ppg 05:45 06:00 0.25 2,963 2,963 SLOT CSGRC'OWFF P Monitored 7"annulus-slight flow-at times static OA pressure=0 psi 06:00 06:30 0.50 2,963 2,613 SLOT CSGRC'TRIP P POOH to 2613'-hole took proper displacement-flow check well, static 06:30 06:45 0.25 2,613 2,644 SLOT CSGRC'CPBO P Establish circulation-3.0 bpm/350 psi-locate Casing collar @ 2646'- PU 2'to 2644' OA pressure=0 psi 06:45 07:00 0.25 2,644 2,644 SLOT CSGRC'CPBO P Cut casing at 2644'-4.5 bpm/690 psi/80 rpm @ 5.5K ft./lbs.torque- observed 200 psi pressure drop on standpipe-OA pressure increased to 390 psi-flow check 7"annulus, static 07:00 07:15 0.25 2,644 2,644 SLOT CSGRC'SFTY P Pre-job Safety and Opts meeting on displacing out freeze protection diesel-OA pressure=390 psi 07:15 08:00 0.75 2,644 2,644 SLOT CSGRC'CIRC P Closed top pipe rams-open annulus return line to tiger tank-Displace 9 5/8"x 7"annulus with 120 bbls of 9.8 ppg brine- 3 bpm 400 psi ICP/510 psi FCP 08:00 08:15 0.25 2,644 2,644 SLOT CSGRC'OWFF P Observed return line at tiger tank- slight returns to tank-open pipe rams and monitor well-shut in 9 5/8"x 7"annulus valves at wellhead OA pressure gauge=10 psi-well static with fluid at flowline 08:15 08:45 0.50 2,644 2,644 SLOT CSGRC'CIRC P CBU-5.0 bpm/300 psi-observed small amount of gas at BU-returns looked clean after surface to surface volume pumped-Brine wt.9.8 ppg in &out-repeated cut verification steps -casing appears cut 08:45 09:30 0.75 2,644 2,644 SLOT CSGRC'OWFF P Flow check well,static at flow line- OA pressure=10 psi-opened bleed line on OA-had returns to waste tank in cellar-Drained stack- opened upper and lower annnuli to bleed tand in cellar-monitored well static for 20 minutes-shut all annulus valve on wellhead 09:30 11:45 2.25 2,644 40 SLOT CSGRC'TRIP P POOH on elevators from 2644'to 40' -hole took proper fill-observe well for 5 minutes static 11:45 12:15 0.50 40 0 SLOT CSGRC'PULD P Break out and lay down casing cutter assembly Page 5 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:15 12:30 0.25 0 0 SLOT CSGRC'SFTY P PJSM-Prepare for changing pipe rams-1st day back for crew- discussed recent sole controle hand injuries-commitment from crew to add focus to hand placement and pinch point awareness 12:30 13:45 1.25 0 0 SLOT WHDBO SEQP P Change top pipe rams to 7"blocks 13:45 14:15 0.50 0 0 SLOT WHDBO PULD P Pull wear ring and set upper test plug into wellhead 14:15 15:15 1.00 0 0 SLOT WHDBO BOPE P Fill stack with water-pressure test 7"rams 250/3500 for 5 minutes each -pull test joint and plug 15:15 15:45 0.50 0 0 SLOT WHDBO SFTY P PJSM-Discussed plans to pull packoff,set wear ring and MU casing spear assembly-Identified hazards for each job-requested strong focus on hand placement and pinch points 15:45 16:15 0.50 0 0 SLOT WHDBO PULD P Engage packoff with retrieving tool- open lower annulus and confirm static-BOLDS-pull packoff with tugger-Set thin wall wear ring in wellhead(10.3"ID.) 16:15 17:15 1.00 0 0 SLOT CSGRC'FISH P MU Baker Itco spear assembly-RIH w/spear&engage 7"casing(3' below casing hanger)-PU and unseat hanger&pull up to just above flow line-PUwt120k 17:15 18:15 1.00 0 0 SLOT CSGRC'CIRC P Circ 2 X btms up @ 5 bbl/min @ 100 psi-Flow ck well static in 17 mins. 18:15 19:15 1.00 0 0 SLOT CSGRC'RURD P Pull 7"casing hanger to above rotary table-Release spear&LD spear assembly-Change elevators f/5" DP to 7"side door to pull casing 19:15 23:30 4.25 0 0 SLOT CSGRC'PULL P Pulled&LD 60 jts(2567.04')7'26# 0 L-80 casing&41'cut-off-7"26# L-80-recovered 30 Ray Oil Tool 7" -1" centralizers-Flow ck well static 23:30 00:00 0.50 0 0 SLOT CSGRC'RURD P RD casing equipment-Pull thin wall wear bushing 05/05/2012 Change rams-MU Spear assembly#2-RIH-Engage fish-Jar free-PU to 2713'-Circ btms up-Raise brine wt to 11.5 ppg-POOH w/fish f/2713'to 540' 00:00 01:00 1.00 0 0 SLOT WHDBO SEQP P PJSM-Drain stack-Change top pipe rams to 3 1/2"x 6"VBR's 01:00 02:00 1.00 0 0 SLOT WHDBO BOPE P Set upper test plug-test 3 1/2"x 6" 4t. VBR's to 250/3500 psi for 5 minutes -pull test plug-set wear ring (10.3"ID.) 02:00 02:45 0.75 0 0 SLOT CSGRC'OTHR P Bring tools to rig floor-change elevators to5" 02:45 04:00 1.25 0 230 SLOT CSGRC'PULD P PJSM-MU fishing BHA-Bullnose, Spear Packoff,Spear w/6.22 OD grapple,Spear extention,Stop sub 8.128"OD,XO, (6(6 1/4"DC's,xo,6 1/4"jar,xo 04:00 05:15 1.25 230 2,640 SLOT CSGRC'TRIP P RIH with 4"drill pipe to 2640'-(TOF @ 2644')PUW 115K SOW 110K Page 6 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:15 05:45 0.50 2,640 2,963 SLOT CSGRC'FISH P Engage fish(324'of 7"casing)with spear @ 2653'-Pulled up to 290K after second hit with jars-pipe moving-pulled up 5'-bottom of fish @ 2963' 05:45 06:15 0.50 2,963 2,674 SLOT CSGRC'TRIP P Attempt to circulate-packed off- POOH from 2963'to 2674'- attempting to break circulation while pulling-gained returns with fish inside casing shoe(2713') PUW 125K 06:15 07:15 1.00 2,674 2,649 SLOT CSGRC'CIRC P Establish circulation stage pumps up to 6.0 bpm/300 psi- had flow increase of 3%at 1st BU with gas breaking out of brine-Circulated second BU-Brine wt.9.8 ppg in& out-set back one stand bottom of fish @ 2649' 07:15 07:30 0.25 2,649 2,649 SLOT CSGRC'OWFF P Observed well-no flow observed- gas breaking out at flowline at a mild boil 07:30 07:45 0.25 2,649 2,649 SLOT CSGRC'CIRC P CBU-6.0 bpm/280 psi-MW.in& out 9.8 ppg 07:45 08:30 0.75 2,649 2,649 SLOT CSGRC'OWFF T Observed gas breaking out at flow line-slight flow 08:30 09:45 1.25 2,649 2,649 SLOT CSGRC'CIRC T Circulate-6.0 bpm/250 psi- increase brine wt.to 10.0 ppg 09:45 10:30 0.75 2,649 2,649 SLOT CSGRC'OWFF T Observed well-no change in gas breaking out-mild boil-observed slight drop in annulus -no flow 10:30 10:45 0.25 2,649 2,713 SLOT CSGRC'TRIP T RIH to 2713'(botton of fish) 10:45 11:30 0.75 2,713 2,713 SLOT CSGRC'CIRC T CBU-5 bpm/200 psi-Brine wt. 10.0 ppg in&out 11:30 13:30 2.00 2,713 2,703 SLOT CSGRC'KLWL T Flow check well-no flow-no change in gas breaking out of annulus-position tool joint-bottom of fish @ 2703'-Shut in well with top pipe rams@ 11:30 hours-Monitor shut in pressures-Viscosify brine in pits and wt.up brine to 10.5 ppg- Shutin pressures after 1 hour SIDPP=25 psi SICP=23 psi 13:30 15:15 1.75 2,703 2,703 SLOT CSGRC'KLWL T Circulate through choke with 10.5 ppg kill wt.mud at 3 bpm- Calculated surface to surface volume 188 bbls-10.5 ppg brine back at 210 bbls pumped-toal volume pumped 255 bbls-Shut down pump at 14:55 hrs-monitor returns at possum belly until small strea draining out of gas buster-bled off standpipe and open pipe rams-monitor well, intermittent static then slight flow-then static 15:15 17:00 1.75 2,703 2,713 SLOT CSGRC'CIRC T Lower string to 2713'-circulate and increase brine wt.from 10.5 ppg to 11.0 ppg-6 bpm/180 psi Page 7 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 18:45 1.75 2,713 2,713 SLOT CSGRC'CIRC T Circulate&increase brine wt.f/11.0 ppg to 11.5 ppg @ 6 bbls/min @ 290 psi 18:45 20:15 1.50 2,713 2,713 SLOT CSGRC'OWFF P Monitor well-well static in 15 mins.- Observed gas bubbles breaking out of brine-but fluid level would drop& no flow down flow line-Obtained SPR's-Blow down TD-Flow ck well static 20:15 00:00 3.75 2,713 540 SLOT CSGRC'TRIP P POOH on TT f/2713'to 540'w/hole taking proper fill-FLow ck well static 05/06/2012 LD fishing assembly-LD 7"csg-Test Upper VBR-MU 3 1/2"tbg stinger-RIH on 4"DP to 2980'(Top of CIBP)Circ btms up(observed gas prior to btms up)bump brine to 12.0 ppg-Set KOP w/54.bbls/17.0 ppg cmt-Squeezed 5.2 bbls away-Shut in&maintain 600 psi on cmt plug 00:00 01:00 1.00 540 324 SLOT CSGRC'PULD P LD BHA(intensifer jar-(6)6 1/4" DC's-Jars-Bumper sub)Release spear f/fish-LD spear assembly 01:00 01:15 0.25 324 . 324 SLOT CSGRC'RURD P R/U casing tongs-change elevators f/5"to 7" 01:15 02:15 1.00 324 0 SLOT CSGRC'PULL P Pulled&laid down 7"casing(2' cut-off-7 jts.299'-27'cut-off) 02:15 02:30 0.25 0 0 SLOT CSGRC'OWFF P Monitor well-static 02:30 02:45 0.25 0 0 SLOT CSGRC'RURD P Brought tubing tongs&3 1/2" elevators to rig floor 02:45 03:15 0.50 0 0 SLOT WHDBO SEQP P Pull wear ring-set upper test plug with test joint 03:15 03:45 0.50 0 0 SLOT WHDBO BOPE P Fill stack and test joint with water- Test upper pipe rams(3 1/2"x 6")x 4"test joint to 250/3500 psi 03:45 04:00 0.25 0 0 SLOT WHDBO SEQP P Pull test plug-set wear ring(10.3" OD.) 04:00 04:15 0.25 0 0 SLOT CSGRC'RURD P Rig up to run 3 1/2"tubing 04:15 06:15 2.00 0 911 SLOT CSGRC'PULD P MU mule shoe-RIH picking up 3 1/2"tubing to 911'(29 joints- cement string)-MU XO(3 1/2"EUE x XT-39) 06:15 07:15 1.00 911 2,625 SLOT CSGRC'TRIP P Change elevators to 4"-RIH from 911'to 2625 07:15 08:00 0.75 2,625 2,625 SLOT CSGRC'SVRG P Service-Top drive, Drawworks and Crown 08:00 08:30 0.50 2,625 2,980 SLOT CSGRC'TRIP P RIH from 2625'to top of bridge plug at 2980'-String took wt.@ 2829'- wash down 3 bpm/200 psi-no problems 08:30 10:15 1.75 2,976 2,976 SLOT CSGRC'CIRC P Circulate and condition mud @ 2976' -even out wt.@ 11.6 ppg in&out- observed gas breaking out at flowline -Increased at 1st BU 10:15 10:30 0.25 2,976 2,976 SLOT CSGRC'OWFF P Flow check well-observed slight flow for 15 min-less than 1/4 bbl pit gain Page 8 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 12:45 2.25 2,976 2,976 SLOT CSGRC'CIRC T Circulate and increase brine wt.from 11.6 ppg to 12 ppg -6 bpm/310 psi -obtain SPP's Held Pre job safety and Opts meeting with Cementer and rig team 12:45 13:15 0.50 2,976 2,976 SLOT CSGRC'RURD P Blow down top drive-RU cement line and valves 13:15 14:00 0.75 2,976 2,976 SLOT CSGRC'PLUG P Established circulation with 3 bbls of 12.5 ppg Mudpush from cementers- Tested lines to 2500 psi-pumped 17 bbls of Mudpush-54 bbls of 17.0 ppg G cement w/adds(308 sxs- 1 cf/sx yld)-3.4 bbls of Mudpush behind and displaced to eqaulization with rig pump-4 bpm/350 psi(12.0 ppg brine)CIP @ 1400 hrs-full returns throughout-ETOC w/100% excess in OH=2502' 14:00 15:00 1.00 2,976 2,403 SLOT CSGRC'TRIP P RD cement line-POOH from 2976' to 2403'-1000 ft/hr pulling speed 15:00 15:45 0.75 2,403 2,403 SLOT CSGRC'CIRC P Insert wiper ball into drill pipe- Pumped 40 bbls of 12.0 ppg brine with 6 lbs/bbl of nutplug-circulate pipe and hole clean 8-10 bpm 400/ 580 psi-saw most of Mudpush back no PH increase observed 15:45 16:15 0.50 2,403 2,339 SLOT CSGRC'RURD P Pulled up to 2339'-blow down top drive-RU cement line and valves- Test lines to 2000 psi 16:15 16:45 0.50 2,339 2,339 SLOT CSGRC'SQEZ T Sqeezed 5.2 bbls of cement away- .25-.5 bpm initial pressure 413 psi G M final pressure 1040 psi-pump shut down @ 1628 hours-ISIP=770 psi 16:45 00:00 7.25 2,339 2,339 SLOT CSGRC'SQEZ T Maintained 600 psi on cmt plug to attempt to shut-off gas migration thru cmt plug-while waiting for cmt to attain 500 psi compressive strength 05/07/2012 Maintain pressure on cmt plug-Bled off pressure-Circ&cond.mud-flow ck(ststic)POOH w/DP&LD tbg -Change handling equipment for 5"DP-Test rams&annular w/5"testjt.-MU clean out assembly-RIH to 2465'(top cmt)CO to 2468'-test cmt plug&csg to 3500 psi-Drill cmt f/2468'to 2710'-Circ&flow ck-Drill cmt to 2732' 00:00 00:30 0.50 2,339 2,339 SLOT CSGRC'SQEZ T Continue to maintain 500 psi on cmt plug to attempt to stop gas migation thru cmt plug 00:30 01:00 0.50 2,339 2,339 SLOT CSGRC'RURD T Bled off pressure-Open rams-RD head pin,valves&cmt hose.-Flow ck static 01:00 03:00 2.00 2,339 2,339 SLOT CSGRC'CIRC P Install bell guide-Circ btms up @ 5 bbls/min @ 340 psi-stage pump up to 10 bbls/min @ 510 psi-Observed contamiated brine w/high Ph and mud wt cut to 11.2 ppg-Circ& condition brine-wt. back up to 11.6 ppg Page 9 of 58 9 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 04:15 1.25 2,339 911 SLOT CSGRC'TRIP P Blow down TD-Flow ck Well static- POOH on TT w/4"DP f/2339'to 911' 04:15 04:30 0.25 911 911 SLOT CSGRC'SFTY P PJSM on rigging up to LD 3 1/2"tbg 04:30 05:45 1.25 911 0 SLOT CSGRC'PULD P POOH&LD 3 1/2"tbg(29 jts)& mule shoe 05:45 06:45 1.00 0 0 INTRMI CSGRC'RURD P RD tubing tongs and elevators-clear equipment from rig floor Install 5" elevators on bails-change heads in Iron roughneck to 5" 06:45 07:00 0.25 0 0 INTRMI DRILL SFTY P Pre job meeting on picking up 5"DP 07:00 07:45 0.75 0 0 INTRMI DRILL PULD P Pick up 21 joints of 5"drill pipe using mousehole and stand back in derrick 07:45 09:00 1.25 0 0 INTRMI DRILL RURD P PJSM on changing saver sub- Change saver sub on top drive to 4 1/2"IF connection 09:00 09:15 0.25 0 0 INTRMI WHDBO SEQP P Drain stack-pull wear rind-set test plug with 5"test joint-fill stack with water 09:15 10:45 1.50 0 0 INTRMI WHDBO BOPE P PJSM-Test annular preventor to p C>P 250/2500 psi-Tested upper&lower {�I 3 1/2"x 6" VBR's pipe rams and floor safety valves to 250/3500 psi- Pull test plug and joint 10:45 11:15 0.50 0 0 INTRM1 WHDBO SEQP P Drain stack-install long wear ring (10"ID) 11:15 12:00 0.75 0 40 INTRMI DRILL PULD T PJSM on making up BHA-MU bit- bit sub-stab-1 NM flex DC to 40' 12:00 12:15 0.25 472 472 INTRM1 DRILL SFTY T PJSM on making up BHA 12:15 15:00 2.75 472 2,200 INTRMI DRILL PULD T Cont.MU 8 3/4"Clean out assembly - (2)6 3/4"NMFC's,4 jts 5"HWDP ,Jars, 7jts 5"HWDP-RIH picking up 5"drill pipe from shed-started taking wt.@ 2183'(55 jts.) 15:00 15:30 0.50 2,200 2,225 INTRM1 DRILL REAM T Fill pipe and wash and ream from 2183'to 2225'-588 gpm/1020 psi/ 50 rpm @ 6000 ft/lbs torque Noticed flow increase-circulate out aired up mud from pipe fill-flow check well, static 15:30 16:30 1.00 2,225 2,468 INTRM1 DRILL REAM T Wash and ream from 2225'to 2465, tagged cement,polished off to 24 68' CiAt �1 -588 gpm/1020 psi 50 rpm @ 6000 ft/lbs-PUW 124K SOW 115K RT. wt. 123K 16:30 17:30 1.00 2,468 2,468 INTRMI DRILL CIRC T CBU-588 gpm/1020 psi/50 rpm @ 6K ft/lbs torqe for casing-Flow ck well static-Blow dwon TD 17:30 17:45 0.25 2,468 2,468 INTRM1 DRILL SFTY P PJSM on rigging up&performing pressure test Page 10 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:45 18:45 1.00 2,449 2,449 INTRMI DRILL PRTS P PU to 2449'-RU&test cmt plug& casing to 3500 psi for 30 mins.-lost 300 psi- Check all surface equipment couldn't find leak-closed valve on mud manifold to pumps- Bled off pressure-Blow down lines& RD *Note-Discovered bad pressure senser 18:45 22:00 3.25 2,468 2,710 INTRMI DRILL DRLG T RIH to 2468'-Drilled cement f/2468' to 2710'-@ 14 bbls/min @ 1020 psi w/50 rpm's @8k torque-10to12k WOB 22:00 22:15 0.25 2,710 2,710 INTRM1 DRILL CIRC T Circ hole clean @ 14 bbls/min @ 1020 psi wl 50 rpm's @ 6 k torque 22:15 22:30 0.25 2,710 2,710 INTRMI DRILL OWFF T FLow ck-well static-obtain SPR's 22:30 00:00 1.50 2,710 2,732 INTRMI DRILL DRLG P Drill out cement f/2710'to 2732'-14 bbls/min w/50 rpm's w/ @ 1040 psi p ' 9131. 7ktorque-5KWOB 05/08/2012 Circ btms up,drill cement f/2732',appeared to get off cement plug @ 2734',drilled to 2752',CBU,monitor well-static,displace f/11.6 brine to 9.8 ppg brine,monitor-gas breaking out,dispalce back to 11.6 ppg brine, monitor-static, POOH w/correct fill,test BOPE-witness waived by AOGCC insp Jeff Jones, PU/MU/standback 37 stands of 5"dp, MU drilling BHA,trip in to 544'. 00:00 00:30 0.50 2,732 2,732 INTRMI DRILL CIRC T Circ btms up @ 600 gpm 1080 psi w/ 50 rpms'w/7 k torque Caught btms up samples appears to still be cmt 00:30 00:45 0.25 2,732 2,752 INTRMI DRILL DRLG T Drilled cmt f/2732'to 2752'@ 600 gpm 1090 psi w/80 rpm's w/7 k torque Appears to have drilled off plug @ 2734' 00:45 01:15 0.50 2,752 2,732 INTRMI DRILL CIRC T Circ btms up @ 2752'w/600 gpm @ 1100 psi w/50 rpm's @ 7 k torque- Pull back to 2732' 01:15 02:00 0.75 2,732 2,732 INTRMI DRILL OWFF T Blow down TD-Monitor well for 30 mins.well static for entire time-No bubbling 02:00 02:15 0.25 2,732 2,732 INTRM1 DRILL CIRC T Displace well f/11.6 ppg brine to 9.8 ppg brine @ 600 gpm @ 790 psi w/ 50 rpm's @ 7 k torque 02:15 02:45 0.50 2,732 2,732 INTRMI DRILL OWFF T Blow down TD-Monitor well- Observed gas break out(bubbling)- after 15 mins fluid began to ooze down flow line 02:45 03:30 0.75 2,732 2,732 INTRMI DRILL CIRC T Displace well f/9.8 ppg brine to 11.6 ppg brine @ 600 gpm @ 1060 psi w/ 50 rpm's @ 7 k torque 03:30 04:00 0.50 2,732 2,732 INTRMI DRILL OWFF T Monitor well for 30 mins.-well static entire time(no bubbles) 04:00 05:45 1.75 2,732 472 INTRM1 DRILL TRIP T POOH on TT f/2732'to 472'-hole took proper fill 05:45 06:00 0.25 472 472 INTRMI DRILL OWFF T Flow ck welll @ HWDP-well static Page 11 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 06:30 0.50 472 0 INTRMI DRILL TRIP T Pull&Std back HWDP-Break bit, bit sub&stab&LD-Std back NM DC's 06:30 07:00 0.50 0 0 INTRM1 DRILL OTHR T Clear rig floor of excess equipment& clean up 07:00 07:30 0.50 0 0 INTRM1 WHDBO RURD P Drain stack-Pull wear bushing-Set test plug 07:30 07:45 0.25 0 0 INTRM1 WHDBO SFTY P PJSM on rigging up for BOP test& testing BOPE 07:45 08:30 0.75 0 0 INTRM1 WHDBO RURD P Rig up to test BOPE. 08:30 13:00 4.50 0 0 INTRMI WHDBO BOPE P Test BOPE as follows w/5"test joint:Test annular to 250 low and 2500 psi high.Test upper and lower pipe rams,blind rams,choke manifold valves#1 thru 16,Top drive p�r manual and auto IBOP,floor safety dDll and dart valve,4"demco valve on the mud line,kill line manual and HCR, choke line manual and HCR to 250 psi low and 3500 psi high.All tests charted, all tests held f/5 minutes. Function tested gas alarms. Function tested the accumulator. Tested the manual and hydraulic chokes in the choke manifold by choking flow to 1100 psi while pumping through each. Witness of tests waived by AOGCC inspector Jeff Jones. 13:00 13:15 0.25 0 0 INTRMI WHDBO SFTY P Pre job safety meeting on pulling test plug and blowing down choke and kill lines. 13:15 14:00 0.75 0 0 INTRM1 WHDBO RURD P Pull test plug.Took 40k overpull to pull test plug out w/blocks. Drain stack. 14:00 14:30 0.50 0 0 INTRMI WHDBO OTHR P Blow down lines. Line up choke manifold for drilling. 14:30 15:00 0.50 0 0 INTRM1 WHDBO CIRC P Make up stack washing tool. Flush BOP stack,pumping 504 gpm w/ 280 psi. Rotate 40 rpm w/3k ft lbs of torque.. Blow down the top drive. 15:00 15:30 0.50 0 0 INTRMI WHDBO RURD P Set long FMC wear bushing. 15:30 15:45 0.25 0 0 INTRMI DRILL SFTY P Pre job safety meeting on picking up/ making up 5"drill pipe via mousehole. 15:45 20:00 4.25 0 0 INTRMI DRILL PULD P Pick up/Make up/Stand back 37 stands of 5"drill pipe. 20:00 20:15 0.25 0 0 INTRM1 DRILL SFTY P Pre job safety meeting on PU/MU directional drilling BHA. 20:15 22:15 2.00 0 81 INTRMI DRILL PULD P Make up BHA:8-3/4"Hughes Christensen HCD605Z,ser# 7134259,jetted w/(7)14's(TFA 1.0523),7"SperryDrill Lobe 7/8-6stage w/1.3 deg bend, intergral stab,6-3/4"DGR, EWR-P4, PWD, HCIM, DM,TM HOC,float sub to 81'. Page 12 of 58 • S Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:15 22:45 0.50 81 81 INTRM1 DRILL OTHR P Upload MWD @ 81'. 22:45 23:15 0.50 81 238 INTRMI DRILL TRIP P Continue to make up BHA:(3) NM flex collars,(3)5"HWDP to 238'. 23:15 23:30 0.25 238 238 INTRMI DRILL DHEQ P Shallow pulse test MWD,pumping 600 gpm w/1300 psi. 23:30 23:45 0.25 238 238 INTRM1 DRILL TRIP P Blow down the top drive. 23:45 00:00 0.25 238 544 INTRMI DRILL TRIP P Continue to make up BHA:(1)5" HWDP,Weatherford jar(ser# 1621-0164), (7)5"HWDP to 544.89'. 05/28/2012 POOH, LD test packer,MU Geo Pilot assy, RIH,drill out,cement to 2730'sidetracked,drill to 2742', experiencing pack-offs,work and clean up hole,drill 30'new hole,CM,flow check,slight ooze,CBU,flow check static, FIT 14.5 ppg EMW, Drill to 3562'. 00:00 00:15 0.25 1,300 409 INTRMI DRILL MPSP T Continue POOH on trip tank to HWDP. 00:15 00:45 0.50 409 0 INTRM1 DRILL MPSP T POOH,rack HWDP, DC's, LD Baker retrievamatic. 00:45 01:15 0.50 0 0 INTRMI DRILL RURD T Clean/Clear floor 01:15 02:45 1.50 0 637 INTRMI DRILL PULD T PJSM and MU Geo Pilot BHA as per Sperry DD. 02:45 03:15 0.50 637 637 INTRMI DRILL CIRC T Shallow test MWD/Geo Pilot 03:15 04:15 1.00 637 2,524 INTRM1 DRILL TRIP T RIH from 637'to 2524'. PUW=125, SOW= 120K 04:15 04:30 0.25 2,524 2,572 INTRMI DRILL WASH P Establish initial drilling parameters. 500 gpm,230 psi-60 rpm,6K torque-125K up, 120K dwn, 120K rot-and begin blending fluids to reduce MW to 9.8 ppg from 11.0 ppg.Tag cement at 2572'. 04:30 06:30 2.00 2,572 2,713 INTRMI DRILL DRLG P Drill out cement from 2572'to 2713'- 550 gpm/2220 psi-80 rpm @6.5 K tq.-Blend MOBM in pits to reduce mud wt.from 11.0 ppg until mud wt. in&outat9.8ppg. 06:30 07:15 0.75 2,713 2,742 INTRM1 STK DDRL P Drill 8 3/4"hole w/GeoPilot from 2713'to 2742'- 650 gpm/2380 psi/ 70 rpm @ 6K tq.ADT=0.37 hrs TVD 2389'-Encountered several minor packoff events 07:15 10:00 2.75 2,742 2,742 INTRMI STK DDRL T Backreamed to shoe-continued to encounter minor packoffs and overpulls while reaming-laid down 1 single to enable working BHA 30'up into casing-minor packoffs occuring inside casing-Washed and reamed side track hole numerous times 650 gpm/2380 psi/70 rpm @ 6K tq. Hole conditions improved but still required weight on bit(5-8K)to ream area.Observed a lot of cuttings across shakers while reaming- cement and shale Page 13 of 58 • CCa C64 —z-i3 Regg, James B (DOA) ' 7-60173v From: Regg, James B (DOA) Sent: Monday, May 07, 2012 9:55 AM To: 'scott.a. brunswick@conocophillips.com' Cc: Brooks, Phoebe L (DOA) Subject: RE: Well bubbling on CD4 -213 (Sundry# 312 -006) PTD # is wrong — should be 2061730 (workover on CD4 -213; Sundry 21 -006). Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Schwartz, Guy L (DOA) Sent: Monday, May 07, 2012 8:27 AM To: Regg, James B (DOA); Brooks, Phoebe L (DOA) Subject: FW: Well bubbling on CD4 -213 (Sundry# 312 -006) Subject: 9 For you guys. Guy Schwartz SU ' 6 ZO Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Brunswick, Scott A [mailto: Scott. A. Brunswick(@conocophillips.com] Sent: Sunday, May 06, 2012 1:52 PM To: Schwartz, Guy L (DOA) Cc: Doyon 19 Company Man Subject: Well bubbling on CD4 -213 (Sundry# 312 -006) Mr. Schwartz, I am following up my previous e-mail notification of bubbling in the wellbore and shutting in of the top BOP rams with a written report. Date, Time of Well Event: 06 May 2012 at — 1130 hrs Well Location / API# / PTD #: CD4 -213 © Alpine (Sundry # if applicable) API# - 50- 103- 20540 -01 -00 PTD # -21 ZO(.0 Sundry# - 312 -006 Rig Name: Doyon 19 Operator Contact: Scott Brunswick (W) 907 - 263 -4249 (C) (907- 227 -8499) - Scott. A .Brunswick(a7conocophillips.com Operations Summary: Doyon 19 had latched onto the 7" casing fish while performing out cut & pull operations when it was noted that gas was breaking out of the mud at the return line. The rig circulated bottoms up with the 9.8 ppg brine with no significant change in the aas bubbling. The rig weighted up the brine system to a 10.0 ppg brine with no success. The rig shut in the top rams @ 11:30 and monitored pressures while vicosifying the brine and bringing the weight in the pits up to 10.5 ppg. Shut in pressures after one hour: SIDPP 25 psi / SICP 23 psi. The rig then circulated through the choke with the 10.5 ppg brine © 3 bbl /min, shut down the pumps at 14:55 and monitored the returns at the possum belly 1 • until small stream draining out of gas buster. The rig bled off the stanpipe pressure and opened the rams. Monitored the well for flow, observed intermittent static then slight flow, then static. Decision was made to bring the brine weight up to 11 ppg, then stepped up to a 11.5 ppg. Shut down the pumps @ 18:45 and observed the well staic. POOH with 7" casing fish and layed down. BOPE Used: Top rams. .r Reason for BOPE Use: Gas breakout at surface. Actions Taken / To Be Taken: Currently Doyon 19 is setting a 17.0 ppg cement plug in the 7" casing & open hole, followed by a cement squeeze, and then we will hold pressure for — 6 hrs to allow the cement to achieve some compressive strength and try to hold any gas from contaminating the cement downhole. The results of the cement job will determine further paths forward. Let me know if you have any comments and /or questions. Scott Brunswick Drilling Engineer Alpine Drilling Team Office: (907)- 263 -4249 Cell: (907)- 227 -8499 2 . • Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, January 06, 2012 9:53 AM To: 'Brunswick, Scott A' Subject: RE: CD4 -213 Sundry prr 26 - / 73 Scott, We will withdraw Sundry #311 -309 and use the updated Sundry #312 -006 for the proposed Plugging wellwork on CD4 -213. Guy Schwartz Senior Petroleum Engineer MOWED FEB ; 8 Z(})a AOGCC 793 -1226 (office) 444 -3433 (cell) From: Brunswick, Scott A [mailto:Scott.A.Brunswick @conocophillips.com] Sent: Friday, January 06, 2012 9:49 AM To: Schwartz, Guy L (DOA) Subject: CD4 -213 Sundry Guy I would like to withdraw my original Sundry to abandon for CD4 -213 (311 -309), I will submit an updated Sundry to abandon to reflect the changes to update the rig that will be used as well as the procedure to reflect where the PTD of the CD4 -213A PB1 wellbore will begin. Thanks Scott Brunswick Drilling Engineer Alpine Drilling Team Office: (907)- 263 -4249 Cell: (907)- 227 -8499 1/6/2012 • • SEMITE fl 9 SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 C. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 �® ('° Anchorage, AK 99510 Re: Nanuq Field, Nauq Oil Pool, CD4 -213 Sundry Number: 312 -006 JAN 2 4 h Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Since ely, Of Daniel . eamount, Jr. y�� Chair DATED this C day of January, 2012. Encl. Conoco Phillips Alaska, Inc. • • Post Office Box 100360 Anchorage, Alaska 99510 -0360 Conoco Phillips Telephone 907 - 276 -1215 January 4th, 2011 Alaska Oil and Gas Conservation Commission"" fvE!"1 333 West 7 Avenue, Suite 100 V Anchorage, Alaska 99501 JAN 6 5, 2.012 6a Cons. Commission Re: Sundry Permit -- Request to Re -Enter CD4 -213 and Plug for Re -Drill A chor3vie Dear Sir or Madam: This sundry permit has been updated to reflect the changes in schedule for this project and the updated decision on rig selection to the previously submitted sundry to abandon that was approved on October 13 2011 (Sundry number 311 - 3.09). ConocoPhillips Alaska, Inc. hereby applies for a sundry permit to re -enter the CD4 -213 well with the intention to permanently abandon the 7" portion of the well and use the existing surface casing and wellhead to set a v kick off plug for future sidetrack operations. Future drilling operations include CD4 -213A PB1 which purpose is to acquire core samples of the HRZ/Kalubik and Miluveach shales, the CD4 -213A PB1 wellbore will be plugged back into the surface casing and a 2 sidetrack will be drilled as CD4 -213A; an Alpine C Sand injector well. The predicted start date for the re -entry and plug setting operations is 02/15/2012. Doyon Rig 141 is intended to perform the work. The sidetracking procedures will be covered in a separate Application for a Permit to Drill CD4 -213A PB1. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Application attachments include: 1. Form 10 -403 2. A proposed re -entry and abandonment program 3. CD4 -213 Current Schematic 4. CD4 -213 Post Abandonment Schematic Application information already on file with the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Scott Brunswick at 263.4249 or Chip Alvord at 265 -6120. Sincerely, Scott Brunswick Drilling Engineer Attachments: • • cc: CD4 -213 Well File / Sharon Allsup Drake ATO 1530 Brian Noel ATO 1700 Fred Herbert ATO 1566 Chip Alvord ATO 1570 Elizabeth Galiunas ATO 1500 Gaute Naadland ATO 1700 Nina Anderson ATO 1702 Lanston Chin Kuukpik Corporation fi r, '-m`� Form 10 -403 ,'b. JAN 0 5 2012 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION afip i� E1�11x�E APPLICATION FOR SUNDRY APPROVALS .a,, w,nc1 20 AAC 25.280 1. Type of Request: Abandoi#� f P i'Plug for Redrill Q • Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend 1' Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well EI • Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 206 -173 . 3. Address: Stratigraphic ❑ Service MI 6. API Number: P.O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20540 -00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No IN CD4 -213 ' 9. Property Designation (Lease Number): 10. Field / Pool(s): 380077, 384209, 380075 / ALK 380077 Nanuq Nauq 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): 8305' 6201' , Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 114' 114' Surface 2678' 9.625" 2715' 2400' Intermediate 8204' 7" 8241' 6201' Production 2271' 4.5" 2308' 2000' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None 4.5" L -80 2300' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): None None 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service El 14. Estimated Date for 1/1/2012 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned „, � i Commission Representative: GSTOR ❑ SPLUG il 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Scott Brunswick @ 907 - 263 -4249 Printed Name C. Alvord Title Alaska Drilling Manager Signature Phone 907 - 265 -6120 Date 4-04 41 /440CA I (4(Zo re_ fi b 1 Z COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 2 - C C) Plug Integrity ❑ BOP Test Yr Mechanical Integrity Test ❑ Location Clearance ❑ Other: * 3 SOO ,,OCc 66f /esi' 4-Z s—o C ps ,4,�ntt,(a,t r (-41,.......,,,i) , Z5-- ZP SCh) - Dc. R- +4.$111V e. -e L f K' / c, r 1/ 7-4-c. Subsequent Form Re iuif ed. ___ 6 le A2-- Approved by: ///‘ COMMIS APPROVED BY ER THE COMMISSION Date: RBDMS 0 6 JAN 201! l ORIGINAL • • Dovon 141 CD4 -213 Abandonment Procedures The proposed scope of work for this sundry application includes: 1. Move on Doyon 141. 2. Test 7" casing & BPV through inner annulus to 1,000 psi for 10 minutes & chart pressure test. 3. Test tree adaptor to 5000 psi. 4. Rig up lubricator and pull BPV. 5. Circulate diesel freeze protect over to 9.2 ppg kill weight brine through tree and monitor for flow 30 minutes. 6. Set BPV and test through IA to 1000 psi. 7. Set blanking plug. • 8. Nipple down tree. 9. Nipple up BOPE and test with 4.5" x 7" test joints to 3500 psi. Clearance issues with the blanking plug prevent the lower rams from being tested at this point. CPAI requests approval for testing the lower rams after the tubing is pulled from the well. « 10. Remove blanking plug and BPV. 11. Pull 4 1 /2" tubing kill string. • 12. Pressure test lower rams with 4.5" and 7" test joints. 13. Set CIBP (Cast Iron Bridge Plug) @ 2,992 ft and pressure test to 2500 psi. 14. Cut 7" casing @ 2,974and 2,644 ft MD. 15. CBU with 9.2 ppg brine. 16. Pull 7" casing to surface and lay down. Pull 7" cut section with spear and lay down. 17. RIH with 3.5" cement stinger on 4" drill pipe and set cement kick off plug from the top of the CIBP to 100' inside surface casing shoe. 18. POOH with cement stringer assembly and lay down. 19. Perform Bi- Weekly BOP test! 20. Pick up and run in hole with 8 -3/4" drilling BHA. 21. Tag up on cement plug, pressure test to 2000 psi. r �� 22. Swap 9.2 ppg brine to OBM. Polish off cement, drill cement in casing to within 10 feet of shoe. 23. Transfer to PTD for CD4 -213A PB1 Net.) PT) • CD4 -213 Current Schematic U41N IC'D4 -213 1 1j1 It t71iriIIIWUIt i6 X14111 Max Iv I41O TO lk ?�1pwi�s� lc1c. uillllllp9 l zn N.,wrvw.wrx. rnuw"iiaxaw 1 Wdl 4lwwn n : b.II Wij 41Cel le®fli " nv �Wyr,,, 8'41.03Y1"S+n'2° 1 44°41 };i 1541 5P' S I p p�3 Cemm�i'... tll'a@I¢ ge¢ D'44 4'4"441''' info . g4.6t1 iatk Ap11H.i flRii € ... Lrras 44Fi 43 pp 7#a [ "adnl au 4E ter'xihi a' -- l.}IIA Tom. iti '(Nwl -�.( 111 �+ 'p" Ca I 51rI ' 11 111 1' 111 1 111110V 0 1 1 10011 1 10110 0 01 1 111 1 1 1 1 1 LI II Cwwwgp 6wx °""P G., 51 d.41 C T�4 (�bp.R '1✓wi P:urTi 0wI C.44' 11'4'4.. Pii day VR.. pg 1pN1:np 1vir.,�a t7 ,W.MGTOR 1E 15 ?50 3B 0 114.9 114 !p5 pp i mp _ ..__. _ta sYwgp p ww:wbi �aaaec., pliM�**xm.. Tip liCgg a,1_ 8i9 Csrpi+144+,.:- bNl+mp Nrt U Nary' .. iiN+p T:;"R7r +a1 ... n , 6N +�ulu �,,,,,, C Ill 033 p.@35 3®. 31;711.1 7 4t)I4 1 ED p9 'I C. p pww�bfim 34'''","i ®v :11kxp . . Np tilt IDAw Ip ph e - ¢wa 1lwp3N 1T'L}.. 2'1'4'44. . 6pi6Yp .. std., TUi+TM4 0,1 - ' 11 6 t 3 /F 7MF11 TF p 2-' 36 1 3, ap9 r a ,fl 0 i 44°441 wl 11111 III 1 1 1' inn itrinme . " T ie) Ow .„0.,. arl p -- 9 3 a TNp Ifl4If 1Dn S.E pwPflN w L'4 . i an pwaNq .. S fd 4 7+.p1f Fc l 01tirp 4 lrp I 3• I 2L4 ,":1.�J9 I 3L l'",10 9 tt I in ° BR. I ITV ✓�I9I1� m u�i ION 1 n pl l h 111 T I I G ll u p Tap ikwam {nMlri ° . t G4..aI�He e..kwwd o tll h141uV 1 t 4 - ' . , p ,c , i farcii cp Ft 9 " uy , T 2 Z 5 I 4A .'�L9 WNWIIiEU'I 131Ra iNF ENTlts C lk s ' t7E , C' 1€t1T O FL G89111aral 111 i do 6 pmwT 1}q. *m i dir „� 171Mi:997Y.'3T'E "4i l nlrm�sa;i 8' 1pilfdk].. '''I 11 ',,,, 13:18wC310Dp 13l'i7E.�i §F"Nr sY rx4 TaCwti.M k.WMvp' s fl 9 I 11 I 111V0 I 1 mamma pt CAN, 1, ` 11,1 III D lfrI1 " I on .cu, aspr I. pR c r „ 'fir T:1id „.,m7. _-1 - , 0 • CD4-213 Post Abandonment Schematic CD4 — 213 Cut, & PuB Abandonment Updated Jan 03, 2012 / A A 4: 1E' Insulated Conductor to -114' !!' Top of Kok Off Plug 2.613' MD tJ 9-5,V 40 p$ LY3131 Surface Casing 27D431) 2.360.1g TVD 7 Casing Stub ;, , 4 tj Bottomof Kick Off Pkg 2360 MD 2,965' MD CIBP - 2„0a3 MD 02 cpg kiI tseight brie 7- 4 Cement top as panned - 4,550' MD. 3'73T TVID Wands 5 C.,14_Lf LID141,.■95* TM :t l -''' — — fY t !! A4 ■ /h. • : ly. Ailalli 1122011211.112E1 !I; ■/■. ...■ =WON ..._ 7 I 4 — — , 4 l'I'l ,,, 4) . _•,',: ID € : 8,305` MD f 6,201.09' T I — — — — -;ALL-iiLi.—' ■ l ! Page 1 of 1 • Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code " IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F: \Daily_Document Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 1/5/2012 • • SlfAUEE [1[F /1_,ASEKKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMJSSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 C. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc.® P.O. Box 100360 Anchorage, AK 99510 Re: Nanuq Field, Nauq Oil Pool, CD4 -213 Sundry Number: 311 -309 Dear Mr. Alvord: . ^=v' Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 0/ Daniel T. Seamount, Jr. 2 � Chair DATED this` J day of October, 2011. Encl. Il l s . ConocoPhillips Alaska, Inc. • • Post Office Box 100360 )11 Anchorage, Alaska 99510 -0360 Conoco Phillips Telephone 907 - 276 -1215 October 05 2011 RECEIVED Alaska Oil and Gas Conservation Commission OCT 0 6 2011 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 Alaska Oil & Gas Coos. Commission Anchorage Re: Sundry Permit -- Request to Re -Enter CD4 -213 and Plug for Re -Drill Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a sundry permit to re -enter the CD4 -213 well with the intention to permanently abandon the 7" portion of the well and use the existing surface casing and wellhead to set a kick off plug for future sidetrack operations. Future drilling operations include CD4 -213A PB1 which purpose f is to acquire core samples of the HRZ/Kalubik and Miluveach shales, the CD4 -213A PB1 wellbore will be plugged back into the surface casing and a 2 sidetrack will be drilled as CD4 -213A; an Alpine C Sand injector well. The predicted start date for the re -entry and plug setting operations is 01/01/2012. Doyon Rig 141 is intended to perform the work, however, dependent on ice road timing and current planned operations, Doyon 19 may be an option to perform the work. The sidetracking procedures will be covered in a separate Application for a Permit to Drill CD4 -213A PB1. - Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Application attachments include: 1. Form 10-403 2. A proposed re -entry and abandonment program 3. CD4 -213 Current Schematic 4. CD4 -213 Post Abandonment Schematic Application information already on file with the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Scott Brunswick at 263.4249 or Chip Alvord at 265 -6120. / � �w 9CQ0a7 w / l Sincerely, �a ,�ey� � '�� E 'er` bE',C�✓ i ertrew c�o'� v„ Scott Brunswick /'I Drilling Engineer S (9a/ t/ Attachments: cc: CD4 -213 Well File / Sharon Allsup Drake ATO 1530 Brian Noel ATO 1700 Mark Chambers ATO 1566 • • Chip Alvord ATO 1570 Elizabeth Galiunas ATO 1500 Jack Walker ATO 1740 Nina Anderson ATO 1702 Lanston Chin Kuukpik Corporation RECEIVE' Form 10-403 Ifl 1 ACT ® 2011 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. Commission APPLICATION FOR SUNDRY APPROVALS A nchalage i ( 20 AAC 25.280 1. Type of Request: Abando A,,, Plug for Redrill • Perforate New Pool El Repair Well ❑ Change Approved Program El J' Suspend ❑ ') Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well 0 ' Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 206 -173 • 3. Address: Stratigraphic ❑ Service Q 6. API Number: P.O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20540 -00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 0 CD4 - 213 9. Property Designation (Lease Number): 10. Field /Pool(s): 380077, 384209; 380075 / ALK 380077 Nanuq Nauq 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): 8305' • 6201' • Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 114' 114' Surface 2678' 9.625" 2715' 2400' Intermediate 8204' 7" 8241' 6201' Production 2271' 4.5" 2308' 2000' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None 4.5" L-80 2300' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): None None 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 14. Estimated Date for Commencing Operations: Oil Oil Well Status Gas Status aft proposed work: V" ❑ WDSPL El Suspended ` 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Scott Brunswick @ 907 - 263 -4249 Printed Name C. Alvord Title Alaska Drilling Manager Signature ziZ. ll4 04,,, , „ fy , /,Phone 907 - 265 -6120 Date 4- Oct -11 — /a1 c�mo 1401,5A COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 k rV t Plug Integrity ❑ BOP Test i Mechanical Integrity Test ❑ Location Clearance ❑ Other: * 3 SOU 1 5,:. Bb I 7 lI -- -- / \ L SOd /1Sc h+t.. i -G-t (e..�'- l4"4� k s f; L.P S Prt✓. &� Zz /1 ��` 2..8'5 a Subsequent Form e [J D 7 . / APPROVED BY JO / Approved by: COMMISSIONER THE COMMISSION Date: r J RBDMS OCT 1 71 '° � t, � ,,,,d/ .4 • • Dovon 141 CD4 -213 Abandonment Procedures The proposed scope of work for this sundry application includes: 1. Move on Doyon 141 /19. P s � 2. Test 7" casing & BPV through inner annulus to 1psi for 10 minutes. P. 7" 3. Test tree adaptor to 5,000 psi. 4. Pull BPV. 5. Circulate diesel freeze protect over to 9.2 ppg kill weight brine through tree and monitor for flow 30 minutes. 6. Set BPV and test through inner annulus to 1,500 psi. 7. Set blanking plug. sr 8. Nipple down tree. 9. Nipple up BOPE and test with 4.5" x 7" test joi s. Clearance issues with the blanking plug prevent the lower rams from being tested at this point. CPAI requests approval for testing the lower rams after the tubing is pulled from the well. 10. Remove blanking plug and BPV. 11. Pull 4 IA" tubing kill string. 12. Pressure test lower rams with 4.5" and 7" test joints. 1 � P 13. Set CIBP (Cast Iron Bridge Plug) @ 2,992 ft.° -f -p 14. Cut 7" casing @ 2,974and 2,644 ft MD. 15. CBU with 9.2 ppg brine. 16. Pull 7" casing to surface and lay down. Pull 7" cut section with spear and lay down. 17. RIH with 4.5" cement stinger on 4" drill pipe and set cement kick off plug from the top of the CIBP to 100' inside surface casing shoe. 18. POOH with cement stringer assembly and lay down. W ®.G 19. Pick up 4.5" tubing kill string and RIH to 2000 f e� t. ..�- -r r - r , 20. Install TWC and pressure test to 1,500 psi from inner annulus. �� ,,t 42111-) 21. Nipple down BOP and nipple up tree. 22. Pull TWC and displace well to inhibited brine and diesel freeze protect. ! - l1 ' 1 1 23. Set BPV and secure well. 24. RDMO Doyon 141/19 • • CD4 -213 Current Schematic WNS C114 -213 C il IpS We11 Attrar idea Max Angle & !113 NNW., APIANO r1N . 41 3 Mm W I .#t.. LIT! IT N3 1H1 . p:0!M t) txnrsaR°a SC 08 I1>A1,L� SUSP 51:7x3 I RIC S.200_33 C:.alr.re 1115 taper^: Cal. r1,1I4 Eh d Os. 110•Gd lira Mg Rr.. Coll :� ^T4a;�ea.ww'4;rrcTm[11t Lalhi"1 4306 11&r7C17 Lea. Ty: Pert Rsemss C£ TALLIES Irrce4 *2"51X33 Casino rip la Gran; 0,.1 4Im.. ,11;430 C=.,. 9rtagi0 _. Tap Ink SA 11g3...g3.. 0x1 [stet 1T4Ci... llirg 111., Dram - 911 9 Tag MO CONDUCTOR 10 19293 31E0 114.9 114.0 &LCO M.43 Cason OltsrlAtArt tiling C... MAAR 10 _. T.p IIIK01 =1.1 Din j_. 0•1 Cosh (NMI... lal`914,. Salrg... .`Irby Tap3M5 90 9.919 30.77 2,713.1 2.:35'x.2 4000 L.0 ..Beg 1.1..o4alYn 1114@ R.. Urfa; _. T.p 1111101 * 11 0.i ['ATM ITATA ., llI10 SN_. Arena . 9r1r47 Tan tart 91"E OEAT= 7 4370 34.1 $29±'.5 927i.e2 2b C9 L.5t•. .1 � 31 'k Tubing Strings Tnarp ElstrrArlift . 13fr*p O_. 51x4*; 10... Tp 101.01 NA LOAM .'J.. 0 Climb Mart 5111rg NR_. 5trry._ 53r1rg Tag 11.:3 Tu84- 11 -p.1 S11611 I 41.12 I 1.9_ '314 2.353.5 I x1 2133.3 I 1208 1..90 I 1ST Canpia Ion ®efitpa TAP C1 IIVdl 7.p lal Tap fkiCAt 1 11110 1 I"i r..,, 0i.alpii:n C,.,n.r1. 1C l.. 31.4 31 4 41.12 FAA E.. FMC 4 11'2 Gan `01 * h.-;.* ; Fug 4.5E0 2,287.2 2.587.1 4499 W.E3 551F:*1./NE E1lTn % 1.41_12. OPEN tOIEED TUBING Mates: General & Safety end C.i. 4nwirii1a 1, 1 ti 1 :E. 1A,E.L7.- 1SPEN-EJ ..8 LL 8T3IW3 12I9723.111 1 4..CE'AEA.SCHeM4f!.: w,'A1c1.o S:.11.u4:.x:9 . 33,071 NTETtICCiiT1: T� 3 190$ - _.. • • 0 CD4 -213 Post Abandonment Schematic CD4 -213 Plug Back Abandonment Schematic , A 1 [ i 16" Insulated Conductor to Date Updated 1 k - 114' 10/04/2011 • ;1;ill 4 % 12.6 ppf L -80 Kill String to 2000' MD Diesel Freeze Protect 41 9.2 ppg corrosion inhibited brine 9 -5/8" 40 ppf L -80 BTCM Surface Casing 2713.1' MD / 2389.2' TVD 41111111111111 .:""1 +!II 17.0 ppg Cement Kick Off Plug @ 2613'MD 11111111•1111411 KOP 2813' MD / 2406' ND Top - 7" 26 ppf L -80 BTC Mod Casing @ 43.26° 2974' MD, 2581.54' TVD CIBP @ 2992' MD / 2594.65' ND 7......,. i...:••".....i:ii..........1....i..1........:,:l........ Planned TOC +/ -4559' MD / 3742' TVD Mil Planned K2 /Qannik sand +/ -5059' MD / 4106' TVD 1. 9.2 ppg corrosion inhibited brine •••.".•••; i` i y;T TD of 8.75" hole 8305' MD Planned Top Reservoir at +/- Nanuq 8154' MD / 6189' TVD -4 " v _ii __ ' t; 7" 26 ppf L -80 BTC Mod Production Casing © 85.09° 8295' MD, 6200.2' TVD • • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve / D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: / /F: \Daily_Document Record \Procedures_Instructions \FW INTENT PLUG for RE -D... 10/6/2011 • • i it Li S n [IL ASEn SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMIIIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Brian Noel �� Alpine Drilling Engineer i ConocoPhillips Alaska, Inc. a, P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Nanuq Oil Pool, CD4 -213 Sundry Number: 311 -205 jib 2 S ZO1 *MS Dear Mr. Noel: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. er: s e r K. Norman o : sioner DATED this 'day of June, 2011. Encl. Conoco Phillips Alaska, Inc. • • Post Office Box 100360 .". Anchorage, Alaska 99510 -0360 Conoco Phillips Telephone 907 - 276 -1215 June 15 2011 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 RECEIVED Anchorage, Alaska 99501 tin! a ?W Re: Sundry to Re -Enter CD4 -213 Dear Sir or Madam: Alberta l & G COW c rn11SSion ConocoPhillips Alaska, Inc. hereby applies for a Sundry to Re -Enter the existing CD4 -213 onshore h ell on the CD4 drilling pad. This well was originally permitted in December 2006 — PTD: 206173. Drilling operations commenced on , 12/26/2006. Drilling operations continued on the well until the intermediate casing had been run to TD and cemented in place. At this point in the well, the decision was made to run a 4.5" kill string and suspend the well in order to move the rig over to the CD3 pad to v commence winter drilling operations. A 10 -403 sundry request to operationally shutdown the well was approved on 1/10/07 — Sundry Number: 307 -009. Cement bond log using SCMT logged good cement with TOC at 3,842' ELM on 1/28/07. A subsequent 10 -403 Sundry to Suspend was approved on 2/19/08 — 308 -052. ConocoPhillips intends to re -enter the CD4 -213 well to drill and complete the lateral wellbore. As originally permitted, this well will be a Nanuq horizontal injector. The lateral well trajectory, he and toe locations will be the same as stated in the original If= . permit to drill, with a changed vertical profile along the trajectory to improve reservoir exposure given recently acquired data. `Trie viell will be completed with 3.5" slotted liner with swell packers as opposed to the originally proposed 4.5" slotted liner. The intended spud date for this well is 6/25/2011. It is intended that Doyon Rig 19 be used to drill the well. Once completed, t the well will be pre - produced for a year prior to converting over to injection. 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 -403 APPLICATION FOR Sundry to Re -Enter per 20 ACC 25.005 (a). 2. A proposed re -entry and drilling program 3. A drilling fluids program summary. 4. Proposed completion diagram 5. Pressure information as required by 20 ACC 25.035 (d)(2). 6. 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: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Mike Winfree at 265 -6820. Since ': ly, Mike A. Winfree Drilling Engineer Attachments cc: CD4 -08 Well File / Sharon Allsup -Drake ATO 1530 Mark Chambers ATO 1566 Liz Galiunas ATO 1500 Ryan Robertson ATO 1702 Lanston Chin Kuukpik Corporation STATE OF ALASKA ! , ( �/1( R FIVE ALASKAIRAND GAS CONSERVATION COMMISSIO U' APPLICATION FOR SUNDRY ip � ?Ol �� 20 AAC 25.280 - 1i ' sion 1. Type of Request: Abandon r Aug for Redrill J Perforate New Pool f Repair well J • ange Approve P rogram Suspend r Rug Perforations r Perforate r Pull Tubing r A WAN& ion Operational Shutdown E R -enter Susp. Well Stimulate Alter casing g r Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 7 • Exploratory r 206 -173 • 3. Address: . 6. API Number: Stratigraphic S ervice IT P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20540 -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 j No Fi CD4 -213 . 9. Property Designation (Lease Number): 10. Field /Pool(s): • ADL 380077, 384209, 380075 Colville River Field / Nanuq 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): 8305 ' 6201 ' 8207' 6191' Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 16 114' 114' SURFACE 2676 9.625 2713' 2389' INTERMEDIATE 8261 7 8295' 6201' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): none none 4.5 kill string L -80 2309 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) no packer none no SSSV 12. Attachments: Description Sum ary of Proposal J 13. Well Class after proposed work: Detailed Operations Program r- BOP Sketch r Exploratory E Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/25/2011 Oil P • Gas r WDSPL r Suspended E 16. Verbal Approval: Date: WINJ (-" GINJ r WAG Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brian Noel @ 265 -6979 Printed Name Brian Noel Title: Alpine Drilling Engineer Signature Phone: 265 -6979 Date 4.7 s A( Commission Use Only Sundry Number: 3) s "" C9C Conditions of approval: Notify Commission so that a r presentat y itness .3 6 1 0 ps- /' Plug Integrity r BOP Test // Mechanical Integrity Test V Location Clearance r Other: P l oco 01 kC Ul' j n j GCO/Y'.. Sac GC•nr te-3 c): r e.f 19-0 r . Co u veer' 4 :K ' c, e.fi ok . ' o r t . 1h cci i -�- c� •pk r ,•ows Q� p C2' 6 — 1 7 3) Subsequent Form Required: io / APPROVED BY 6.-71-// Approved by: CI MMISSIONER THE COMMISSION Date: .rye �. 4_, _ n Duplicate ‘. • • CD4 -213 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 6 -1/8" Hole / Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, 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) monitoring, weighted sweeps. Abnormal Reservoir Medium BOPE drills, Keep mud weight above 9.8 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. Hydrogen Sulfide gas Low H drills, detection systems, alarms, standard well control practices, mud scavengers • • Alpine : CD4 -213 Procedure 1. Move on Doyon 19. 2. Confirm that a BPV is installed before MIRU. 3. Pull BPV. 4. Circulate KWF through tubing kill string at 2,309' MD. 5. Pressure test casing to 3,500 psi for 30 minutes 6. Install two way check. 7. Pressure up IA to test TWC in direction of flow. ^' 8. With two tested barriers in place, ND Tree, NU BOPE. s 9. Shell test BOPE and flange break. 10. Pull TWC 11. Pick up 4 -1/2" landing joint and screw into tubing hanger 12. Pull 4 -1/2" Tubing Hanger and 4 -1/2" kill string to floor. 13. Set test plug and test BOPE — 3 54° P s 14. PU and RIH with production drilling assembly (LWD Program: GR/RES /PWD). 15. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. (rt T) 16. Drill 6 -1/8" horizontal section to well TD with 9.0 ppg OBM. 17. Circulate the hole clean and pull out of hole. 18. Run lower completion of 3'W, 12.6# L -80 SLHT slotted liner and Baker Flexlock liner hanger. 19. Run upper completion of 2 -7/8 ", L -80 tubing with TRMAXX -5E, 3 x GLM, 80 -32 PBR, D nipple and wireline entry guide. Land hanger. 20. Install 2 way check and test and pressure test hanger seals to 5000 psi. Nipple down BOP. 21. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 22. Drop ball and rod, shear valve in GLM and test tubing and annulus to 3500 psi / 30 mins L--7 S Er fgt class (F FI i3e-L, 23. Circulate tubing to diesel and install freeze protection in the annulus. 24. Set BPV and secure well. 25. Move rig off location. ICI • Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in the attachments. There are no wells that fail major risk analysis. The closest well to the proposed CD4 -213 wellpath is Nanuq 3 with an ellipse separation of 84' at 11,116' MD. Drilling Area Risks: Reservoir Pressure: Offset injection has the potential to increase reservoir pressure over predicted, although this is highly unlikely, the rig will be prepared to weight up if required. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. DRILLING FLUID PROGRAM Production Hole Section — 6 1/8" Density 9.0 — 9.2 ppg ✓ PV 10 -15 YP 25 -30 Funnel Viscosity Initial Gels 10 -15 10 minute gels 12 -20 API Filtrate NA HPHT Fluid Loss at 160 12 -14 cc /30 min PH 9.0 -9.5 KCL 6% Production Hole Section: The horizontal production interval will be drilled with a MOBM drill -in fluid. The fluid will consist of 80/20 OWR. Base oil is LVT -200 mineral oil, the internal phase will consist of 33% w/w CaCl2 brine with emulsifiers and wetting agents. Sized calcium carbonate will be used as a bridging agent for proper filter cake building and fluid loss control. • 0 CD4 -213 Completion Schematic CD4 -213 Nanuq Injector Completion Sperry Sun 16" Insulated Conductor to Directional Plan WPO7 —114' 6/14/2011 ' 2 -7/8" 6.5 ppf L -80 EUE 8RD -Mod Tubing 2 -7/8" TRMAXX -5E TRSV, 2.312" X Nipple i4 ,,,,, 9 -5/8" 40 ppf L -80 BTC -M Surface Casing 2713' MD / 2388' TVD Upper Completion: MD TVD 1) Tubing Hanger 32' 32' 2) 2 -7/8" TRMAXX -5E TRSV (2.312" X- profile) 2177' 2000' 3 3) 2 -7/8" x 1" Camco KBMG- GLM (43 °) 4091' 3400' 4) 2 -7/8" x 1" Camco KBMG- GLM (39 °) 7057' 5600' 5) 2 -7/8" x 1" Camco KBMG- GLM (2.347" ID) 7781' 6014' 1—Dl� / -A TOC w /DCK -2 (64 °) +/ -4559' MD / 3%412-1A41' 3742' TVD 6) 80 -32 PBR 7835' 6093' � C B L K2 /Qannik sand 7) 2 -7/8" x 7" Baker FH Packer 7865' 6104' +/ -5059' MD / 4106' TVD 8) 2 -7/8" "D" Nipple (2.250" Min ID) (70 °) 7895' 6115' 2 -7/8" 6.5 #/ft L -80 9 ) BOT Indicating stinger with fluted WLEG 7935' 6128' i ` ' EUE -8RD- Mod Tubing Stung into tieback extension 10' s with PolyOil Thermal Centralizers on Each Connection Lower Completion: MD TVD MI 10) Baker 5" x 7" Flexlock Liner Hanger w/ tieback sleeve 7945' 6131' © 11) 3 -1/2" 9.3 #/ft L -80 SLHT liner w/ blank across shale • and slots across sand. r� 12) 3-W 9.3# L -80 Orange Peel 14527' 6202' , 7 14 I� fJ N OP P— H;:::: ::: , ,),,,., S"- �� 40 aV n : „, 3 /z 9.3 #/ft L -80 SLHT Slotted Liner �i� '`_'"Y Top Nanuq 10 11 12 8194' MD / 6189' TVD (82 °) 7 TD 6 -1/8” hole 15520' MD / 6141' TVD 1 7" 26 ppf L -80 BTC Mod Production Casing 95' MD, 6200' TVD (85 °) • • PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Csg Setting Fracture Pore Casing Size Depth Gradient pressure ASP Drilling (in) MD/TVD(ft) (Ibs. / gal) (psi) (psi) 16 114 / 114 10.9 52 53 9 5/8 2713 / 2388 14.5 1128 1,138 7" / TD 8295 / 6200 16.0 2805 2191 N/A 15520 / 6141 16.0 2805 N/A 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 lb/gal 0.052 = Conversion from lb./gal to psi /ft 0.1 = Gas gradient in psi /ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP =FPP — (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below intermediate casing (7 ") ASP = FPP — (0.1 x D) PIA' P = 2805 —(0.1 x 61410 = 2191 psi • • f4: 6ti • ConocoPhillips(Alaska) Inc. r!; Western North Slope CD4 Nanuq Pad CD4-213 CD4-213 f!' Plan: CD4-213wp07 Standard Proposal Report 15 June, 2011 • •;:. • ,111111/1 HALLIBURTON ■•■■■■ • Sperry Drilling Services ti 4 Easting (5000 ft/in) Nu _ D 2 1 ! �� // 1,4 \` CD2 - 29 - V IC, 6 Jt►Fte 1d 0 CD2-1,1111/1.-_, i � �` � �� 19 _ � it ��� Bergschrund 2A - • *i. 11 � ► 3PB1 4 I , ii II p • CD2 - - � 1 Alp" • : - CD4 -07 / �D 45 D2-33 CD2 -44 CD 35A — ► D 2-33, .... 1 o D2 4 „4 1-39 _ - ` 3 . ,� Bergschrund 2 \CD s p -47 w 04 — CD C12-471 - _ A p0 1 i ..D 1 .8 CD2 -51 — - CD2- 6 %462 7 \ CD ' -58L1 CD2 -52 CD2 — ' CD ;Al,” ! ;i2 -59D 5CD2 -27 CD4 -301B _ CDC D4 7 D4 -213 p 07 D 1 1._ c B1 • — CD4 - . CII ' 306 12 - 3 7 ` 12 -36 — - CD. 304' — - �,� ,��� Vi ,� � CD4 -301A _ C lialitl11114. - B _____ ° _ CD 318A q;,�''�� :, CD 02 I cm `CD4 301 A �4 321 / s . /sue ' // — _ Ili `� OA" ��' CD4 320 _ CD� � •CD4 208A — CD4 "►t'„,6: PB2 TI ci Nanuq 5 - i► , 21. - - CD4 - D4 -214 - _ 0,! = i PB1 _ CD4- 208Awp22 — - - CD4 - wp03 CD4- 03wp02 _ ConocoPhillips(Alaska) Inc. -WNS CD4- 210Aw Western North Slope - CD4 Nanuq Pad - - I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I Easting (5000 ft/in) Project: Western North Slope CD4 213wp07 Site: CD4 ConocoPhillips Wellboee: CD4- 213 UlPad oo GD i 6 - 3 l oD ] Alaska DDI<00: Rdatrvelyshal, simples.. or simple e profiles with low 3000 { . 5 1Q -3000 DOI6.0 -6.4: Shorter wells s6th Nab tonuosM or longer walls with low tortuosity DDI = 6775 n - - - - - _ DDI6.4 -68: Lag wells with r4ettoetylerto3e profiles . ICD4213 14Jun11119 , 3- 112 " x6 -118" DDI, 6.8: Lag, tortuous profiles with a high degree of �cv8y . - I16IHALLIBURTOIN REFERENCE INFORMATION Surface Location 1AQQQ 1 Co-ordinate (WE) Reference: Well CD4 -213, True North Northing 5957217.19 - - OR / 00060706 Plat 323+19.9 0 56 205(8800819) Eashng 1517974.60 IC -213 14 Jun ' 11 e Sperry (VS) Reference: Slot - (00N, 0.00E) Ground Level 19.90 S � perry Drilling Catwlas3n Method Minimum Curcxune Latitude 70°15 9 N - 33 Geode& Zone Alaska Zola 8. e4 Longitude 150'59' 28.812 W 17:45, June 14 2011 G.:nen Daum: Nut, American Datum 19e3 CASING DETAILS SURVEY PROGRAM - 13 QOQ 1VD TVD55 MD Name Size 15 D421314JMn11 517 _,e -1500 2388.49 233229 2712.67 95/8 95/8'012 -1/4" 69.55 529.55 004213 gyro (084-213) CB- GYRO-SS b Slfr 619722 614102 826456 7 7• o9 -318' 56821 8264.56 C04213 (CD4-213) MWD+IFR-A6.C42-SC 6198.14 614194 1452043 3-1/2 3- 1/706.1/8' 8264.56 14520.43 C134213w007 (004-213) MW13+1FR- 42- C42-SC - - Tagels _ I CD421314Jun11146 .y - Name TV050 +N/S +FJ -W Northing Easting Shape 4°°° 4JU CD4-213 ' T9 6141.94 295325 -553607 596025997 151248782 Point - 004- 21314JUn11 18 6150.19 239970 -526686 5959702.16 151274796 Poi. - 084-213141un1/77 615500 177196 -4961.57 595906957 151304297 Point co CD4 - 213 1400811 76 6170.26 1129.83 -484928 595842250 1513344.73 Point eo I CD4-213 14Jun11 1 9 ,yf, ° , r , . ,.a .. r..... xv a.» .0 SECTION DETAILS . o. .^-.... a .c.... ore 0808 + - _ • Sec MD Inc 401 TVD 7VD56 +911-3 881-99 Northing Easting DLeg 10.5. 95.0 Target f a - ':I -0 1 8264.56 85.09 336.30 6197.22 6141.02 - 2677.57 - 2813.11 5954586.91 1515118.49 0.00 0.00 - 1553.96 2 831456 85.09 336.30 6201.50 6145.30 - 2631.95 - 2833.13 5954631.95 1515099.22 0.00 0.00 - 1504.24 1 1000 3 8492.90 88.30 334.74 6211.78 6155.58 -2469.95 - 2906.90 5954795.12 1515028.11 2.00 -25.93 - 1326.77 y I CD4 21314Jun11 714 1 Q - 4 9064.53 88.30 334.74 6228.74 6172.54 - 1953.20 -315032 5955315.73 1514792.76 0.00 0.00 - 757.80 • 5 9145.29 89.77 334.07 6230.10 6173.90 - 1880.38 3185.60 5955389.10 1514759.07 2.00 -24.41 477.44 004.213141un1171 I' 1 6 9145.76 89.77 334.07 6230.10 6173.90 - 1879.95 3185.80 5955389.53 1514758.87 1.00 178.43 -676.97 �, 7 9707.69 89.77 334.57 6232.41 6176.21 - 1374.58 - 3431.49 5555898.79 1514521.47 0.00 0.00 - 118.04 0 - 41 - 8 9731.18 90.00 334.07 6232.45 6176.25 - 1353.46 - 3441.76 595592008 151451154 1.00 -1.57 -94.69 004-213 14Jun11 T2 9 9785.07 90.54 334.07 6232.20 6176.00 - 1304.99 3465.33 5955968.92 1514488.77 1.00 -0.02 -41.08 / 10 10164.47 90.54 334.07 6228.63 6172.43 - 963.82 - 3631.24 5956312.72 1514328.45 0.00 0.00 336.27 _ Q - 11 1021836 90.00 334.01 8228.38 6172.18 - 915.35 - 3851.81 5956361.56 1519305.68 1.00 179.70 389.87 001-213 14Jun11 73 _ - �Q 12 10248.10 89.70 334.07 6228.46 6172.26 -888.60 - 3667.81 5956388.52 1514293.11 1.00 - 180.00 419.45 14 11197.22 89.99 334.07 6233.31 6177.11 -35.05 4082.84 5957248.64 1513892.08 1.00 0.01 1363.17 C04.213 14Jun11 14 - CD4 -213 14JUn11 713 Ae' J °° o 9-55/8" x 12 -1/4` 13 11168.66 89.70 334.07 6233.23 6177.3 -60.73 -407095 5957222.76 15134.14 0.00 0.00 1335.07 I 15 11197.22 89.99 334.07 6233.31 6177.11 -35.05 408284 5957248.64 1513892.08 1.00 0.00 1383.47 16 1193280 89.99 334.07 6233.46 6177.26 626.48 4404.49 595791527 1513581.26 0.00 0.00 2095.12 17 11934.04 90.00 334.07 6233.46 6177.26 627.59 4405.03 5957916.39 1513580.74 1.00 - 16.51 2096.35 CD4- 213 14100711 T5 -1500- -1500 18 12006.55 90.75 334.07 6232.98 6176.78 694.59 -4437.62 5957983.91 1513549.25 1.00 0.01 2170.46 I CD4-213 14JUn11112 3 A 19 12444.66 9025 334.07 6227.28 6171.08 1086.76 4628.33 5958379.09 1513364.97 0.00 0.00 2604.20 20 1249256 91.22 334.06 6226.46 6170.26 1129.83 4649.28 5958422.50 1513344.73 1.00 -0.19 265114 CD4-213 14Jun11 76 40 0 0 - 21 12498.05 9128 334.06 6226.34 6170.14 113476 4651.68 5958427.47 1513342.41 1.00 -021 2657.30 _ 22 13118.38 91.28 334.06 6212.49 6156.29 1692.48 492292 5958989.49 1513080.31 0.00 0.00 3274.15 - - CO 23 13206.77 90.40 334.06 621110 6155.00 1771.96 4961.57 5959069.57 1513042.97 1.00 179.99 3362.05 004.21314Iun1117 24 13207.82 90.38 334.06 6211.19 6154.99 1772.90 4962.03 5959070.52 1513042.52 1.00 - 179.98 3363.09 - I CD4-21310 un11111 3rJ - 25 13866.54 90.38 334.08 6206.77 6150.57 2365.26 .5250.12 5959667.45 1512764.14 0.00 900 4018.27 3 26 13904.83 9 334.06 6198.14 6150.19 2953.25 653807 5959702.16 1151248 82 1.00 0.02 4054.36 CD4-213 T9 - 7'x8 -3/4" $00 - -2000 -1000 0 1000 2000 05 I I I I 1 I I I I I 1 I I I I I 1 I I I I I I I I I I I _ ' i r, _ 0 00 - Drillout: 50.00 hold at 8264.56 MD / e 00 --3000 M� ild` 1 _ G - I I I I T 1 I I I I I 1 I ail I I I I I I I 1 -6000 4500 -3000 -1500 0 Drillout: 50.00 hold at 8264.56 MD West( - )/East( +) (1500 Win) 6080 / C / - ANNOTATIONS f ND TVDSS MD Annotation U) / - 819722 6141.02 826456 0rilbut: 5000 hold x 826458 MD W 620150 6145.30 841450 Start 5 63 h ld 2 0-49 .90 MD 9 • J= - 8 I - 64 1. / 6228 74 6172 9064.53 Start DLS 2 TF-24.41 6211.78 6155 58 8492.90 Sta1 Q O 6230.10 6173.90 9145.76 Start 561.94 hold at 9145.76 MD 0) / 6232.41 6176 21 9707.69 Seel 0161.00 TFO -1.57 t] - / - 6232.45 6176.25 9731.18 Start DLS 100 TFO -002 / 623220 617600 978507 Start 379.40 hold et 9785.07 MD _ 6228.63 617243 0164.47 Slat DLS 100 TFO 179.70 I CD4 -21 6228.38 6172.18 0218.38 Start DLS 1.00 TFO - 180.00 - I 3 -112 % 6 -118" a1 6228.46 617226 0248.10 Slat 920.56 hold at 10248.10 MD 6175- I I - 6175 623331 6177.03 119282 Stn DLS 1 IN) TFO 001 d / O / / 6233.31 6177.11 119722 Slat 617726 1932 80 Start DLS 190 TFO -16.51 22 MO / M i / - 6233.46 6177 26 1934.04 Start DLS 1.0 TFO 0.01 hold at • - I - - 1 ' 6232.98 6176 78 200855 Start 436.12 hold at 12008.55 MD 622728 6171.08 2444.66 Slat DLS 100 TFO -0 19 - erg O O a ` - 6226.46 617026 2492.56 Slat DLS 1.0 TFO - 0.01 / 00 0 ' A 5 N ■ 6226.34 6170.14 2498 05 518.1 620.3311014 at 1249805 MD O 0 O 0 G3 d 621249 6156.29 3118.38 Slat DLS 1.0 TFO 179 99 - 7 x 8 -3/4" 01 06 01 0 " 00 '� / / 0 0 I I CD4.213wp01l- 6211 20 6155.00 3208.77 Slat DLS 1.0 TFO - 17998 + 0 I / I 6211.19 6154.99 3207 82 Start 658.72 hold at 13207.82 MD 7 0 I / I _ 6206.77 6150.57 3866.54 Slat 01.5 1.00 TFO 002 I 6206.39 6150.19 3904.83 Slat 615.60 held at 13904 83 MO 0 < / I / CD4 -213 14Jun11 1�6 - 6198.14 6141.94 4520.43 TD x 14520.43 I / FORMATION TOP DETAILS I CD4 -213 14Jun11 t I CD4-213 14Jun11 113 CD4- 213 14Jun11 5 / CD4-21314Jun11117 /CD4- 21314Jun11119 -6 270 6270 ( TVDPath TVD4sPah MDPxh Formation I CD4-213 14Jun11 112 I C D4213 14Jun11 114 I CD4 -213 14 Jun 11 11 Base NamR _ 618920 613300 81940 Tap 54109 (1400891 96) I - I I I I I I I I I I 1 I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 I I I I -200 -1000 0 1000 2000 3000 4000 5000 Vertical Section at 340.00 °(1000 Win) CD4- 213wp07 Plan View 3000 1520 3 -1/2" x 6 -1/8" 00 A A 2000— G9‘.1' 213�p 0 1 300 1000 • 12000 0 11000 100 0 Z 2000 00 9 -5/8" x 12 -1 /4" - st 01000 - 10 v) 30 0 0 4000 • -2000— 90 6 00 0 7" x 8 -3/4 "- 1� 0 00 3 -3000— 600 I I I .I -7000 -6000 -5000 -4000 -3000 -'1•00 -1000 0 1000 West( -) /East( +) (1000 ft/in) CD4- 213wp07 Section View 6160 - c) 0 6180- w 7" x 8 -3/4" g 3 -1/2" x 6 -1/8" o • C N 6200- 4* N O Q O 4) 0 o0 O N co O 6220- CD o , O 0 0 0 0 O ,- a) (0 4) 0 O O 6240- ° o ° 0 6260 - I I I I 1 I 1 1 I -1500 -750 0 750 1500 2250 3000 3750 4500 Vertical Section at 340.00° (750 ft/in) • • ConocoPhillips HALLIBURTDN Standard Proposal Report Database: EDM v16 Prod Local Co- ordinate Reference: Well CD4 -213 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: 36.3 +19.9 @ 56.20ft (Doyon 19) Project: Western North Slope MO Reference: Plan: 36.3 +19.9 @ 56.20ft (Doyon 19) . Site: CD4 Nanuq Pad North' Reference: True Welk CD4 -213 Surveycalcu Method: Minimum Curvature Wellbore: CD4 -213 Design: CD4- 213wp07 Project Western North Slope Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site CD4 Nanuq Pad Site Position: Northing: 5,957,908.57ft Latitude: 70° 17' 36.666 N From: Map Easting: 377,794.25ft Longitude: 150° 59' 22.031 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -0.93 ° Well CD4 -213, Alpine CD4 Well Position +N /-S 0.00 ft Northing: 5,957,470.04 ft Latitude: 70° 17' 32.377 N +E/ -W 0.00 ft Easting: 377,941.09 ft Longitude: 150° 59' 17.544 W 1 Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 19.90ft , Wellbore CD4 -213 Magnetics Model Name Sample Date Declination Dip Angle Field Strength . (°) r) (nT) BGGM2011 6/14/2011 16.06 79.70 57,317 Design CD4- 213wp07 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,264.56 Vertical Sermon: Depth From (TVD) 444/4 +E/-W Direction (ft) (ft) 0) ( 36.30 0.00 0.00 340.00 6/15/2011 12 :54 :43PM Page 2 COMPASS 2003.16 Build 69 • • ConocoPhillips HALLIBUR"T DN Standard Proposal Report Database: EDM v16 Prod Local Co- ordinate Reference: Well CD4 - 213 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: 36.3 +19.9 @ 56.20ft (Doyon 19) Project: Western North Slope MD Reference: Plan: 36.3 +19.9 @ 56.20ft ( Doyon 19) Site: CD4 Nanuq Pad North Reference: True Welk CD4 -213 Survey Caieulation Method: Minimum Curvature Wellbore: CD4 -213 Design: CD4- 213wp07 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth. inclination Az muth Depth System . +N! S +E/-W Rate Rate Rate Tool Face tft) ( t tft) ft (ft) (ft) MOON) t °!lOOft) 0100ft) ( 8,264.56 85.09 336.30 6,197.22 6,141.02 - 2,677.57 - 2,813.11 0.00 0.00 0.00 0.00 8,314.56 85.09 336.30 6,201.50 6,145.30 - 2,631.95 - 2,833.13 0.00 0.00 0.00 0.00 I 8,492.99 88.30 334.74 6,211.78 6,155.58 - 2,469.86 - 2,906.94 2.00 1.80 -0.88 -25.95 9,064.94 88.30 334.74 6,228.74 6,172.54 - 1,952.83 - 3,150.91 0.00 0.00 0.00 0.00 9,145.61 89.77 334.07 6,230.10 6,173.90 - 1,880.09 - 3,185.75 2.00 1.82 -0.82 -24.37 9,146.38 89.77 334.08 6,230.11 6,173.91 -1,879.40 - 3,186.09 1.00 -0.61 0.79 127.79 9,708.00 89.77 334.08 6,232.41 6,176.21 - 1,374.29 - 3,431.59 0.00 0.00 0.00 0.00 9,731.50 90.00 334.07 6,232.45 6,176.25 - 1,353.15 - 3,441.87 1.00 1.00 -0.05 -3.02 9,785.40 90.54 334.07 6,232.20 6,176.00 - 1,304.68 - 3,465.43 1.00 1.00 0.01 0.68 10,164.80 90.54 334.07 6,228.63 6,172.43 - 963.48 - 3,631.31 0.00 0.00 0.00 0.00 10,218.69 90.00 334.07 6,228.38 6,172.18 - 915.01 - 3,654.87 1.00 -1.00 -0.01 - 179.61 10,248.44 89.70 334.08 6,228.46 6,172.26 - 888.26 - 3,667.88 1.00 -1.00 0.02 178.84 11,168.99 89.70 334.08 6,233.23 6,177.03 -60.35 -4,070.33 0.00 0.00 0.00 0.00 11,197.56 89.99 334.07 6,233.31 6,177.11 -34.66 - 4,082.81 1.00 1.00 -0.02 -1.20 11,198.14 89.99 334.08 6,233.31 6,177.11 -34.14 -4,083.07 1.00 0.00 1.00 90.12 11,932.87 89.99 334.08 6,233.46 6,177.26 626.66 - 4,404.29 0.00 0.00 0.00 0.00 11,934.38 90.00 334.07 6,233.46 6,177.26 628.02 - 4,404.95 1.00 0.78 -0.62 -38.28 12,009.22 90.75 334.07 6,232.97 6,176.77 695.31 - 4,437.67 1.00 1.00 0.01 0.51 12,445.33 90.75 334.07 6,227.28 6,171.08 1,087.50 - 4,628.33 0.00 0.00 0.00 0.00 12,492.91 91.22 334.06 6,226.46 6,170.26 1,130.28 - 4,649.14 1.00 1.00 -0.02 -0.98 ' 12,498.43 91.28 334.07 6,226.34 6,170.14 1,135.25 - 4,651.55 1.00 0.99 0.11 6.49 13,118.74 91.28 334.07 6,212.49 6,156.29 1,692.97 - 4,922.72 0.00 0.00 0.00 0.00 13,207.12 90.40 334.06 6,211.20 6,155.00 1,772.45 - 4,961.37 1.00 -1.00 -0.01 - 179.61 13,208.33 90.38 334.07 6,211.19 6,154.99 1,773.54 - 4,961.90 1.00 -0.87 0.50 150.24 13,866.89 90.38 334.07 6,206.77 6,150.57 2,365.79 - 5,249.85 0.00 0.00 0.00 0.00 13,905.19 90.77 334.06 6,206.39 6,150.19 2,400.23 - 5,266.60 1.00 1.00 -0.02 -0.88 14,520.79 90.77 334.08 6,198.14 6,141.94 2,953.81 - 5,535.76 0.00 0.00 0.00 90.05 6/15/2011 12 :54 :43PM Page 3 COMPASS 2003.16 Build 69 • • ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well CD4 -213 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: 36.3 +19.9 @ 56.20ft (Doyon 19) Project: Western North Slope MD Reference: Plan: 36.3 +19.9 @ 56.20ft ( Doyon 19) Site: CD4 Nanuq Pad North Reference: True Welk CD4 -213 Survey Calculation Method: Minimum Curvature Welibore: CD4 -213 Design: CD4- 213wp07 Planned Survey red . Vertical Map Map DePlft Inclination Azimuth thaPth TVDss +N/-S +E/-W Northing . Easting DLS Vert Section (ft) (1 (*) ft (ft) (ft) (ft) (ft) 6,141.02 8,264.56 85.09 336.30 6,197.22 6,141.02 - 2,677.57 - 2,813.11 5,954,838.72 375,085.12 4.60 - 1,553.95 Drillout: 50.00 hold at 8264.56 MD - T' x 8-3/4" 8,300.00 85.09 336.30 6,200.25 6,144.05 - 2,645.24 - 2,827.30 5,954,871.27 375,071.45 0.00 - 1,518.72 8,314.56 85.09 336.30 6,201.50 6,145.30 - 2,631.95 - 2,833.13 5,954,884.65 375,065.84 0.00 - 1,504.24 Start DLS 2.00 TFO -25.93 8,400.00 86.63 335.55 6,207.67 6,151.47 - 2,554.15 - 2,867.89 5,954,963.00 375,032.35 2.00 - 1,419.24 8,492.90 88.30 334.74 6,211.78 6,155.58 - 2,469.95 - 2,906.90 5,955,047.82 374,994.71 2.00 - 1,326.77 Start 571.63 hold at 8492.90 MD 8,492.99 88.30 334.74 6,211.78 6,155.58 - 2,469.86 - 2,906.94 5,955,047.90 374,994.68 2.00 - 1,326.68 8,500.00 88.30 334.74 6,211.99 6,155.79 - 2,463.53 - 2,909.93 5,955,054.29 374,991.79 0.00 - 1,319.70 8,600.00 88.30 334.74 6,214.95 6,158.75 - 2,373.13 - 2,952.59 5,955,145.36 374,950.61 0.00 - 1,220.17 8,700.00 88.30 334.74 6,217.92 6,161.72 - 2,282.73 - 2,995.24 5,955,236.43 374,909.43 0.00 - 1,120.63 8,800.00 88.30 334.74 6,220.89 6,164.69 - 2,192.33 - 3,037.90 5,955,327.50 374,868.25 0.00 - 1,021.10 8,900.00 88.30 334.74 6,223.85 6,167.65 - 2,101.94 - 3,080.55 5,955,418.57 374,827.07 0.00 - 921.56 9,000.00 88.30 334.74 6,226.82 6,170.62 - 2,011.54 - 3,123.21 5,955,509.64 374,785.89 0.00 - 822.03 9,064.53 88.30 334.74 6,228.73 6,172.53 - 1,953.21 - 3,150.73 5,955,568.40 374,759.32 0.00 - 757.80 Start DLS 2.00 TFO - 24.41 9,064.94 88.30 334.74 6,228.74 6,172.54 - 1,952.83 - 3,150.91 5,955,568.78 374,759.15 0.00 - 757.39 9,100.00 88.94 334.45 6,229.59 6,173.39 - 1,921.18 - 3,165.95 5,955,600.68 374,744.63 2.00 - 722.50 9,145.61 89.77 334.07 6,230.10 6,173.90 - 1,880.09 - 3,185.75 5,955,642.07 374,725.50 2.00 - 677.12 CD4 - 213 14Jun11 T1 9,145.76 89.77 334.07 6,230.10 6,173.90 - 1,879.96 - 3,185.82 5,955,642.20 374,725.43 0.00 - 676.97 Start 561.94 hold at 9145.76 MD 9,146.38 89.77 334.08 6,230.11 6,173.91 - 1,879.40 - 3,186.09 5,955,642.77 374,725.17 1.23 - 676.35 9,200.00 89.77 334.08 6,230.32 6,174.12 - 1,831.18 - 3,209.53 5,955,691.37 374,702.52 0.00 - 623.02 9,300.00 89.77 334.08 6,230.73 6,174.53 - 1,741.24 - 3,253.24 5,955,782.00 374,660.28 0.00 - 523.55 9,400.00 89.77 334.08 6,231.14 6,174.94 - 1,651.30 - 3,296.95 5,955,872.62 374,618.03 0.00 - 424.09 9,500.00 89.77 334.08 6,231.55 6,175.35 - 1,561.36 - 3,340.67 5,955,963.25 374,575.79 0.00 - 324.62 9,600.00 89.77 334.08 6,231.96 6,175.76 - 1,471.42 - 3,384.38 5,956,053.88 374,533.55 0.00 - 225.16 9,700.00 89.77 334.08 6,232.37 6,176.17 - 1,381.48 - 3,428.09 5,956,144.51 374,491.31 0.00 - 125.69 9,707.69 89.77 334.08 6,232.41 6,176.21 - 1,374.56 - 3,431.45 5,956,151.48 374,488.06 0.00 - 118.04 Start DLS 1.00 TFO -t5T 9,708.00 89.77 334.08 6,232.41 6,176.21 - 1,374.29 - 3,431.59 5,956,151.76 374,487.93 0.00 - 117.74 1 9,731.18 90.00 334.07 6,232.45 6,176.25 - 1,353.44 - 3,441.72 5,956,172.77 374,478.13 1.00 -94.68 Start DLS 1.00 TFO -0.02 9,731.50 90.00 334.07 6,232.45 6,176.25 - 1,353.15 - 3,441.87 5,956,173.06 374,477.99 1.00 - 94.35 CD4 14Jun11 T2 9,785.07 90.54 334.07 6,232.20 6,176.00 - 1,304.97 - 3,465.29 5,956,221.61 374,455.36 1.00 - 41.08 Start 379.40 hold at 9785.07 MD 9,785.40 90.54 334.07 6,232.20 6,176.00 - 1,304.68 - 3,465.43 5,956,221.91 374,455.22 1.00 -40.75 9,800.00 90.54 334.07 6,232.06 6,175.86 - 1,291.55 - 3,471.82 5,956,235.14 374,449.05 0.00 -26.23 9,900.00 90.54 334.07 6,231.12 6,174.92 - 1,201.62 - 3,515.54 5,956,325.76 374,406.80 0.00 73.23 10,000.00 90.54 334.07 6,230.18 6,173.98 - 1,111.69 - 3,559.26 5,956,416.38 374,364.55 0.00 172.69 10,100.00 90.54 334.07 6,229.24 6,173.04 - 1,021.75 - 3,602.98 5,956,507.00 374,322.30 0.00 272.16 6/1512011 12 :54 :43PM Page 4 COMPASS 2003.16 Build 69 • • ConocoPhillips HALLIBURTDN Standard Proposal Report Database: EDM v16 Prod Local Co- ordiruder Reference: Well CD4 - 213 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: 36.3 +19.9 @ 56.20ft (Doyon 19) Project: Western North Slope MD Reference: Plan: 36.3 +19.9 @ 56.20ft (Doyon 19) Site: CD4 Nanuq Pad North Reference: True Well: CD4 -213 Survey Calculation Method: Minimum Curvature Wellbore: CD4 -213 Design: CD4- 213wp07 Planned Surrey Measured Vertical Map Map Depth inclination Azimuth rhoPth TtfDS+s +NI-S +Ef-W Northing Easting DLS Vert Section (ft) ( °) (°) . (ft) ft (ft) (ft) (ft) (ft) 6,172.44 10,164.47 90.54 334.07 6,228.64 6,172.44 - 963.78 - 3,631.16 5,956,565.42 374,295.06 0.00 336.27 Start DLS 1.00 TFO 179.70 10,164.80 90.54 334.07 6,228.63 6,172.43 - 963.48 - 3,631.31 5,956,565.72 374,294.92 0.00 336.61 10,200.00 90.19 334.07 6,228.41 6,172.21 - 931.82 - 3,646.70 5,956,597.62 374,280.05 1.00 371.62 10,218.36 90.00 334.07 6,228.38 6,172.18 - 915.31 - 3,654.73 5,956,614.26 374,272.29 1.00 389.88 Start DLS 1.00 TFO - 180.00 10,218.69 90.00 334.07 6,228.38 6,172.18 - 915.01 - 3,654.87 5,956,614.57 374,272.15 1.00 390.21 CD4-213 14Juni 1 T3 10,248.10 89.71 334.08 6,228.45 6,172.25 - 888.56 - 3,667.73 5,956,641.22 374,259.72 1.00 419.46 Start 920.56 hold at 10248.10 MD 10,248.44 89.70 334.08 6,228.46 6,172.26 - 888.26 - 3,667.88 5,956,641.52 374,259.58 1.00 419.80 10,300.00 89.70 334.08 6,228.72 6,172.52 - 841.89 - 3,690.42 5,956,688.25 374,237.80 0.00 471.08 10,400.00 89.70 334.08 6,229.24 6,173.04 - 751.95 - 3,734.14 5,956,778.88 374,195.55 0.00 570.55 10,500.00 89.70 334.08 6,229.76 6,173.56 - 662.02 - 3,777.86 5,956,869.50 374,153.30 0.00 670.01 10,600.00 89.70 334.08 6,230.28 6,174.08 - 572.08 - 3,821.57 5,956,960.13 374,111.05 0.00 769.48 10,700.00 89.70 334.08 6,230.80 6,174.60 - 482.14 - 3,865.29 5,957,050.75 374,068.80 0.00 868.94 10,800.00 89.70 334.08 6,231.32 6,175.12 - 392.21 - 3,909.01 5,957,141.38 374,026.55 0.00 968.41 10,900.00 89.70 334.08 6,231.84 6,175.64 - 302.27 - 3,952.73 5,957,232.01 373,984.30 0.00 1,067.87 11,000.00 89.70 334.08 6,232.36 6,176.16 - 212.34 - 3,996.45 5,957,322.63 373,942.06 0.00 1,167.33 11,100.00 89.70 334.08 6,232.88 6,176.68 - 122.40 - 4,040.16 5,957,413.26 373,899.81 0.00 1,266.80 11,168.66 89.70 334.08 6,233.23 6,177.03 - 60.65 - 4,070.18 5,957,475.48 373,870.80 0.00 1,335.09 Start DLS 1.00 TFO 0.01 11,168.99 89.70 334.08 6,233.23 6,177.03 -60.35 - 4,070.33 5,957,475.79 373,870.66 0.00 1,335.42 11,197.22 89.98 334.07 6,233.31 6,177.11 -34.97 - 4,082.67 5,957,501.36 373,858.73 1.00 1,363.49 i Start 735.59 hold at 11197.22 MD 11,197.56 89.99 334.07 6,233.31 6,177.11 -34.66 - 4,082.81 5,957,501.67 373,858.59 1.00 1,363.83 CD4- 213 14Jun11 T4 11,198.14 89.99 334.08 6,233.31 6,177.11 -34.14 -4,083.07 5,957,502.20 373,858.34 1.00 1,364.41 11,200.00 89.99 334.08 6,233.31 6,177.11 - 32.46 - 4,083.88 5,957,503.89 373,857.56 0.00 1,366.26 11,300.00 89.99 334.08 6,233.33 6,177.13 57.47 - 4,127.60 5,957,594.51 373,815.31 0.00 1,465.73 11,400.00 89.99 334.08 6,233.35 6,177.15 147.41 - 4,171.32 5,957,685.14 373,773.06 0.00 1,565.19 11,500.00 89.99 334.08 6,233.37 6,177.17 237.35 - 4,215.04 5,957,775.77 373,730.81 0.00 1,664.66 11,600.00 89.99 334.08 6,233.39 6,177.19 327.28 - 4,258.76 5,957,866.40 373,688.56 0.00 1,764.13 11,700.00 89.99 334.08 6,233.42 6,177.22 417.22 - 4,302.48 5,957,957.02 373,646.31 0.00 1,863.59 11,800.00 89.99 334.08 6,233.44 6,177.24 507.16 - 4,346.20 5,958,047.65 373,604.06 0.00 1,963.06 11,900.00 89.99 334.08 6,233.46 6,177.26 597.09 - 4,389.91 5,958,138.28 373,561.81 0.00 2,062.52 11,932.80 89.99 334.08 6,233.46 6,177.26 626.59 - 4,404.26 5,958,168.01 373,547.95 0.00 2,095.15 Start DLS 1.00 TFO - 16.51 11,932.87 89.99 334.08 6,233.46 6,177.26 626.66 - 4,404.29 5,958,168.07 373,547.92 0.00 2,095.22 11,934.04 90.00 334.07 6,233.46 6,177.26 627.71 - 4,404.80 5,958,169.13 373,547.43 1.00 2,096.38 Start DLS 1.00 TFO 0.01 11,934.38 90.00 334.07 6,233.46 6,177.26 628.02 - 4,404.95 5,958,169.44 373,547.29 1.00 2,096.72 CD4- 213 14Jun11 T5 12,000.00 90.66 334.07 6,233.09 6,176.89 687.03 - 4,433.64 5,958,228.90 373,519.56 1.00 2,161.99 6/15/2011 12 :54 :43PM Page 5 COMPASS 2003.16 Build 69 III • ConocoPhillips HALLIBURTDN Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well CD4 - 213 Company: ConocoPhillips(Alaska) Inc. TVD rice: Plan: 36.3 +19.9 @ 56.20ft (Doyon 19) Project Western North Slope MD Reference: Plan: 36.3 +19.9 @ 56.20ft ( Doyon 19) Site: CD4 Nanuq Pad North Reference: True Welk CD4 -213 Survey Calculation Method: Minimum Curvature Wellbore: CD4 -213 Design: CD4- 213wp07 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TYDss +NIS +E/ W Northing Easting DLS Vert Section (ft) ( (°) (ft) it (ft) (ft) (ft) (ft) 6,176.78 12,008.55 90.74 334.07 6,232.98 6,176.78 694.71 - 4,437.38 5,958,236.65 373,515.95 1.00 2,170.49 Start 436.12 hold at 12008.55 MD 12,009.22 90.75 334.07 6,232.97 6,176.77 695.31 - 4,437.67 5,958,237.25 373,515.66 1.00 2,171.15 12,100.00 90.75 334.07 6,231.79 6,175.59 776.95 - 4,477.36 5,958,319.52 373,477.31 0.00 2,261.44 12,200.00 90.75 334.07 6,230.48 6,174.28 866.88 - 4,521.08 5,958,410.14 373,435.06 0.00 2,360.90 12,300.00 90.75 334.07 6,229.18 6,172.98 956.81 - 4,564.80 5,958,500.75 373,392.81 0.00 2,460.36 12,400.00 90.75 334.07 6,227.87 6,171.67 1,046.74 - 4,608.52 5,958,591.37 373,350.56 0.00 2,559.82 12,444.66 90.75 334.07 6,227.28 6,171.08 1,086.90 - 4,628.04 5,958,631.84 373,331.69 0.00 2,604.23 Start DLS 1.00 TFO - 0.19 12,445.33 90.75 334.07 6,227.28 6,171.08 1,087.50 - 4,628.33 5,958,632.45 373,331.41 0.00 2,604.90 12,492.56 91.22 334.06 6,226.46 6,170.26 1,129.97 - 4,648.99 5,958,675.25 373,311.45 1.00 2,651.87 Start DLS 1.00 TFO - 0.01 12,492.91 91.22 334.06 6,226.46 6,170.26 1,130.28 - 4,649.14 5,958,675.56 373,311.30 1.00 2,652.22 CD4 14Jun11 T6 12,498.05 91.28 334.07 6,226.34 6,170.14 1,134.90 - 4,651.39 5,958,680.22 373,309.13 1.00 2,657.33 Start 620.33 hold at 12498.05 MD 12,498.43 91.28 334.07 6,226.34 6,170.14 1,135.25 - 4,651.55 5,958,680.57 373,308.97 1.00 2,657.71 12,500.00 91.28 334.07 6,226.30 6,170.10 1,136.66 - 4,652.24 5,958,681.98 373,308.31 0.00 2,659.27 12,600.00 91.28 334.07 6,224.07 6,167.87 1,226.57 - 4,695.95 5,958,772.59 373,266.06 0.00 2,758.71 12,700.00 91.28 334.07 6,221.84 6,165.64 1,316.48 - 4,739.67 5,958,863.19 373,223.81 0.00 2,858.15 12,800.00 91.28 334.07 6,219.61 6,163.41 1,406.39 - 4,783.38 5,958,953.79 373,181.57 0.00 2,957.59 12,900.00 91.28 334.07 6,217.37 6,161.17 1,496.30 - 4,827.10 5,959,044.39 373,139.32 0.00 3,057.03 13,000.00 91.28 334.07 6,215.14 6,158.94 1,586.21 - 4,870.81 5,959,134.99 373,097.08 0.00 3,156.47 13,100.00 91.28 334.07 6,212.91 6,156.71 1,676.12 - 4,914.53 5,959,225.59 373,054.83 0.00 3,255.91 13,118.38 91.28 334.07 6,212.50 6,156.30 1,692.65 - 4,922.57 5,959,242.25 373,047.06 0.00 3,274.19 Start DLS 1.00 TFO 179.99 13,118.74 91.28 334.07 6,212.49 6,156.29 1,692.97 - 4,922.72 5,959,242.57 373,046.91 0.00 3,274.54 13,200.00 90.47 334.07 6,211.25 6,155.05 1,766.04 - 4,958.25 5,959,316.20 373,012.58 1.00 3,355.36 13,206.77 90.40 334.06 6,211.20 6,155.00 1,772.13 - 4,961.21 5,959,322.34 373,009.71 1.00 3,362.09 Start DLS 1.00 TFO - 179.98 13,207.12 90.40 334.06 6,211.20 6,155.00 1,772.45 - 4,961.37 5,959,322.66 373,009.57 1.00 3,362.44 CD4 14Jun11 77 13,207.82 90.39 334.07 6,211.20 6,155.00 1,773.07 - 4,961.67 5,959,323.29 373,009.27 1.00 3,363.14 Start 658.72 hold at 13207.82 MD 13,208.33 90.38 334.07 6,211.19 6,154.99 1,773.54 - 4,961.90 5,959,323.75 373,009.05 1.00 3,363.65 13,300.00 90.38 334.07 6,210.58 6,154.38 1,855.97 - 5,001.98 5,959,406.82 372,970.32 0.00 3,454.82 13,400.00 90.38 334.07 6,209.90 6,153.70 1,945.90 - 5,045.70 5,959,497.45 372,928.06 0.00 3,554.28 13,500.00 90.38 334.07 6,209.23 6,153.03 2,035.84 - 5,089.43 5,959,588.07 372,885.81 0.00 3,653.75 13,600.00 90.38 334.07 6,208.56 6,152.36 2,125.77 - 5,133.15 5,959,678.69 372,843.55 0.00 3,753.21 13,700.00 90.38 334.07 6,207.89 6,151.69 2,215.70 - 5,176.88 5,959,769.31 372,801.30 0.00 3,852.67 13,800.00 90.38 334.07 6,207.22 6,151.02 2,305.63 - 5,220.60 5,959,859.93 372,759.04 0.00 3,952.14 13,866.54 90.38 334.07 6,206.77 6,150.57 2,365.47 - 5,249.70 5,959,920.23 372,730.92 0.00 4,018.32 Start DLS 1.00 TFO 0.02 13,866.89 90.38 334.07 6,206.77 6,150.57 2,365.79 - 5,249.85 5,959,920.55 372,730.78 0.00 4,018.67 13,900.00 90.72 334.07 6,206.45 6,150.25 2,395.56 - 5,264.33 5,959,950.55 372,716.78 1.00 4,051.60 1 6115/2011 12:54.43PM Page 6 COMPASS 2003.16 Build 69 0 • ConocoPhillips HALLIBURTQN Standard Proposal Report Database: EDM v16 Prod Local Co- ordinate Reference: Well CD4 -213 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: 36.3 +19.9 @ 56.20ft (Doyon 19) Project Western North Slope MD Reference: Plan: 36.3 +19.9 @ 56.20ft ( Doyon 19) Site: CD4 Nanuq Pad North Reference: True Welk CD4 -213 Survey Calculation Method: Minimum Curvature Wel Mote: CD4 -213 Design: CD4- 213wp07 Planned Survey Measured Ventral Map Map Depth Inclination Azimuth Del TYDes +N/-E +E/ Northing Fasting DLS Vert Section (ft) ( (6) (ft) ft (ft) (ft) (ft) (ft) 6,150.19 13,904.83 90.76 334.06 6,206.39 6,150.19 2,399.91 - 5,266.44 5,959,954.94 372,714.74 1.00 4,056.41 Start 615.60 hold at 13904.83 MD 13,905.19 90.77 334.06 6,206.39 6,150.19 2,400.23 - 5,266.60 5,959,955.26 372,714.59 1.00 4,056.76 CD4 14Jun11 T8 14,000.00 90.77 334.07 6,205.12 6,148.92 2,485.48 - 5,308.06 5,960,041.17 372,674.52 0.00 4,151.05 14,100.00 90.77 334.07 6,203.78 6,147.58 2,575.40 - 5,351.79 5,960,131.78 372,632.27 0.00 4,250.51 14,200.00 90.77 334.07 6,202.44 6,146.24 2,665.33 - 5,395.51 5,960,222.40 372,590.01 0.00 4,349.96 14,300.00 90.77 334.07 6,201.10 6,144.90 2,755.26 - 5,439.23 5,960,313.01 372,547.76 0.00 4,449.42 14,400.00 90.77 334.07 6,199.76 6,143.56 2,845.18 - 5,482.95 5,960,403.63 372,505.51 0.00 4,548.88 14,500.00 90.77 334.08 6,198.42 6,142.22 2,935.11 - 5,526.67 5,960,494.25 372,463.26 0.00 4,648.33 14,520.43 90.77 334.08 6,198.14 6,141.94 2,953.48 - 5,535.60 5,960,512.76 372,454.63 0.00 4,668.65 TD at 14520.43 - 3-112" x 6 - 118" 14,520.79 90.77 334.08 6,198.14 6,141.94 2,953.81 - 5,535.76 5,960,513.09 372,454.48 0.11 4,669.02 CD4- 213 14Jun11 T9 Targets Target Name - hit/miss target Dip Angie Dip Dir. TVD +N/-S +E/ -W Northing Fang - Shape ( (°) (ft) (ft) (ft) (ft) (ft) CD4 -213 14Jun11 T1 0.00 0.00 6,230.10 - 1,880.09 - 3,185.75 5,955,642.07 374,725.50 - plan hits target center - Point � CD4 -213 14Jun11 T8 0.00 0.00 6,206.39 2,400.23 - 5,266.60 5,959,955.26 372,714.59 1 - plan hits target center - Point CD4 -213 14Jun11 T4 0.00 0.00 6,233.31 -34.66 - 4,082.81 5,957,501.67 373,858.59 - plan hits target center - Point CD4-213 14Jun11 T9 0.00 0.00 6,198.14 2,953.81 - 5,535.76 5,960,513.09 372,454.48 - plan hits target center - Point 1 CD4 -213 14Jun11 T7 0.00 0.00 6,211.20 1,772.45 - 4,961.37 5,959,322.66 373,009.57 - plan hits target center i - Point CD4 -213 14Jun11 T5 0.00 0.00 6,233.46 628.02 - 4,404.95 5,958,169.44 373,547.29 - plan hits target center - Point CD4 -213 14Jun11 T3 0.00 0.00 6,228.38 - 915.01 - 3,654.87 5,956,614.57 374,272.15 - plan hits target center - Point CD4-213 14Jun11 T6 0.00 0.00 6,226.46 1,130.28 - 4,649.14 5,958,675.56 373,311.30 - plan hits target center - Point CD4-213 14Jun11 T2 0.00 0.00 6,232.45 - 1,353.15 - 3,441.87 5,956,173.06 374,477.99 - plan hits target center - Point 6/15/2011 12:54:43PM Page 7 COMPASS 2003.16 Build 69 • . ConocoPhillips HALLIBURTDN Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well CD4 - 213 Company: ConocoPhillips(Alaska) Inc. TVD Plan: 36.3 +19.9 @ 56.20ft (Doyon 19) Project Western North Slope MD Refetetice: Plan: 36.3 +19.9 @ 56.20ft (Doyon 19) Site: CD4 Nanuq Pad North Reference: True Wet CD4 - 213 Survey Calculation Minimum Curvature Welibore: CD4 - 213 Design: CD4 213wp07 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) Oft Name r) (1 2,712.67 2,388.49 9 -5/8" x 12 -1/4" 9 -5/8 12 -1/4 8,264.56 6,197.22 7" x 8 -3/4" 7 8 -3/4 14,520.43 6,198.14 3 -1/2" x 6 -1/8" 3 -1/2 6 -1/8 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology C) ( 8,194.06 6,189.20 Top Nanuq (Albian 96) 6,316.20 Base Nanuq Plan Annotations Measured Vertical Local Coordinates Depth Depth +WIWS +El-W (ft) (ft) (it) (i) Comment 8,264.56 6,197.22 - 2,677.57 - 2,813.11 Drillout: 50.00 hold at 8264.56 MD 8,314.56 6,201.50 - 2,631.95 - 2,833.13 Start DLS 2.00 TFO -25.93 8,492.90 6,211.78 - 2,469.95 - 2,906.90 Start 571.63 hold at 8492.90 MD 9,064.53 6,228.73 - 1,953.21 - 3,150.73 Start DLS 2.00 TFO -24.41 9,145.76 6,230.10 - 1,879.96 - 3,185.82 Start 561.94 hold at 9145.76 MD 9,707.69 6,232.41 - 1,374.56 - 3,431.45 Start DLS 1.00 TFO -1.57 9,731.18 6,232.45 - 1,353.44 - 3,441.72 Start DLS 1.00 TFO -0.02 9,785.07 6,232.20 - 1,304.97 - 3,465.29 Start 379.40 hold at 9785.07 MD 10,164.47 6,228.64 - 963.78 - 3,631.16 Start DLS 1.00 TFO 179.70 10,218.36 6,228.38 - 915.31 - 3,654.73 Start DLS 1.00 TFO - 180.00 10,248.10 6,228.45 - 888.56 - 3,667.73 Start 920.56 hold at 10248.10 MD 11,168.66 6,233.23 -60.65 - 4,070.18 Start DLS 1.00 TFO 0.01 11,197.22 6,233.31 -34.97 - 4,082.67 Start 735.59 hold at 11197.22 MD 11,932.80 6,233.46 626.59 - 4,404.26 Start DLS 1.00 TFO -16.51 11,934.04 6,233.46 627.71 - 4,404.80 Start DLS 1.00 TFO 0.01 12,008.55 6,232.98 694.71 - 4,437.38 Start 436.12 hold at 12008.55 MD 12,444.66 6,227.28 1,086.90 - 4,628.04 Start DLS 1.00 TFO -0.19 12,492.56 6,226.46 1,129.97 - 4,648.99 Start DLS 1.00 TFO -0.01 12,498.05 6,226.34 1,134.90 - 4,651.39 Start 620.33 hold at 12498.05 MD 13,118.38 6,212.50 1,692.65 - 4,922.57 Start DLS 1.00 TFO 179.99 13,206.77 6,211.20 1,772.13 - 4,961.21 Start DLS 1.00 TFO - 179.98 13,207.82 6,211.20 1,773.07 - 4,961.67 Start 658.72 hold at 13207.82 MD 13,866.54 6,206.77 2,365.47 - 5,249.70 Start DLS 1.00 TFO 0.02 13,904.83 6,206.39 2,399.91 - 5,266.44 Start 615.60 hold at 13904.83 MD 14,520.43 6,198.14 2,953.49 - 5,535.60 TD at 14520.43 6/15/2011 12:54:43PM Page 8 COMPASS 2003.16 Build 69 44 It -y ConocoPhillips(Alaska) Inc. -WNS fi Western North Slope CD4 Nanuq Pad 1 1. „., CD4 -213 CD4 -213 p 4. CD4- 213wp07 - 1 i :} � Sperry Drilling Services A, Clearance Summary p Anticollision Report ” ` % 14 June, 2011 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD4 Nanuq Pad - CD4 -213 - CD4 -213 - CD4- 213wp07 a . ': Well Coordinates: 5,957,217.19 N, 1,517,974.60 E (70° 17' 31.19" N, 150° 59' 28.81" W) Datum Height: Plan: 36.3 +19.9 @ 56.20ft (Doyon 19) -t Scan Range: 8,264.56 to 14,520.43 ft. Measured Depth. • .; ``- '& Scan Radius is 1,648.41 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited i Geodetic Scale Factor Applied Version: 2003.16 Build: 69 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference ` ,: Scan Type: 25.00 4, HALLIBURT ®N Sperry Grilling Services ConocoPhillips(Alaska) Inc. -WNS HALLIBURTQN Western North Slope Anticollision Report for CD4 -213 - CD4- 213wp07 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD4 Nanuq Pad - CD4 -213 - CD4 -213 - CD4- 213wp07 Scan Range: 8,264.56 to 14,520.43 ft. Measured Depth. Scan Radius is 1,648.41 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft CD2 Alpine Pad CD2 -37 - CD2 -37 - CD2 -37 14,236.19 1,256.15 14,236.19 1,074.19 17,085.00 6.903 Clearance Factor Pass - Major Risk CD4 Nanuq Pad • CD4 -16 - CD4 -16 - CD4 -16 11,343.89 1,310.93 11,343.89 1,194.40 7,450.00 11.249 Centre Distance Pass - Major Risk CD4 -16 - CD4 -16 - CD4 -16 11,350.54 1,311.24 11,350.54 1,194.00 7,475.00 11.185 Clearance Factor Pass - Major Risk CD4 -210 - CD4 -210 - CD4 -210 9,976.26 1,472.44 9,976.26 1,370.15 7,450.00 14.395 Centre Distance Pass - Major Risk CD4 -210 - CD4 -210 - CD4 -210 14,212.43 1,485.37 14,212.43 1,285.01 11,690.40 7.413 Clearance Factor Pass - Major Risk CD4 -210 - Plan: CD4 -210A - CD4- 210Awp13 8,270.69 830.98 8,270.69 724.92 7,925.00 7.835 Clearance Factor Pass - Major Risk CD4 -211 - CD4 -211 - CD4 -211 9,293.44 1,214.50 9,293.44 1,120.94 7,100.00 12.981 Centre Distance Pass - Major Risk CD4 -211 - CD4 -211 - CD4 -211 9,270.78 1,214.57 9,270.78 1,120.74 7,125.00 12.945 Clearance Factor Pass - Major Risk CD4 -213 - CD4 -213 - CD4 -213 8,304.55 0.4141 1,304.551 -1.39 8,305.00 0.000 Clearance Factor FAIL - Major Risk CD4 -214 - CD4 -214 - CD4 -214 8,278.02 253.68 8,278.02 147.58 7,650.00 2.391 Clearance Factor Pass - Major Risk CD4 -215 - CD4 -215 - CD4 -215 9,213.50 1,230.77 9,213.50 1,128.51 7,225.00 12.035 Centre Distance Pass - Major Risk CD4 -215 - CD4 -215 - CD4 -215 9,203.92 1,230.89 9,203.92 1,128.41 7,250.00 12.011 Clearance Factor Pass - Major Risk CD4 -23 - CD4 -23 - CD4 -23 8,935.47 956.93 8,935.47 867.57 7,125.00 10.708 Clearance Factor Pass - Major Risk CD4 -23 - CD4 -23PB1 - CD4 -23PB1 8,763.09 928.97 8,763.09 836.08 7,200.00 10.001 Clearance Factor Pass - Major Risk CD4 -23 - CD4 -23PB2 - CD4 -23PB2 8,935.47 956.93 8,935.47 867.57 7,125.00 10.708 Clearance Factor Pass - Major Risk CD4 -306 - CD4 -306 - CD4 -306 14,054.67 377.17 14,054.67 189.78 9,000.00 2.013 Clearance Factor Pass - Major Risk CD4 -306 - CD4 -306 - CD4 -306 14,083.15 374.63 14,083.15 193.84 9,050.00 2.072 Centre Distance Pass - Major Risk CD4 -319 - CD4 -319 - CD4 -319 12,659.00 1,318.29 12,659.00 1,167.47 18,683.23 8.741 Clearance Factor Pass - Major Risk Nanuq 3 - Nanuq 3 - Nanuq 3 11,116.56 244.23 11,116.56 84.42 7,475.00 1.528 Clearance Factor Pass - Major Risk 14 June, 2011 - 17:09 Page 2 of 5 COMPASS ConocoPhillips(Alaska) Inc. -WNS HALLIBURT ®N Western North Slope Anticollision Report for CD4 -213 - CD4- 213wp07 Survey tool program From To Survey /Plan Survey Tool (ft) (ft) 69.55 529.55 CB- GYRO -SS 568.01 8,264.56 MW D +I FR -AK- CAZ-SC 8,264.56 14,520.43 CD4- 213wp07 MWD +IFR- AK- CAZ -SC Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. • Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. • 14 June, 2011 - 17:09 Page 3 of 5 COMPASS SECTION DETAILS -ili 3A. ; , GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference sz v CD4- 213wp07 sec MD Inc Azi 7V0 .WS nEJ -W DLeg TFaca VS Target 1 8264.56 8509 336 30 619722 - 2677 57 - 2813.11 000 000 155395 8264.56 To 14520.43 Ellipsoid Color 2 849290 8509 33630 8211.8 -2 69.95 - 2906.90 0.00 -25.93 - 1320.77 4 9064.53 88.30 334.74 6228.74 - 1953.20 -3150.72 0.00 0.00 - 757.80 0 P600 5 914529 8977 33407 623010 - 1880.38 -3185.60 2.00 -24.41 67744 CD4-213 14Jun11 T1 ceps 5.9 0•50 To surve,ao 1m 0 - 8200 8400 8450 8650 8750 9150 9400 10650 11150 6 9145.76 89.77 334.07 6230.10 - 1879.95 -3185.80 1.00 178.43 678.97 56 vP.ss coFZ1 zwW�lcw.3lzglr0(c04z1s1 cacv6oss _. 7 9707.69 89.77 334.07 6232.41 - 1374.58 -3431.49 0.00 0.00 - 118.04 ill 40055 1atM�z co4z 462045 0 000 150/1001 lz) N9D.sR ccw .Prs +wuzsc .w.tu 8200 8250 8450 —" 8500 8750 8850 9400 9650 11150 11650 8 9731.18 9000 334.07 6232 6 - 1353.46 -3441.76 1.00 -1.57 -9469 CD4- 213 14Jun11 T2 05 w.54 8250 8300 8500 — 8550 8850 8950 9650 9900 11650 12650 9 978507 9054 334.07 622263 8350 8550 8 300 8600 8950 9050 9900 10150 12650 13650 -1304 82 -346533 1.00 -0.00 6.27 — _ "'- -" — — - 10 10164.47 90.54 334.07 6228.38 -- 913.35 3651.8.00 0.00 336.27 CASING DEWS 11 1 10218.38 9000 33407 622836 -91535 - 3654.81 1 1.00 17930 389.87 C04- 21314JUn11 73 8350 8400 8600 8650 9050 9150 10150 10650 13650 — 14650 12 10248.10 89.70 33407 62266 -88860 - 366711 100 -18000 419.45 13 1110666 89.70 33407 623123 -60 73 4070.35 000 0.00 1335.07 14 11197.22 89.99 334.07 6233.31 -35.05 -4082.84 1.00 0.01 1363.47 C04- 21314J4n11 74 6198.14 15520.. s1m.c 1. 3.1/2 15 1119722 89.99 33407 823131 -35.05 .4082.84 1.00 D00 1363.47 16 1193210 8919 33407 62316 626.48 - 4404.49 0.00 000 2095.12 17 11934.04 90.00 334.07 6233.6 62759 -4405.03 1.00 -16.51 2096.35 CD4-213 14Jun11 T5 LEGEND 18 1200855 90.75 33407 623298 694.59 4437.62 1.00 0.01 2170.46 19 1244466 90 75 334 07 622728 1086.76 4628.33 000 000 2604.20 20 12492.56 91 22 33406 62266 112183 464128 1.00 -0.19 2651.84 054213 14Jun11 T6 r4 004210, Plan: 004 -2104, CD4 - 21069911 VO 21 12498.05 91.28 334.06 6226.34 1134.76 4651.68 1.00 - 0.01 2657.30 22 13118.38 9128 334.06 6212.49 1692.48 4922.92 0.00 0.00 327415 I CD237, 00237, 00237 V17 23 13206.77 9040 33406 6211 20 1771 -0961.57 1.00 179.99 3362.05 004- 21314J4n11 17 - -1E CD4-05, CD405, 004 -06 VO 24 13207.82 90.38 334.06 6211.19 1772.90 4962.03 1.00 - 179.98 3363.09 I CD4-0], 004 -0], CD4-07 V1 25 13866.54 90.38 334 06 6206.77 2365.26 5250.12 0.00 000 4018.27 26 13904.83 90.77 33406 620619 239170 526656 1.00 002 405636 CD4-213 14Jun11 TB 6 CD4-12, CD412, CD4 -12 VO 27 14520.43 90.77 334.06 6198.14 2953.25 -5536.07 0.00 0.00 4668.60 0134 -213 14Jun11 T9 -3- CD4 -12, C04- 12PB1, C134 -12PB1 VO 0 / 360 I 004-12, Nanuq 5, Banta) 5 VI 0 / 360 • 200 0 CD4 -16, 004 -16, 004 -16 V2 50 -30 / 330 30 a< CD417, C0417, CD4 -17 V13 -30 / 330 30 t, CD4 -208, CD4 -208, C04-208 V7 Y( CD4-208, CD4-208PB1, C04-208PB1 V6 ' D CD4 -208, Rig: CD4 -208A, CD4 - 20840922 VO C04-208, Rig: CD4-208A, Rig 004-2084 VO / �' 014208 TOM: CD4208APB1, TOM CD4- 208APB1 VO ' , _} CD4 -209, CD4 -209, CD4 -209 V4 -60 / 300 '*4, LASpii 10o 60 ] 054210, CD4 -210, CD4 -210 V3 -60 / 300 25 60 �) 1 I 054- 210, Plan' 814 -2106, CD4 - 21060813 V0 D CD4211, 004 -211, 004-211 V2 I • 004-215 014215 CD4 -215 V4 ( ] C04-214, CD4 -214, C134-214 V3 D4 -21 -$- C04-23, CD4 -23, CD4 -23 VO )( CD423 CD423781 GD423781 VO CD4 -21 -90 / 270 •'� 90 I CD4 -23, C0423PB2, CD4 -23PB2 VO -90 / 270 90 ♦ 1,•1 ] 004 -24, 004-24. C0 -2 VO r 4 004 -24, CD424P81, Bi, CD44PB1 VO I 00424, 00424PB2, CD424PB2 VO � ,1 , A A CD4 -25. C0425. CD4 -25 VO 1( . / ' 1 / CD425, C0425L1, CD425L1 V0 • • I CD425, CD4- 25P81, C0425PB1 VO ® P CD4 -26, CD4 -26, 004 -26 V0 -120 / 240 �����/ t1 / 120 - 004-302, 804302, 004302 V3 ' 11 --3- CD4 -120 / 240 120 304, CD4-304, 814-304 CD4 -301, CD4304PB1, C134-304P1C134-304P131 V16 ' I - 004-306, CD4, 01438, 01438 V1 • 1 0143188, 0043118, 0143118 V6 054318, 0143184, 0143184 V5 150 / 210 "; 150 - D 304318, CD4318P81, CD4-310P61 V3 CD4-319, C134 -319, 004319 V5 -150 / 210 150 20r -3- 004 -320, 004320, C04320 V7 50 D CD4320 CD4320P81, C04-320P131 V4 -180 / 180 -180 / 180 � - C04.321, CD4321, CD4321 V16 O 014322, 004322, CD4 -322 V8 O Nanuq 3, Nanuq 3, Nanuq 3 01 4( Plan: C04 -01 Plan CD4-03, C04 -035802 VO ] Plan: CD4 -27, Plan CD4 -27, GD4- 279903 V0 • • I Nanuk 2, Nanuk 2, Nanuk 2 V1 -]- 0142135807 • Travelling Cylinder Azimuth (TFO +AZI) [1 vs Centre to Centre Separation [100 ft/in] Travelling Cylinder Azimuth (TFO+AZI) [ vs Centre to Centre Separation [25 ft/in] • HALLIBURTON ConOCOPh CD4- 213wp07 Alaska Sperry Drilling ANTI - COLLISION SETTINGS 17:08, June 14 2011 Interpolation Method: MD, interval: 25.00 Depth Range From: 8264.56 To 14520.43 Results Limited By: Centre Distance: 1648.41 GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey /Plan Tool 69.55 529.55 CD4 -213 gyro (CD4 -213) CB- GYRO -SS 568.01 8264.56 CD4 -213 (CD4 -213) MWD +IFR- AK- CAZ -SC 8264.56 14520.43 CD4- 213wp07 (CD4 -213) MWD +IFR- AK- CAZ -SC CASING DETAILS TVD MD Name Size 2388.49 2712.67 9 -5/8" x 12 -1/4" 9 -5/8 6197.22 8264.56 7" x 8 -3/4" 7 6198.14 14520.43 3 -1/2" x 6 -1/8" 3 -1/2 0 60 02 m a cn C U 0 30 N c 02 U - V 1 I I 1 1 1 I 1 I I 9000 9900 10800 11700 12600 13500 14400 Measured Depth LEGEND CD4 -210, Plan CD4 -210A, CD4- 210Awp11 VO -- CD4 -210, Plan: CD4 -210A, CD4- 210Awp13 VO -9- CD4 -304, CD4 -304, CD4 -304 V6 - CD2 -37, CD2-37, CD2-37 V17 -0- CD4 -211, CD4 -211, CD4 -211 V2 -e- CD4 -304, CD4- 304PB1, CD4- 304PB1 V16 - CD4-05, CD4 -05, CD4 -05 VO -A- CD4 -213, CD4 -213, CD4 -213 V4 -- CD4 -306, C04306, CD4306 V1 CD4 -07, CD4-07, CD4-07 V1 -e- CD4 -214, CD4 -214, CD4 -214 V3 --X- CD4 -318, CD4 -318, CD4-318 V6 --A-- CD4 -12, CD4 -12, CD4 -12 VO CD4 -215, CD4 -215, CD4 -215 V4 -A- CD4 -318, CD4 -318A, CD4 -318A V5 - 9- CD4 -12, CD4- 12PB1, CD4 -12PB1 VO -8- CD4 -23, CD4-23, CD4 -23 VO --- CD4 -318, CD4- 318PB1, CD4-318PB1 V3 ---1- CD4 -12, Nanuq 5, Nanuq 5 V1 CD4 -23, CD4- 23P81, CD4 -23PB1 VO -0- CD4 -319, CD4 -319, CD4 -319 V5 $ - CD4 -16, CD4 -16, CD4 -16 V2 -e- CD4 -23, CD4- 23PB2, CD4-23PB2 VO -- CD4-320, CD4 -320, CD4 -320 V7 -6- CD4 -17, CD4 -17, CD4-17 V13 -- CD4 -24, CD4 -24, CD4-24 VO -9- CD4 -320, CD4- 320PB1, CD4- 320PB1 V4 --- CD4 -208, CD4 -208, CD4 -208 V7 CD4 -24, CD4-24PB1, CD4 -24PB1 VO -0-- CD4 -321, CD4 -321, CD4 -321 V16 - X - CD4 -208, CD4- 208PB1, CD4-208PB1 V6 -9- CD4 -24, CD4 - 24PB2, CD4 -24PB2 V0 - CD4 -322, CD4 -322, CD4 -322 V8 --Q- CD4 -208, Rig: CD4 -208A, CD4- 208Awp22 VO -0- CD4 -25, CD4 -25, CD4 -25 VO -A- Nanuq 3, Nanuq 3, Nanuq 3 V1 - CD4-208, Rig: CD4-208A, R g CD4-208A V0 $- CD4 -25, CD4 -25L1, CD4 -25L1 VO -X- Plan: CD4 -03, Plan: CD4 -03, CD4- 03wp02 VO - CD4 -208, TD'd: CD4- 208APB1, TD'd CD4-208APB1 VO - X - CD4 -25, CD4- 25PB1, CD4 -25PB1 VO -6- Plan: CD4 -27, Plan: CD4 -27, CD4- 27wp03 VO - CD4 -209, CD4 -209, CD4 -209 V4 - CD4-26, CD4 -26, CD4 -26 VO $- Nanuk 2, Nanuk 2, Nanuk 2 V1 9 CD4 -210, CD4 -210, CD4-210 V3 -0- CD4 -302, CD4 -302, C04 -302 V3 -{ - CD4- 213wp07 Easting (5000 ft/in) I I II ii i i Iii i Im i I i i i I II I II III I I ImilIII I II I I I IIIII Imill m Iiiii Iim IiiII IIIII I il m i ll — 17:12, June 14 2011 — - CD4 -07 C►4 16 • CD4- 213wpt CD2 -37 CD4 -208 - CD D4- 7 pp4- 208PB1 CD' z1 0 S— CD4- . — Z CD 3 0 1 21- 06 _ A. o _ - '' CD4 -319 \ � - 3 o _ _ i ��� � CD4- 320P B1 —ea _ CD 318A : =r CD4-302 o Z - p 4 -2� CD4 4 A� � -.41 .4 CDL1 / � i `'�I,i' 94-321 / �' `� � � CD4 -320 - - CD4 -' a; /�``,! PB2 T, fi CD4 -208A anuq 5 - t o , 21. CD4- D4 -214 • 0,' =1 ?PB1 - _ CD4- 208Awp22 — ConocoPhillips(Alaska) Inc. -WNS Western North Slope - CD4 - wp03 CD4- 03wp02 _ CD4 Nanuq Pad CD4- 210Awp11 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I Easting (5000 ft/in) GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference SECTION DETAILS CD4- 213wp07 Sec MD Inc Azi TVD ON/ -S OE/ -W DLeg TFace 1/Sec Target 1 8264.56 85.09 336.30 619722 - 2677.57 - 2813.11 0.00 0.00 - 1553 95 8264.56 To 8501.00 Ellipsoid Color 3 8492.90 88.30 334.74 6211.8 - 2469.95 -2833.13 2906.90 2.00 -25.93 - 1326.77 4 906413 88.30 334.74 6228.74 - 1953.20 -3150.72 0.00 0.00 - 757.80 suavEY PMOMIN 5 9145.29 89.77 33407 6230.10 - 1880.38 -3185.60 2.00 -24.41 -677.44 CD4-213 14Jun11 Ti on own, ro arvw Tod 0 8200 8400 8450 8650 8750 9150 9400 10650 11150 6 9145.76 89.77 334.07 6230.10 - 1879.95 -3185.80 1.00 178.43 -676.97 69.56 5280 (cce.e,9 7 9707.69 89.77 334.07 6232.41 " 1374.58 -3431.49 0.00 0.00 - 118.04 568 01 8260 56 s13 10660 6 0213) 8200 8250 8450 8500 8750 8850 9400 9650 11150 11650 8262.66 1462043 c�21360071004,131 6001602.00505 8 9731.18 9600 334.07 623245 - 1353.46 -3441.76 94. 441.76 1.00 - 1.57 -9469 004- 27314Jun11 T2 8250 8300 8500 - -- - ---- 8550 8850 8950 9650 9900 11650 12650 9 9785.07 90.54 334.07 623220 - 1304.99 -346513 100 -0.02 -41.08 8 300 • 8350 8550 " " - " "- 8600 8950 9050 9900 - 10150 12650 '" " " "" -- " " " " -' 13650 10 10164.47 90.54 334.07 6228.63 - 963.82 -3631.24 0.00 0.00 336 27 uisu, Dares 11 10218.36 9000 33407 6228 38 91515 - 385401 1.00 179.70 38087 CD4 -213 14Jun11 T3 TVO MD Herne S. 8350 8400 8600 8650 9050 ' - --- 9150 10150 10650 13650 14650 12 10248.10 89.70 33407 622846 -888.60 - 3667.81 1.00 - 180.00 41945 266006 2712 67 4560,12.1,11 9 13 11168.66 89.70 33407 623123 -6673 -4070.35 000 000 1335.07 618 826056 r 6.6 7' 619814 14620 ai 11,2 6000 112 14 11197.22 89.99 334.07 6233.31 35.05 -4082.84 1.00 0.01 1363.47 CD4-213 14Jun11 T4 15 11197.22 89.99 334 07 623311 - 35.05 -4082.84 1.00 000 1363.47 16 11932.80 89.99 334.07 6233.46 626.48 -4404.49 000 000 209512 17 11934.04 90.00 334.07 6233.46 627.59 -4405.03 1.00 -18.51 2098.35 CD4-213 14Jun11 T5 LEGEND 18 12008.55 90 75 334.07 6232 98 694.59 -4437.62 1.00 0.01 2170 46 19 12444.66 90.75 334 07 6227 28 108636 -4628.33 000 000 2604 20 20 12492.56 91.22 334.06 622646 112903 -4649.28 1.00 -0.19 2651.84 C04 -213 14Jun11 76 CD4 -210, Plan. CD4 -210A, CD0.21OAvg11 VO 21 12498.05 91.28 334.06 6226.34 1134.76 4651.68 1.00 - 0.01 2657.30 22 13118.38 91 28 334.06 6212.49 1692.48 -4922 92 0.00 0.00 327415 I CD237, 002 -37, 002 -37 V17 23 13206.77 90 40 334 06 6211 20 1771.96 -4961.57 1.00 17909 3362.05 004 -213 14Jun11 77 K CD4-05, 004-05, C04 -05 VO 24 13207.82 90.38 334.06 6211.19 1772.90 -4962.03 1.00 - 179.98 3383.09 I 0040], 004 -07, CD4-07 1/1 25 13866.54 90 38 33406 6206.77 2365.26 5250.12 0.00 0.00 401827 26 13904.83 90.77 33406 620639 2399.70 5266.86 1.00 0.02 4056.36 CD4-213 14Jun11 T8 CD4 -12, C04 -12, 004 -12 VO 27 14520.43 90.77 334.06 8198.14 2953.25 5536.07 0.00 0.00 4668.60 004 -213 14Jun11 T9 • -9- CD4 -12, 004-12781, C0412PB1 VO 0 / 360 I C0412, Nanuq 5, Nanuq 5 V1 0 / 360 200 0 CD4 -16, 004-16, 004-16 V2 50 -30 / 330 30 K CD4 -17, CD4 -17, CD4 -17 V13 -30 / 330 30 004 -208, 004-208, 0134 -208 V7 K C04-208, C04-208P81, 004-208781 V6 - e- 004 -208, Rig: CD4 -208A, CD4- 208Aep22 VO 0 CD4-208, Rig: CD4-208A, Rig CD4 -208A V0 • 1 4' I 004208, TDd: C04208AP81, TD'A C04- 208APB1 VO - 9- CD4 -209, CD4 -209, CD4 -209 V4 -60 / 300 1 Q 1 60 -60/ 300 25 60 4 �- 004 -210, 000.210, 004210 V3 I 004-210, Plan. CD4 -210A, C04-210Aup13 VO -9 C04-211, C04 -211, 004-211 V2 A C04-213, 004-213, 004-213 V4 - 3- 004-214, C134-214, C0 -214 V3 004-215, C04-215, 0134-215 V4 D4 -21 CD423, 00423, 00423 VO C04_21 K 004-23, CD4-23P81, CD4 -23P81 VO -90 / 270 90 I C04-23, C04-23P82, C04-23P82 VO -90 / 270 90 - 2 CD4-24, 004-24, CD4 -24 V0 A 004 -24, 004-24781, 0D4-24P81 50 I 004-24, 004-24PB2, CD4-24P82 50 6, C04-25, C11425, C01 -25 VO K CD4-25, CD4-25L1, CD4-25L1 VO I C04-25, CD4-25P81, CD4 -25PB1 VO A 004 -26, CD4 -26, CD4 -26 V0 1 1 0 004302, 004-302, C04 -302 V3 gillir 120 / 240 120 -9- CD4 -304, 004-304, 004304 56 120 1 240 120 D C04 -304, C04-304P81, CD4304P81516 I 004-306, 0D4306, 004 -306 V1 • I 004318, 004318, 004318 V6 C134 -318, CD4 -318A, CD4318A V5 -150 / 210 150 D 004 -318, C04-318P131, C04318P81 V3 3 004-319, 004319, CD4319 V5 -150/210 150 200 -3 CD4 -320, CD4-320, C134320 V7 1 -180 / 180 D 004320, CD4-320P81, CD4 - 320761 54 -180 / 180 �- C04321, 004 -321, 004321 V16 O 004 -322, 004-322, 004322 V8 0 Nanuq 3, Nanuq 3, Nanuq 3 V1 K Plan: CD4 -03, Plan' CD4.03, CD4 -038602 V0 - Plan: CD4 -27, Plan: 00427, CD4 - 2784,03 V0 I Nanuk 2, Nanuk 2, Nanuk 2 51 - CD42138p07 Travelling Cylinder Azimuth (TFO +AZI) [1 vs Centre to Centre Separation [100 ft/in] Travelling Cylinder Azimuth (TFO+AZI) [ vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference SECTION DETAILS CD4- 213wp07 Sec MD Inc Azl TVD 01 +E/ -W Oleg TFace VS c Target 1 826456 85.09 336.30 6197 22 - 2677.57 - 281111 000 000 1553 95 2 831456 8E09 33630 8500.00 To 11001.00 EIGpsOd COOT 3 849290 88.30 33474 6 -2469.95 - 2 2906.90 2.00 -25.93 - 132677 4 906453 88.30 334.74 6228.74 - 1953.20 -3150.72 0.00 0.00 - 75730 SURVEY N10CJrM 5 9145.29 89.77 33407 623010 - 1880.38 -3185.60 200 -24.41 -67744 C04- 21314Jan11 T1 rv� o µn ro aw.yy mi.� e. 0 8200 8400 8450 8650 8750 9150 9400 10650 11150 8 9145.76 89.77 334.07 623010 - 1879.95 -3185.80 1.00 178.43 -676.97 0epn 00.19 529.5510.410 400-05 r" -1353.48 9707.69 69.77 334.07 6232.41 - 1374.58 3031.49 0.00 0.00 -118.04 Al i ersax 60+7.0 (c04zial nrvm.on ccozsc 6200 8250 8450 8500 8750 - -- -- - 8850 9400 9650 11150 11650 8 9731.18 90.00 33407 8232.6 - 1353.48 344176 1.00 -1.57 -94.89 CD4- 21314Jun11 12 u5a 19 wu0.00 cw -2n.pm lcwa�a) .......,,,,z_. 8250 8300 8500 8550 8850 8950 9650 9900 11650 12650 9 978507 9054 334 07 623220 - 130499 -348533 1.00 -0.02 -41_08 q PFD.S 8300 8350 8550 ' -" - - "- ' - 8600 8950 9050 9900 " - -- '__ "' 10150 12650 - - _ -'" 13650 11 0218.36 9000 33407 6228.38 -915 35 -3631.24 0.00 0.00 336.27 -3654 81 1.00 17970 38987 004 -213 14JUn11 T3 8350 8400 8600 8650 9050 9150 10150 10650 13650 _ -- 14650 12 0248.10 8970 33407 6228.46 -88860 3667.81 1.00 - 180.00 419.45 13 1188.88 89.70 334 07 623323 -60.8 4070.35 000 000 1335.07 810e.14 14520 43 31m.61rt s12 14 119722 89.99 334.07 623131 -35.05 -4082.84 1.00 0.01 1363.47 C04- 21314Jan11 T4 15 119722 89.99 33407 6233.31 3505 4082.84 1.00 0.00 1363.47 16 1932.80 8999 33407 62316 62648 4404.49 0.00 0.00 2095.12 17 1934.04 9000 334.07 6233.6 627.59 -4405.03 1.00 -16.51 2098.35 C54 -213 14Jan11 T5 LEGEND 18 2008.55 90/5 334 07 6232.98 694 59 4437.62 1.00 0.01 2170.46 19 2444.66 90.75 33407 622728 1086.76 -4628.33 0.00 000 260420 AA 20 2492.56 91 22 334.06 6226.6 1129.83 4649 28 1.00 -0 19 2651.84 CD4 -213 1415011 TO LO CD4 -210, Plan: CD4-2108, 004- 210014911 VO 21 2498.05 91.28 334.06 8226.34 1134.76 -4651.68 1.00 -0.01 2657.30 22 3118.38 91 28 33406 6212.49 1692.48 4922.92 0.00 0.00 3274 15 I 60237, 60237, CO2 -37 V17 23 320637 90.40 334 06 621120 1771.96 -0961.57 1.00 17919 336205 004 -213 1430n11 17 K C04 604415, C04 -05 V0 24 3207.82 90.38 33406 6211.19 1772.90 -4962.03 1.00 - 179.98 3363.09 I CD4-07, CD4 -07, CD4-07 V1 25 3866.54 90 38 33406 6206 77 2365.26 -5250.12 0.00 0.00 4018 27 26 3904.83 90.77 33406 620639 239870 5266.86 1.00 002 4056.36 C04 - 2131411011 TO A C04 -12, CD4 -12, 004 -12 VO 27 4520.43 90.77 334.06 619814 295125 -5538.07 0.00 000 4668.60 004 -213 14Jun11 79 • -3- C04-12, C04- 12PB1, CD4 -12PB1 VO 0 / 360 I C04 -12, Nanuq 5, Nanuq 5 V1 0 / 360 200 C04 -16, CD4 -16, CD4 -16 V2 50 -30 / 330 30 0 604 -17, 604 -17, 6D4 -17 913 -30 / 330 - 30 (, 004208, 604 -208, C04 -208 V7 !( 004-208, 654- 208961, 004-208961 06 D CD4 -208, Rig: C04-208A, 604- 208Ax922 VO O CD4 -208, Rig: CD4 -2080, Rig CD4 -208A V0 I 004-208, TOE: C04-208AP81. TO'E CD4- 208AP81 VO 60 / 300 - 3- 604 -209, C04-209, CD4-209 V4 lo. 60 �- 604 -210, CD4 -210, C04 -210 V3 -60 / 300 60 I CD4 -21o, Plan: C04 -210A, CD4- 210Ax913 VO D CD4- 211. 604 -211, 004-211 V2 A 004-213, 004 -213, 004-213 V4 • C04-214, C04 -214, 604 -214 V3 1 .41. F 111 A CD4-215, C04-215. 604-215 V4 A CD4-23, CD4 -23, C04 -23 VO !( 004-23, CD4- 23P81, CD4 -23PB1 VO -90 / 270 90 I 004-23, CD4- 23P82, CD4 -23PB2 0 -90 / 270 90 - 3 C04-24, C04-24, CD4 -24 VO A 604 -24, 004-24981, C04-24P81 VO I 604 -24, C04- 24982. 6134-249132 VO 604-25, 004 -25, C04-25 V0 09< 004-26, CD4 -25L1, 004-2511 90 I CD4 -25, CD4- 25PB1, CD4 -25781 VO A C04 -26, C04 -26, C04 -26 VO O 600302.604352, 604 -302 83 -120 / 240 120 ] C04 -304, 604354, C04 -304 vs -120 / 240 120 -9- 004304, 654-304981, 604- 304981 V16 I CD4318, C04318, C04-3 01 • I 004318, 004318, 004318 19 VB -9- 004-318, 0043180, 604-318005 -150 / 21 O 150 CD4318, C54- 318981, 004318981 V3 C04 -319, 004319, 004319 V5 -150 / 210 150 2O 1 D CD4 -320, 004320, CD4 -320 V7 50 -180 / 180 D 601 -320, C04- 320981 CD4- 320P81 V4 -180 / 180 3 010^ 321, 004321, 004321 016 CD4 -322, C04 -322, 004322 V8 J Nanuq 3, Nanuq 3, Nanuq 3 V1 !( Plan' CD4 -03, Plan: CD4-03, C04 -0394,02 VO - -3- Plan: CD4 -27, Plan: CD4 -27, CD4 - 27x903 0 I Nanuk 2, Nanuk 2, Nanuk 2 91 -9- 001- 2139p07 Travelling Cylinder Azimuth (TFO +AZI) [1 vs Centre to Centre Separation [100 ft/in] Travelling Cylinder Azimuth (TFO+AZI) [ °] vs Centre to Centre Separation [25 ft/in] •IIA SECTION DETAILS ar ,/ GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference " = __ . - CD4- 213wp07 Sec MD Inc An 510 •N/ -S •EI -W DLeg TFace VSec Target 1 8264 56 85.09 336.30 6197.22 - 2677.57 - 2813 11 000 0.00 1553 95 2 8314 56 85 09 336 30 11000.00 To 12001.00 Ellipsoid Color 3 8492.90 88.30 334.74 6211.78 - 2469.95 - 2906.90 2.00 -25.93 - 1326.77 4 9064.53 88.30 334.74 6228.74 - 1953.20 -3150.72 0.00 0.00 - 757.80 SURVEY Rtac1708 5 914529 89.77 334.07 6230.10 - 1880.38 -3185.60 200 - 24.41 - 677.44 CD4- 213 14Jun11 T1 rod F,e„ ze ro w - 0 8 200 8400 8450 8650 8750 9150 9400 10650 11150 6 9145.76 89.77 33407 6230.10 - 1879.95 -3185.80 1.00 178.43 576.97 0, ce.cc 5s5 c g4 1nw.0(002u1 ca0va0a5 89.77 4 - _ aeu 58 c0.a FIc 7 9707.69 89. 334.07 6232.41 - 1374.58 -3431.49 0.00 0.00 - 116.04 6"276 X u cw -E500r l 1 � �. - z�a1 .� 8200 8250 8450 8500 8750 8850 9400 9650 11150 11650 -_ 8 9731.18 90 00 334.07 6232.45 - 1353.46 3441.78 1.00 -1.57 -94.69 004 -213 14Jun11 72 enln.aRa4ccx sc 8250 8300 8500 - - --- 8550 8850 8950 9650 9900 11650 12650 9 978507 9754 33407 8232 - 1304.99 3465.33 170 - 0.02 -41.08 8300 -- " -' - -" 8350 8550 _'_ "_'_ "___ -_- 8600 8950 9050 9900 �_` 10150 12650 - "'- " "' - - "" 13650 10 0164.47 90.54 334.07 6228.63 -963.82 3631.24 0.00 0.00 338.27 .6440 DUALS 11 0218.36 90.00 33407 6228.38 915.35 3654.81 1.00 179.70 389.87 CD4 -213 14Jan11 T3 so IAD Nemo Sin 8350 8400 8600 8650 9050 9150 10150 10650 13650 14650 12 0248.10 89.70 33407 6228.46 -88860 366781 1.00 - 180.00 41945 2366 MP 2712 57 9 45/8 13 1168.66 89.70 334-07 6233.23 -60.73 -4070.35 0.00 0.00 133577 6198 14820.0 3.1/2.54e svz 14 1197.22 89.99 334.07 6233.31 -35.05 -4082.84 1.00 0.01 1363.47 C04 -213 14Jan11 T4 15 119722 89.99 33407 6233.31 -35.05 -4082.84 1.00 0.00 136347 16 1932.80 8999 33407 6233.46 62648 -4404.49 700 700 2095.12 17 1934.04 9000 334.07 6233.46 627.59 -4405.03 1.00 -16.51 2096.35 CD4-213 14Jun11 TO LEGEND 18 2008.55 9075 33407 623298 694.59 4437.62 1.00 701 217046 19 2444.66 9075 33407 6227.28 1086.76 -4626.33 000 000 2604.20 20 2492.56 91.22 33406 622646 1129.83 -464928 1.00 -0 .19 265184 CD4- 213 14Jun11 TO 004 -210, Plan: 0042104, 034 - 21048911 VO 21 2498.05 91.28 334.06 6226.34 1134.76 4651.68 1.00 -0.01 2657.30 22 3118.38 91.28 334.06 621749 1692.48 -4922 92 0.00 0.00 327415 I CD2 -37, 002 -37, CD2 -37 V17 23 3206.77 90.40 334 06 6211 20 1771.96 -4961.57 1.00 179.99 3362.05 004 -213 14Jan11 T7 - CD4-05, CD4-05 VO 24 3207.82 90.38 334.06 6211.19 1772.90 4962.03 1.00 - 179.98 3363.09 I 004-07, 004-01, 004-07 Vi 25 3866.54 90.38 334.06 6206.77 2365.26 -5250.12 0.00 0.00 4018.27 26 3904.83 90.77 33406 6206.39 2399.70 5266.86 1.00 0.02 4056.36 CD4-213 14Jun11 TO A CD4-12, 004 -12, C04-12 VO 27 4520.43 9777 334.06 6198.14 2953.25 -5536.07 0.00 0.00 4668.60 004213 14Jan11 79 _} CD4-12, C04- 12781, C0412P/31 VO 0 / 360 I 00412, Nanuq 5, Nanuq 5 V1 0 / 360 • 200 0 C04-16, C04 -16, C04 -16 V2 50 -30 / 330 30 x CD4 -17, C04 -17, CD4 -17 V13 -30 / 330 30 6 004 -208, 004 -208, 004 -208 V7 K 034 -208, C04-208P81, C54.208P01 V6 - 9 - 004 -208, Rig: CD4 -2084, CD4- 208Aw922 VO 0 CD4 -208, Rig: 0042085, Rig 004 -2068 V0 I CD4 -208, TD'4: 004-20847131. TD'4 0042084761 V0 -60 / 3 0 0 A ♦ 60 4i 6 -D C04 -209, CD4z09, CD4-209 V4 ♦ 10 60 IW 7 - 004 -210, Plan x10, 0 -60 / 300 60 I 004-21, Plan: 10A, C D4- 4210Awy13 VO � { D 4 -11 CD4z11, n, CD4- CD/ -2 11 0013, 5, CD4 -213, 00422 V4 13 V4 ��♦ 00422 CD4 -23, CD4 -23, CD4-215, C04 -215, C04-215 V4 . ♦, Q CD4-215. 04-235 V4 C D4-23 -23 0 V0 r . ∎ ∎AFA CD4 -23. CD4 - 23781. 00423781 VO -90 / 278 8888 - ' . 9 0 I C04-23, 53423782, 00423782 VO -90 / 27 0 90 m ii 1 1 11 _ _', -3- 004-24, 03424, CD4 -24 VO ,'( 1 CD4 -24, CD4- 24P81, CD4-24P81 VS ♦ ` I CD424, 004-24762, CD4 -24P82 V0 ® ® .�1 1 ( K 00425. C04-25. VO 1 CD4-25, CD425L1. 1. , 004- 0425L1 VO I n CD4-25, 004257131, 00425781 VO . 101 004-30, C44 - VO .'' 120 0 004302, 004302 CD43 V3 -120 / 240 �- CD4 -304, 004-304, 5 30 - 120 / 240 -� 001304, 004304781, 1. C54 54 120 004309781 Vt6 T.-A, I 004-306, C04306, 004316 V1 • ■ I CD4 -318, CD4-318, C04 -318 V6 -3- 004318, 0343184, 0043184 V5 D CD4 -318, CD4318P61, C04318PB1 03 -150 / 210 150 -3- CD4 -319, C04 -319, 004319 V5 -150 / 210 150 20f C04-320, 004320, 004320 V7 50 180 / 180 D C04 -320, CD4320P81 CD4320P91 V4 -180 / 180 - -D- C9a. -921, CD4321, CD4-321 V16 O 004-322, 004-322, CD4-322 V8 O Nanuq 3, Nanuq 7 Nanuq 3 VI K Plan CD4 -03, Plan. C04-03, CD4- 03wp02 VO ] Flee CD4 -27, Plan: C04 -27, CD4- 27wp03 VO I Nanuk 2, Nanuk 2, Nanuk 2 VI -3- CD4- 213wp07 Travelling Cylinder Azimuth (TFO +AZI) [1 vs Centre to Centre Separation [100 Win] Travelling Cylinder Azimuth (TFO+AZI) [ °] vs Centre to Centre Separation [25 ft /in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference SECTION DETAILS 17.10 4 tne;14 2049 : CD4- 213wp07 Sec MD Inc Azi TVD ON/-S OEl -W Dleg TFace VSec Target 1 8264 56 8509 336 30 6197 22 - 267787 - 2813.11 0.00 0.00 -1553.95 2 831486 8809 336.30 6201.50 -2631.95 -2833.13 0.00 12000.00 To 14001.00 Ellipsoid Color 3 849290 8630 334.74 6211.78 - 2469.95 - 2906.90 2.00 -25. - 1326.77 4 9064.53 88.30 334 74 6228.74 - 1953.20 3150.72 0.00 0.00 - 757.80 SURVEY PROM. 5 9145.29 89.77 33407 6230.10 - 1880.38 3185.60 2.00 -24.41 -677.44 C04-213 14Jun11 T1 r an ]o swan- 0 8200 8400 8450 %50 8750 9150 9400 10650 11150 6 9145.76 89.77 334.07 6230.10 - 1879.95 3185.80 1.00 178.43 576.97 cegn 55.w 14.55 004313 PPo(CD0.49I Tm ca0*R0 � Noss 08/41210 ss 7 9707.69 89.77 334.07 6232.41 - 1374.58 -3431.49 0.00 0.00 -118.04 040 w uwU.casx - c=zsc 8200 8250 8450 - - -- 8500 8750 8850 9400 9650 11150 11650 �� 04 052490 &91--.g.,07 8 9731.18 90.00 33407 6232.45 - 1353.46 -3441.76 1.00 -157 -94.69 CD4-213 14Junll 72 1 uwwcavc - 5C 8250 8300 8500 8550 8850 8950 9650 9900 11650 12650 9 0 9054 33407 623220 -1963.82 -3465.33 1.00 -000 30 .27 8 300 " - -- - -_ -_ -' 8350 8550 - "' "___" - " "'__ -" 8600 8950 9050 9900 -'" - - - - -. 10150 12650 -_ 13650 1 10164.47 90.54 334.07 6228.63 -963.82 3657.8 1 .00 9.70 389.2] rwsP�O pm., 8300 70278,36 90.00 334.0] 6228.38 - 915.35 - 3654.81 1.00 179.70 389-87 C134- 21314Jun11 TO rw on R.,. sn 8350 8400 8600 8650 9050 - 9150 10150 10650 13650 ----- - - - - -_ 14650 12 10248.10 89.70 334.07 6228.46 - 888.60 366781 1.00 -18000 419.45 13 11168.88 89.70 33407 6233.23 -6973 -407935 000 900 1335.07 519722 8284.55 7 x8 7 5190.14 14520.99 112.09re 112 14 11197,22 89.99 334.07 6233.31 35.05 4082.84 1.00 0.01 1363.47 C04-213 14Jun11 T4 15 11197 22 89.99 334.07 6233.31 35.05 -4082.84 1.00 0.00 1363.47 16 11932.80 89 99 334.07 6233.46 626.48 -4404.49 0.00 0.00 2095.12 17 11934.04 9090 334.07 6233.46 627.59 4405.03 1.00 -16.51 2096.35 C04-213 14Jun11 T5 LEGEND 18 12008.55 90.75 334.07 623298 694.59 -443782 1.00 901 217046 19 12444.66 90 75 334.07 622728 1086.76 -4628.33 900 000 2604 20 20 12492.56 91.22 33406 622646 112883 -4649.28 1.00 -0.19 2651 84 CD4-213 14Jun11 TO t8/ C04 -210, Plan: C04 -210A, 0584-21000911 50 21 12498.05 91.28 334.08 622834 1136.76 4651.68 1.00 - 0.01 2857.30 22 13118.38 91 28 334 06 6212.49 1692.48 -492292 900 000 3274 15 I CO237, CO2-37, C13237 V17 23 13206.77 90.40 33406 621120 1771.96 4961.57 1.00 179.99 3362.05 054- 21314Jun11 T7 K C04-05, CD4-05, C04-05 VO 24 13207.82 90.38 334.08 6211.19 1772.9D -4962.03 1.00 - 179.98 3363.09 I 00407, CD4 -07, 004-07 V1 25 13866.54 90 38 334 06 6206.77 236826 -5250.12 0.00 000 4018 27 26 13904.83 9977 33406 620639 2399.70 -5266.86 1.00 902 4056.36 034-213 14Jun11 TO 004 -12, C04 -12, 004 -12 VO 27 14520.43 90.77 334.06 6198.14 2953.25 5536.07 0.00 0.00 4668.60 CD4-213 14Jun11 TO • -.-2- 004-12, C04-12P81, CD4 -12PB1 VO 0 / 360 I 004-12, Nanuq 5, Nanuq 5 V7 0 / 360 200 C04-16, 00416, 004 -16 V2 50 -30 / 330 30 K co417 co417 004 -17 013 -30 / 330 30 (( 004-208, 004-208, 004-208 V7 >( 004208, CD4-206P91, C04-208P01 56 D 004-208, Rig: 004-2088. CD4- 208Awp22 VO 004-208. Rig: CD4 -2083, Rig 004-2083 V0 I 004208, TD'd: CD4-208APB1. TD'd CD4- 208APB1 VO -60 / 300 10 4 60 3 c54zo9, C04zo9. CD4 209 v4 -60 / 300 60 3 004-210, 0134210, 004 -210 53 I C04-210. Plan: CD4 -210A, CD4 - 2103158/13 VO D 004-211, 004211, C04-211 V2 6, 004-213, 004 -213, 004213 V4 -3- 004 -214, 004 -214, C04-214 V3 004-215. 004-215, C04 -215 V4 00423, 00423, 004 -23 VO K CD4 -23, CD4- 23P81, CD4-23P61 VO -90 / 270 90 I 004-23, C04-23P82, CD4 -23P82 VO -90 / 270 90 D C04-24, C04 -24, CD4 -24 VO (, 05424, 004-24P81, 004-24/81 VO I 004-24, C04- 24PB2, 004 -24162 VO 054 -25. C04 -25, 004 "25 00 K 0134 -25, 004-2511, C04-2511 VO I CD4 -25, CD4-25PB1, CD4-25PB1 VO 004 -26, 004-26, 004 -26 50 3 C04-302. 004302 054-302 V3 -120 / 240 120 2 CD4304, 004-304, 004-304 Vs -120 / 240 120 D 004 -304, C04-304P81. C04- 304PB1 516 I 004 -316, 054306, 0134308 Vi I 054378, 054318, 054318 V6 3 054318, 0043184, 054-318455 150 / 210 150 D C134-318, C04318PB1, CD4-318PB1 53 �- 054319, CD4 -319, 054 -319 v5 - 150 / 210 150 200 , -3- 004320, 004-320. 004-3205] 50 -180 / 180 -9- 004320, 054- 320181 CD4320PB1 V4 -180 / 180 3 054321, 004321. 054 -321 V16 0 4 -322. 004 -322. 004-322 V8 'J Nanuq 3, Nanuq 3, Nanuq 3 V1 !( Plan: 004 -03, Plan: 004-03.004 -030802 VO Plan: CD4 -27, Plan: C04-27, 004- 27.98/03 VO I Nanuk 2. Nanuk 2. Nanuk 2 V1 -3- C04- 2130.8/07 • Travelling Cylinder Azimuth (TFO +AZI) [1 vs Centre to Centre Separation [100 ft/in] Travelling Cylinder Azimuth (TFO+AZI) [ °] vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference SECTION DETAILS I 17:20, June 14 2011 CD4 -21 3wp07 Sec MD Inc Aai TVD .NIS +Ei -W DLeg TFace VSec Target 1 826456 85.59 33630 619722 - 267757 - 2813.11 0.00 0.00 - 155195 14000.00 To 14520.43 Ellipsoid Color 2 831456 65.09 336.30 620150 - 2631.95 - 2833.13 000 0.00 -1504.24 3 8492.90 88.30 334.74 6211.78 - 2469.95 - 2906.90 2.00 -25.93 - 1326.77 4 9064 53 88.30 334.74 6228.74 - 1953.20 -3150.72 0.00 0.00 - 757.80 SAM' PROGRAM 5 914529 89.77 33407 623010 - 1880.38 -3185.60 2.00 -24.41 -677.44 C04- 21314JUn11 T1 Depth Fan oeom>'96.940 im 0 - 8200 8400 8450 8650 8750 9150 9400 10650 11150 6 9145.76 89.77 334.07 6230.10 - 1879.95 -3185.80 1.00 178.43 -67697 69.65 629.65 C04 284,.2/004 - 1 14 1 C1668180.64 7 9707 69 89.77 334.07 623241 - 1374.58 3431.48 0.00 0.00 - 118.04 26459 42469044513 1131 1452043064 - 213.901 PO4 ''M �FR � �� 8200 8250 8450 8500 8750 - -- 8850 9400 9650 11150 11650 6 8 973118 90.00 334.07 623245 - 1353.46 -3441.76 1.00 -1.57 -94.69 CD4-213 14Jun11 T2 8250 8300 8500 ' -' "' 8550 8850 8950 9650 9900 11650 12650 9 978507 90.54 33407 623220 - 1304.99 3465.33 1.00 -002 -4108 8 300 - - " - -- - 8350 8550 - - -- -' "'" 8600 8950 9050 9900 - -' " - -' 10150 12650 -- '_ -_ -' 13650 10 0164.47 90.54 334.07 6228.63 - 963.82 -3631.24 0.00 0.00 336.27 6.66166 DEM. 11 0218.36 90.00 33407 622838 -915.35 - 3854.81 1.00 179.70 389.87 C04- 21314Jun11 T3 7VD MD Name Sint 8350 8400 8600 8650 9050 9150 10150 10650 13650 14650 12 0248.10 8970 33407 6228.46 -88860 - 3667.81 1.00 - 18000 419.45 2268. 2712 67 6516 - 13 1168.66 89.70 334.07 6233.23 50.]3 -4070.35 000 000 1335.07 5197.22 826686 66 519814 1462046 3 612 14 1197.22 89.99 334.07 6233.31 35.05 -4082.84 1.00 0.01 1363.47 CD4 -213 14Jun11 T4 15 1197.22 89.99 334.07 6233.31 -35.05 -4082.84 1.00 0.00 1363.47 16 1932.80 8999 334.07 6233.46 62648 -4404.49 000 0.00 209512 17 1934.04 90.00 334.07 6233.46 627.59 -4405.03 1.00 -16.51 2096.35 C134 -213 14Jun11 75 LEGEND 18 2008.55 90/5 33407 6232.98 694.59 -4437.62 1.00 001 2170 46 19 2444.66 90.75 33407 6227.28 1086.76 -4628.33 000 000 2604 20 20 2492.56 9122 33406 6226.46 112983 -4649.28 1.00 -019 265184 CD4-213 14Jun11 TO CD4 -210, Plan: CD4-210A, 0134-210.44p11 VO 21 2498.05 91.28 334.06 6226.34 1134.76 -4651.68 1.00 -0.01 2657.30 22 311818 91.28 33406 6212.49 1692.48 -492292 000 0.00 3274 15 I 00237, CO237, 08237 V17 23 3206.77 9040 33406 6211 20 1771.96 -4961.57 1.00 17999 3362.05 C04- 213 14Jun11 T7 1[ C04 -05, C04-05, CD4-05 VO 24 3207.82 90.38 33406 6211.19 1772.90 -4962.03 1.00 - 179.98 3363.09 7 0134-07, CD4 -07, 013407 V1 25 386654 9038 33406 6206.77 2365.26 -5250.12 0.00 0.00 401827 26 3904.83 9077 33406 6206.39 2399.70 -5266.86 1.00 002 4056.36 0)4-213 14Jun11 T8 004-12. C0412. C04 -12 VO 27 4520.43 90.77 334.06 6198.14 2953.25 -5536.07 0.00 0.00 4668.60 C04 -213 14Jun11 T9 CD4-12, CD4-12P81, CD4 -12P81 VO 0 / 360 7 C134 -12. Nanuq 5. Nanuq 5 V1 0 / 360 200 CD4 -16, 004 -16, 004 -16 V2 50 -30 / 330 30 x CD4-17, C13`17. C04 -17 V13 -30 / 330 30 CD4-208, C04-208, CD4 -208 V7 1( C134-208, CD4- 208P51, 034-2081 V6 D CD4 -208, Rig: DD4208A, 004-20800722 VO C04-208, Rig: CD4 -2080, Rig CD4-208A V0 7 0 4 -208, TD•d: CD4- 208APB1, TOO CD4- 208APB1 VO -60 / 300 60 D CD4 -209, 004 -209, CD4 -209 V4 60 / 300 60 Ah ] 0134 -210, CD4 -210, CD4 -210 V3 I 0 4 -210, Plan: CD4 -2100, C04- 210A43013 VO D 0134211, 004-211. 004-211 02 004 -213, 004- 213. 004-213 V4 3 C04214, C04-214, 034 -214 V3 004-215, 004 -215. 004-215 V4 0 C04-23, CD4-23, CD4 -23 VO 8< 004 -23, C04- 23P61, 0D4 -23761 00 -90 / 270 Ri 9O I 0 13423, 013423782, CD4 -237132 V0 -90 / 270 90 �/ 3 CD4-24, C04-24, CD4 -24 V0 04-24. CD4-24P81. CD4 -24PB1 VO i/ I C04 -24, CD4- 24P82, C34 -24P82 VO i 004 -25, 004-25, 004 -25 V0 /( C04-25, C04-25L1, C0425L1 VO •1 7 CD4-25, CD4- 25PB1, CD4-25P81 VO r 4 034-26, 004 -26, C04-26 V0 ii .7 004-302, 004302, 004-302 03 120 / 240 120 -,- CD4-304, CD4304, 004-304 Vs -120 / 240 120 IF D CD4304, C04304PB1, 004-304781 V16 I CD4-306. 004306, 004 -306 01 I CD4-318, CD4318, CD4318 V6 • - 3' 004-318. 004-318A, CD4-318A V5 -150 / Z1O 150 -9- 004-318, 004-3181.81.004. 318781 V3 15O C134-319, 034-319. CD4319 VS -150 / 210 20, 3 004320, 0134320, 004-32002 50 -180 / 180 - 9 C04320, 004-320PB1 C34- 320PB1 V4 -180 / 180 3 C04 -321, 004321, C04321 V16 'J C04322, 004322, 004322 V8 Nanuq 3, Nanuq 3, Nanuq 3 Vi )( Plan CD4 -03, Plan C04 -03, C04 -030702 VO �- Plan: C04 -27, Plan: CD4-27, C04- 274703 VO I Nanuk 2, Nanuk 2. Nanuk 2 V1 -9- CD4 - 2130707 I Travelling Cylinder Azimuth (TFO +AZI) [9 vs Centre to Centre Separation [100 ft/in] Travelling Cylinder Azimuth (TFO+AZI) [ vs Centre to Centre Separation [25 ft/in] C D4 213w p 0 7 WELLBORE TARGET DETAILS (MAP CO- ORDINATES) 18:05, June 14 2011 Name TVDSS ON/-S *E / -W Northing Easting Shape CD4 -213 14Jun11 T9 6141.94 2953.25 - 5536.07 5960259.97 1512487.82 Point Q Mile View CD4-213 Toe Circle CD4 -213 14Jun11 T8 6141.94 2953.25 - 5536.07 5960259.97 1512487.92 Circle (Radius 1320.00) 6150.19 2399.70 -5266.86 5959702.16 1512747.96 Point CD4 -213 14Jun11 T7 6155.00 1771.96 -4961.57 5959069.57 1513042.97 Point Lu4 -z13 r4.runn To 617v.26 l ice.,, -4o4e.co 6,30422.95 tOL044.73 fvlrn CD4-213 14Jun11 T3 6172.18 - 915.35 - 3654.81 5956361.56 1514305.68 Point CD4-213 14Jun11 T1 6173.90 - 1880.38 - 3185.60 5955389.10 1514759.07 Point CD4 -213 14Jun11 T2 6176.25 - 1353.46 - 3441.76 5955920.08 1514511.54 Point CD4 -213 14Jun11 T4 6177.11 -35.05 -4082.84 5957248.64 1513892.08 Point 6000 CD4-213 14Jun11 T5 6177.26 627.59 -4405.03 5957916.39 1513580.74 Point ,N. itt* \\,. 1 1 � GD2,36P81 �•�� Oa ti0� • GOti� ` GQ`L 4000 ■ �!0 101: `) p.2 10 09: • • •,�� ` GO236 •r • C 2000 N .4_304 viiv - • o - i C) N 6110. r 00 -AIM o 0 1 Ma VIM el Ma -C MIIIIIIIIMMIMgllIllkVr• \ - .4111111klak 0 .., �rte►,:, - 9 Z 0 il 1011111111111100 P 1 001111001.110 0 V 174 VAHA _. i _C 1 1 i 0 2000 ��.�- M ill .� . t G ,�► a) O N'L � ► /� , G oA 2 � 1 � ► , � lit )1, I • ili .,,„, ell. - 4000 RP �'� ' 0% vk 1 1 1. ■■,,, :00' \ cPb( /0 V X �( yi i • AA - 600 - �»■m�i ■� i ∎� �► �∎IkT -N . �� 'itrr0 linik____,A 1-9.- 1:5 -. � , 1 9 Cu, -10000 -8000 - • 0 I EP'' a 0 , o; !0`''P 0 0 G 0 a 4000 6000 60 f est( -)/ - ast( +) (2000 ft/in) ■ MM MMMM MM MM■' MMMI UMiM MMMM M M EM OM■ M iME M MM M M M iEMM M i� M M M MMMMM M MMM M ■� M SMMM M ■MMMMMMMMM M OM M iM :i MM:M M MMM: MM � MMM : MiiiiiiMMiMMMSOMMM':MMO iii :MMM:: M M ■■MMMMMM MM ■ MMMMM ■MM MMMM■M■MMn■ ■■ MMMM ■M■E ■MM iiii■miumm EM■■ME ommu MMM■■■ rE ■ ■■■EEE■■MMM■rEM ■ ■MEE■M■■MEEMr ■■■MM ■■MME■Mrr milmm MMMMMMMMM ■MMM■ ■MMMMMM■ ■M■ MMMM ■■■■MMMM ■MMMM■ ■M MMMM■ MMMM■ MM ■■MM■M■M■MMM■■MMM■■MMMNMM$MMMM■ MMMMMMMMM UMMMMM■MM ■MM■MMMMMMMMMMM■ MMMM MMMMMM MMMM MMMM■ MMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMM MMMM MMMMM MMMM ' M M MMMMOMM OMOM M M iMM O MMM MMMMM ■ MMMMMMMMMMMMMUMMMMMMMMMMOMM■ MMM ■MM■MMU MMM M ■ / ■E■■M ■■■ / ■M ■■■ME ■■■■■■ ■E■M ummO■■■M M ■M/ MUEMEMM U M MUMMMMMMMMMMMMMIMEMSM MUROMMMM MMM LI MMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMM M111mmU�MMMMMMMM omIlm iiiiiiiiiMI MMMMMMMuu� i iiiiiM�MiMMMMM mimmEMM M■MM■■MEMMM ■MMMMMM ■MMMMMM /MM MMM■ MMM M■ OMMI■ M■ MMEMME■ MMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMM #MMM ■MMMEMMMMMMMMMMMMMMMMMMMIN MMMMMMMMOSOM MIMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMNMMMMMNM ■MMMM M■ MMMMMMMMMMMMMMMM MM MMMMISOM■M ■MMMMMINEMMMMMMMMMEM MMMMMM / ■MMMMMM ■MMMMMMMMM ■MMMMMM ■MMMM■■/ ■M■M■■■MMM ■ ■/■//■■■/ MM■ EMM■■ MOMEMPOR■ EMMM■■ ME i7 ■ ■EMM ■MMMMMMMM■■EM ■ ■MEEMM■ ■ EME■■ ■MMMMMM■ MMMM■ MMMMMM■ M ■M ■MMMLMMMMMMMM�IMt1M�� MM ■1MMMMIUMMMM■ MMMM MMMMMMMMMMMMMMMMMMMMMMMMMMMMMMM ■ MM MM MMMM■MMMMMIMMMMMOOMMAMUMM EMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMM■ ■MMMM rMMM MM /■ MM M MMMM ■ ■ ■M ■ ■■MMEMMINIKUM MMM ■■M UMMOMEMMUMM MMMM■ ■MMMMMM■ ■ ■MMEMMMMM■ME ■MM■ ■MMMM■ MMMMMMMMM ■■M MMM■ MMMMMMMM ►'IMMMMMMMMINIMMMMMMMMM■ MMMM ■■MMMMMM ■MMMMMMMMMMMM■M■MMMMMMM M .MMMMMM ■MM MMMMMMMMM■ MMMOMMMMMLI M■ ■■ ■MMMM■MMM■L'M MMMMMM ■MM■MMMMMMMM■MMMMMMMMMMMMMMMMMM ■MMMMMMMMMM�M■ MMM■ ■MMM ■MMMMMti.EPPEMAI M■M MMGINOMMMMMMMMMMMMMMM MMMMMMMMM■MMMMMMMMM ■MMMMMMMMMM MMMMMM MMMMMM■MMMMMMMMMMMMMMM MMMM MMMM MM MMM MMWMMMMMMMMM :MMMMMMMMMMMMMMMMMMMMMM� MMII MMM ■ ■MMMM MMMIMMMMMMMEMMMMMMMMMMMM ■MMMMMMMMMMM ■►'ME MMMM ■MMMMMM■MMMMMMMMMM ■■ ■ME■MMMrd ■ ■MMM ■■MMM I M ■RMM M ■■ MMM■■ ■EM ■■ ■MMM■ ■MME■ ■ ■ ■■1MMM ■ ■ ■MM■■■■ ■MMM ■■ ■ ■M ■■M ■r■ ■■MMMM ■ ■rr ■Mr ■ ■■ MMMMMMEMMMM■ MMM MM ■MMMMMMMMMMMMMMMMMMMMMMMMMMM MMMMO MMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMM ■MMMMMMMMMMMMM MMMM ■MM MMMMMM MMMM/MM MM MMONOMMMOMMMMMMMMiM MMM ■MMMMMMMMMMMMMMMMMMMM■MMMMMMMMM ■MMMM■ ■■MMMMMMMMMMMMMIU MMMMMMMMMMMMWINIMM ■M ■■MMMMMM ■ML #M■ MMMMMM ■MMMMMMMMMM■MMMMMMMMMMMMMM MMM ■■■MM■■■ MMM■■■ MMMM■■ MME■M E■■■ EEME ■■MMINIM■MMOMMM■ ■■MMM■■■■E ■MM ■MME ■M■■ ■MMMMr ■EM■ ■EM■ ■EE i M M MM■■ MM mMM M �MMiM M ii M : o iMMMas. . iMMinu MCMMM MiMiMMMM M ■MMMMMMMM ■ ■M■EMM■MMMNOM ■■E ■M■ MMM ■■ ■MMIIMM ■M ■ ■M■ ■■M■■MMMEM■ ■■■MMM ■■ ■MWOME ■MMMMMM■ MMM MMMMMMMMMMMMMMMM ■MMMMMM■MMMMMM MMMM MMO MMMMMMMEM ■MMM■MMMMMMMMMMMMM M ■ MMMMMMMMMMM MM■MMMMM. ■M ■MMMMMM■ ■MMM ■■MMMM■ ■MMM MMMM MMt'! MM ■MMMMMMMMMMMMMMMMMMM■MMMMMMMMMM ■MMMM ■MMMM ■MMMM ■MMMM� MMMM MMMMMMM . MMMMMMMMMMMMii i. M irRRM::* MMMMMMMMMMMMMMMMMMMMMM ■ /Mua:MM I!I mm UMMMMMMM MMMM.■ /MMMMMM■ ■ MMMMM■M■M.MMMMMMM MMM ■MMMMMMM■■ WOMMMI ■■. � MERN MMM ■MM M M■■ ■ MMMMMMMOM MiMME RO MM MUMMMM �� MMMMME MMO MMMM: as M M MMMM MMMMMMM MM IMMMMMMOMM MMONMMMMMMMMMMMMMMMMMM M MM n M M EM■UMMM MMMM ■ ■ MMM M 1 MMMMMM %MLMHMMMMLM MMMMMiMMM M :MM M M l ■/M ■MMM M MMMMMM ■■UMMOMMMMMiMMM I� ■MMM ■M ■MMMMMMIMMMMMMMMMMM�M M r i� MMMMM ■■ M MMM►MMMii iiIl■M ■ ■ ■EM ■ ■ ■M■ ■L1■ ■MMMMMM ■rM M M ■MMM ■M MMMM ■MMMMMMMMMpMMMI LU WMCM MM M MOMM ■MM ■MMMM HhhlluIN M ■ MM■MMMMMMEMMM!1!MM.SAME i# IMMMMMML' MMMMMMMl1MMMMMMMMMMMMMMMMMMMMMMMMM ■ 'MMMM M ■M MM M M M M M ' : M � 'MM M MMMMM % MMMONEMM M MM M ►I EM MMM MMMOM M MMM MMM ■MMMM. M MM MMMM MMM MMMMLMMMMMMMMMMMM ■MMLMMMMMMMMMMM MM ■ MMM MMOMMMM MMMMMOMMUMMMiiMMM MMMMMM 1MMMMMMMt�MMMMMMMI�MMMMMMMMMM MiMMiM MMM ■ ■MME■■ ■E ■MME MMIMMOM M/■■■■r M■ MBI NIM M■■ MM■■■ r■ MMEMM r■MM■M■MEM■M■MEMMUMMMM ■■ ■■■ME ■ MMM ■MMM ■ 0 MM �MMM MI M/r INI MMMMEMO ■ M MMMMMMM ■ MMMMMM MMMM MM MM MMM■ t1 MM M ■Mi�MMMMMMMMMMMMMMMiiIMMMMMM MMMMMM MHE / ■■ /1 ■MM■E■w.■MEMEME ■MML1u.Er■M ■MMMEM MMMM■ �� M M■MH ■M ■MMMM {M ■MMMMMMMMi aaMMMMM ■MMMMMMMMMMMMMMM ■■MMMM MMMM i•■ ,�.�a.aMMMMMMM ■MMMM■ i1 MMMMMM 7MMMIMMMil1MMM��MMMl1MMMMMMMMMM� NMMMMMM :MMMM:MMMMMM . MMMMMM MM MMMM ►"■s: MMMMMM MMMMMM::: ■ %:Mau muuuUM U MMM■MMMMMMMM M ■■■MMMM ■MMMM MM M�MMMMML!MM MMM MM /IMMMMMMLMMMMMMMMMMMMMMMMMMM MMMMMMMMMMMMM _■_ Mt MM MM■MMMN MMMMMM MM, MM fkMMU MMMMMMMi MMMMMMML IMMMMMMOMMMMMMMMMMMNMMMMN OW dart CmocoPNRpAIAImk, Inc..WM5 Giot:arecten: -0 .93 ° JcbNO: IN /A Reek Western North Sepe Magnetic 0 .0edllon: 20.48 ° AR No: IN /A WAR C134- 213wp07 Op 80.75 ° APINO: IN /A Rig IN /A Doglegper 100 ft System (WO) Rama.,: Mem SetLevel Sure.Leeden Original VS Plane: 340.00 Pc,. WO C04 -213 x 151797,60 N View VS Plane: 340.00 ° Ree IMIRM: 55.20 I V: 5957217.19 ft Unit System: APIB0sed /W5 Section A'S) RaReence: Set Comments: POOL: PIO Viegjv 8 8 8 8 8 8 8 8 8 8 _ O — N M R to O cD P in in N is to is in in in in CD4- 213wp07 Plan: 8264' to 14520.43' MD Nanuq 3: 6050' to 6350' TVDss + — I — 5961603 Nanuk 2: 6050' to 6350' TVDss I 1 CD4 -215: 9514' to 14761' MD - .2960600 CD4 -210: 7470' to 11690.4' MD CD4 -214: 8696' to 15072' MD - 5959600 CD4 -306: 6050' to 6350' TVDss CD4 -211: 7727' to 14379' MD t - -- - -.._ - - -- -- - 5958603 o i .. • z --_.. _ 5957600 — CD4- 213wp07 Plan —. —Nang 3 — —Nanuk 2 z t Section View -- • -CD4 -21 CD4 -2 10 -- -CD4 -214 , 5956600 - CD4 -30 —CD4 -211 . ___ ___ - - -_ - f— 5955603 I I I 7 � ! � � _ -..... _ - 5954600 1 - 5953600 _ - -- CD4 -2 5 C 14-214 CD4I211 5952603 O. r O East ( +) / West ( -) a 0 ) o m N - D4-211 / 4 • i �� r � CD4 -215 -- _ - - 1. 14-214 _ - - - _ _ - - - CD4-306 i i Nanuk2 • l i b anuq 3 R 8 8 8� 8 8 $`�� ` g N O O Q Q N t7 itJ Vertical Section Bong View VS Plane" Combo Preuew Page 1 of 1 (CD4- 213wp07Todbox)ds) 6/15/2011 11:25 AM • Closest in POOL III Closest Approach: Reference Well: CD4- 213wp07 Plan Offset Well: Nanuq 3 Coords.- Coords.- ASP ASP 3 -D ctr -ctr - - Meas. Subsea N( +)/S( -) View VS Meas. Subsea N( +)/S( -) Vrew VS Distance. • Depth Incl.Angle TRUEAz i. TVD E( +)A( -) (340) Comment Depth Inc! Angle TRUEAzi TVD E( +)NW( -) (340) :Comments POOL Min Distance POOL Min Distance (244.08 ft) in POOL (244.08 ft) in POOL (8264 - 14520.43 MD) (8264 - 14520.43 MD) b Nanuq 3(6050- b CD4- 213wp07 Flan 244.08 - 11125 89.7 334.07 617743 5957183 1513922 1292.06 6350TVDss) 7472.51 2331 271.73 609092 5957079 1513719 123238 (6050 - 6350 1VDss) Closest Approach: Reference Well: CD4- 213wp07 Plan Offset Well: CD4-306 Coords - Coords.- ASP ASP 3- Dctr -ctr Meas. Subsea N( +)IS( -) View VS Meas. Subsea N( +)/S( -) View VS Distance. Depth Incl.Mgle TRUEAzi. TVD E( +)AN( -) (340) Comments Depth Incl.Mgle TRUEAz i. TVD E( +)AN( -) (340) Comment POOL Min Distance POOL Min Distance (374 93 ft) in POOL (37493 11) in POOL (8264 - 14520 43 MD) (8264 - 14520 43 MD) to CD4 -306 (6050 - b C04- 213wp07 Flan 374.93 14075 90.77 334.06 614853 5959857 1512675 4226 635°TVD9s) 9032.63 4921 293.95 635659 5959989 1512957 427258 (6050 - 6350 TVDs s) Closest Approach: Reference Well: CD4- 213wp07 Plan Offset Well: CD4 -214 Coords.- Coords.- ASP ASP 3- Dctr -ctr Meas. Subsea N( +)/S( -) View VS Meas. Subsea N( +)S( - View VS Distance. Depth Incl.Mgle TRUEAz i. TVD E( +)AN( -) (340) Comment Depth Incl.Mgle TRUEAzi. ND E( +)M/( -) (340) Comment POOL Min Distance POOL Min Distance (96458 ft) in POOL (96458 ft) in POOL (8264 - 14520.43 MD) (8264 - 14520.43 MD) b CD4 -214 (8696 - b CD4- 213wp07 Plan 964.58 826456 85.09 3363 6141.664 5954586 1515118 - 155354 15072 MD) 867122 86.13 144.82 6151.75 5953658 1515380 - 251825 (8696 - 15072 MD) Closest Approach: Reference Well: CD4- 213wp07 Plan Offset Well: Nanuk 2 Coords.- Coords.- ASP ASP 3- D ctr -ctr . - Meas. Subsea N( +)/S( -) View VS Meas Subsea N( +)/S( -) View VS Distance. Depth Inc! Angle TRUEAzi. TVD E( +)AN( -) (340) Comment Depth Incl.Mgle TRUEAzi. TVD E( +)NV( -) (340) Comment POOL Min Distance POOL Min Distance (1016.14 ft)m POOL (1016 14 ft) in POOL (8264- 14520.43 MD) (8264- 14520 43 MD) to Nanuk 2 (6050 - b CD4- 213wp07 Flan 1016.14 8264.56 85.09 3363 6141964 5954586 1515118 - 155354 635° TVD 7032.43 188 27323 6121.69 5953769 1514515 31131 (6050- 6350 TVDss) Closest Approach: Reference Well: CD4- 213wp07 Plan Offset Well: CD4 -211 Coords.- Coords.- ASP ASP 3 -D ctr -ctr Meas. Subsea N( +)S( -) Mew VS Meas. Subsea N( +)S( -) View VS Distance. ' - Depth Incl.Mgle TRUEAzi. ND E( +)AN( -) (340) Comment Depth Inc! Angle TRUEAzi. TVD E( +)AN( -) (340) Comment POOL Min Distance POOL Min Distance (1251.84 ft) in POOL (1251.84 ft) in POOL (8264 -14520 43 MD) (8264 - 1452043 MD) b CD4 -211 (7727 - b CD4- 213wp07 Flan 1251.84 8725 88 3 334.74 6163.11 5955006 1514932 - 109533 14379 MD) 770233 8691 147.06 6155 81 5955525 1516071 - 977.46 (7727 - 14379 MD) Closest Approach: Reference Well: CD4- 213wp07 Plan Offset Well: CD4 -210 Coords.- Coords - ASP ASP 3 -D ctr -ctr Meas. Subsea N) +)S( - Vrew VS Meas. Subsea N( +)/S( -) Mew VS Distance. Depth Incl.Mgle TRUEAzi. TVD E( +)AN( -) (340) Comment Depth Inc! Angle TRUEAzi. TVD E( +)AN( -) (340) Comment POOL Min Distance POOL Min Distance (1472.68 ft) in POOL (1472.68 ft) in POOL (8264 - 14520.43 MD) (8264 - 1452043 MD) b CD4 -210 (7470- to CD4- 213wp07 Flan 1472.68 9975 9054 334.07 6174.8 5956141 1514408 14824 116904 MD) 7451.02 84.14 333.93 617532 5956765 1515742 3084 (7470 - 11690.4 MD) Closest Approach: Reference Well: CD4- 213wp07 Plan Offset Well: CD4 -215 Coords.- Coords.- ASP ASP 3 -D ctr -ctr - Meas Subsea N( +)S( -) View VS Meas Subsea N( +)/S( -) View VS Distance. • Depth Inc! Angle TRUEAzi. TVD E( +)AN( -) (340) Comment Depth Incl.Mgle TRUEAzi. TVD E( +)AN( -) (340) Comment POOL Min Distance POOL Min Distance (1785 49 ft) in POOL (1785 49 6) in POOL (8264 - 14520.43 MD) (8264 - 14520.43 MD) to CD4 -215 (9514 - to CD4- 213wp07 Flan 1785.49 - 8264.56 85.09 3363 6141.664 5954586 1515118 - 155354 14761 MD) 948946 83.75 1543 6154.99 5953165 1514036 - 2546.76 (9514 - 14761 MD) CD4- 213wp07 PoolSummaryxls 6/152011 1206 PM • 0 CD4-213wp07 Surface Location rZ. CPAI Cool dm _ ate Converter From: To: r ______ Datum: iNAD83 .71 Region: r --,...--, Datum: INAD27 , Region: ialaska 71 LatitudelLongitude .Decimal Degrees ,i- Latitude/Longitude Decimal Degrees UTM Zone: r South .,`. UTM Zone: T rue — South .: State Plane Zone: ;,1 ,1 Units: iL iLTT:1. State Plane Zone: T rue .,„: Units: ri; Legal Description (NAD 27 only) Starting Coordinates: Legal Description X: !1517974.60 Township: 011 Range. 004 E Y: 15957217.19 Meridian: u ,,.. Section: 24 FNL -.- 2942 4193 FEL "r 3L12.79957 ,.,... , 1 _ _ Transform il :Li Qui Help CD4-213wp07 Intermediate Casing Casin ..,, .., i _ ..._ 1 CPAI Cool climate Conveiter Qi.. From: To: , _ Datum: nNAD83 ... I Region: r ..... Datum: : N . AD : Region: alaska w , 1 Cs` Latitude/Longitude Decimal Degrees ■ ' - Latitude/Longitude Decimal Degrees 1 r UTM L — : one: F South * UTM Zone: : i r South State Plane Zone: 4 ...,7 Units: 11.71;71 ; - State Plane Zone: I T rL 77:1 3 Units: Legal Description (NAD 27 only) Starting Coordinates: Legal Description X: 11515118.49 Township: 1011 Fr,:i Range: 004 ' iu04 1E 's: 15954586.01 - • i Meridian: ru ,. , Section:125 340.28038 Fl\r 1 FET 3116.2492 1 Transform il Quit Help ' • • I_ CD4-213wp07 TD 1 (Pm cool (finale Convertei 1.L.H From: To: .. Datum: 1 .... • Region lalaska .....:" Datum . NAD 27 ,,. Region: alaska . LatitudelLongitude Decimal Degree Is r Latitude/Longitude 'Decimal Degrees :::" r UTM Zone: . 1 r South r UTM Zone: rue 11 ----- 17 South State Plane Zone: 4 , Units: us .ft , i , - State Plane Zone: True 7 Units: ,17571 ..... * Legal Description (NAD 27 only) Starting Coordinates: Legal Description X: 1512487.82 Township: [j Range.; 71 OTT," Range. i Y: 5960259.97 Meridian: . 1_1 1,' Section:114 IRTIL 15270.6391 1iii: 1558.43236 Transform I Quit Help REV DATE BY CK APP DSPTION REV DATE BY CK A DESCRIPTION 8 2/25/08 CZ GD C.A. UPDATED PER K080010ACS 9 4/02/09 CZ DB C.A. UPDATED PER K090003ACS N \, b � ) �L1 CD4 TO ALPINE 9 •�' ti ''� ; ACCESS ROAD / lO � , � / F i poi LOCATION OF \--9714--,, t 5 'I I rill THIS SURVEY � mo Q CD4 o pyQ Wa j `' �, ALPINE SATELLITE DEVELOPMENT ' VICINITY MAP NOT TO SCALE GP GES� R OF PAD-. CD -4 0.5 0 , 1 SHO ULDE PAD r,N E CAL mg �o W,$ C\ 0,,,RM � p o u I d .,n N1 pa ts V • • o rnt .Tc � e�.00USB:••••� , REAM 7 d .f. NN MN \ , OB° U • • • - - woo* QOL�L . u u o i-1--.: • • .... ���� -woo • Gj10N 0' 1E 0 5 U LE • � --w�� 98 MO / - id ATE G1N E HE �' PIG OL (Ton FUE �� MOO b 9W0 � �a PLANT CD -4 TO ALPINE_ N PIPELINE ASPC N 13•2750" j LCMF LJ 4j 0 Z LEGEND: KU U KP I K N 0 PROPOSED CONDUCTOR o o • EXISTING CONDUCTOR V) N Be WELLHEAD WELLHEAD Narrow 190 E61 Avis. • Aneh..0. Al". 69602 • ( 0 0 7 ) 27 & 7 1 0-0 690 o ABANDONED WELL Alpine Of ce A. (9 8139 Alpine Survey Office ALPINE MODULE: CD40 UNIT: CD C.noc.Phillips ALPINE PROJECT CD - WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05-03-03-1B-1 10/11/05 CE— CD 40 -121 1 OF 3 9 REV DATE BY CK APP ORIPTION REV DATE BY CK 0 DESCRIPTION 5 2/25/08 CZ GD C.A. UPDATED PER K080010ACS 6 4/02/09 CZ DB C.A. UPDATED PER K090003ACS ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC.24, T 11 N, R 4 E, U.M. SEC.LINE 0/S EXIST. WELL 'Y' 'X' LAT.(N) LONG.(W) FSL FEL GND PAD CD4 -X98 5,957,282.22 1,518,247.43 70° 17' 31.873" 150° 59' 20.893" 2407' 31' 12.4 19.1 CD4 -X99 5,957,277.98 1,518,227.75 70' 17' 31.828" 150° 59' 21.464" 2402' 51' 12.4 19.0 CD4 -301B 5,957,273.28 1,518,208.24 70' 17' 31.779" 150° 59' 22.030" 2397' 70' 12.4 19.0 CD4 -302 5,957,268.38 1,518,188.64 70' 17' 31.728" 150' 59' 22.599" 2392' 90' 12.4 19.6 CD4 -303 5,957,263.99 1,518,169.26 70' 17' 31.681" 150° 59' 23.162" 2387' 109' 12.4 19.6 CD4 -304 5,957,259.26 1,518,149.87 70' 17' 31.632" 150' 59' 23.725" 2382' 128' 12.4 19.5 CD4 -05 5,957 254.43 1,518,130.28 70° 17' 31.581" 150° 59' 24.293" 2377' 148' 12.4 19.5 CD4 -306 5,957,249.76 1,518,110.87 70' 17' 31.532" 150° 59' 24.857" 2372' 167' 12.4 19.6 CD4 -07 5.957,245.29 1,518,091.49 70' 17' 31.485" 150' 59' 25.419" 2367' 186' 12.4 19.7 CD4 -208 5,957,240.13 1,518,071.80 70' 17' 31.431" 150' 59' 25.991" 2362' 206' 12.4 19.8 CD4 -209 5,957,235.77 1,518,052.15 70' 17' 31.385" 150' 59' 26.561" 2357' 226' 12.4 19.7 CD4 -210 5,957,230.92 1,518,032.98 70° 17' 31.334" 150° 59' 27.118" 2352' 245' 12.4 19.6 CD4 -211 5,957,226.94 1,518,013.75 70' 17' 31.292" 150° 59' 27.676" 2348' 264' 12.4 20.0 CD4 -212 5,957,222.25 1,517,994.40 70° 17' 31.243" 150° 59' 28.238" 2343' 283' 12.4 19.6 CD4 -213 5,957,217.19 1,517,974.60 70' 17' 31.190" 150' 59' 28.812" 2337' 303' 12.4 19.9 CD4 -214 5,957,212.46 1,517,955.51 70' 17' 31.140" 150' 59' 29.367" 2332' 322' 12.4 19.8 CD4 -215 5,957,208.07 1,517,935.87 70' 17' 31.094" 150° 59' 29.937" 2327' 341' 12.4 19.8 CD4 -16 5,957,203.17 1,517,916.63 70' 17' 31.043" 150° 59' 30.495" 2322' 361' 12.4 19.5 CD4 -17 5,957,198.80 1,517,897.14 70' 17' 30.997" 150' 59' 31.061" 2318' 380' 12.4 19.5 CD4 -318A 5,957 193.71 1,517,877.38 70' 17' 30.944" ' 150' 59' 31.634" 2312' 400' 12.4 19.6 CD4 -319 5,957,189.64 1,517,857.90 70' 17' 30.900" 150' 59' 32.200" 2308' 419' 12.4 19.7 CD4 -320 5,957,185.03 1,517,838.65 70' 17' 30.852" 150° 59' 32.759" 2303' 438' 12.4 19.7 CD4 -321 5,957,180.22 1,517,819.26 70° 17' 30.802" 150° 59' 33.322" 2298' 458' 12.4 19.0 CD4 -322 5,957,175.24 1,517,799.90 70° 17' 30.749" 150° 59' 33.884" 2292' 477' 12.4 19.0 CD4 -X23 5,957,170.76 1,517,780.38 70' 17' 30.702" 150' 59' 34.450" 2288' 496' 12.4 19.0 CD4 -X24 5,957,166.23 1,517,760.82 70' 17' 30.655" 150' 59' 35.018" 2283' 516' 12.4 19.0 CD4 -X25 5,957,161.34 1,517,741.31 70° 17' 30.603" 150° 59' 35.584" 2278' 535' 12.4 19.0 CD4 -X26 5,957,157.10 1,517,721.97 70' 17' 30.558" 150' 59' 36.146" 2273' 554' 12.4 19.5 CD4 -227 5,957,151.94 1,517,702.56 70' 17' 30.505" 150° 59' 36.709" 2268' 574' 12.4 19.6 CD4 -X27 5,957,150.77 1,517,697.37 70' 17' 30.492" 150' 59' 36.860" 2266' 579' 12.4 18.4 C04 -X28 5,957,146.24 1,517,678.39 70' 17' 30.445" 150' 59' 37.411" 2261' 598' 12.4 18.8 KUUKPIK NOTES: ' , _ L COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 83. � leleM L Al . ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L.) Alpine Survey Office IIPV ALPINE MODULE: CD40 UNIT: CD C.noc.Phillips ALPINE PROJECT CD -4 WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05- 03- 03 -1B -2 10/11/05 CE -CD40 -121 2 OF 3 6 REV DATE BY CK APP CESZRIPTION REV DATE _ BY CK _A DESCRIPTION 5 5/25/08 CZ GD C.A. UPDATED PER K080010ACS 6 4/02/09 CZ DB C.A. UPDATED PER K090003ACS NOTES: 1. ALL COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. ORIGINAL GROUND ELEVATIONS WERE DERIVED FROM THE AVERAGE ELEVATION ALONG THE TOE OF THE CD -4 GRAVEL PAD. 3. BASIS OF COORDINATES: ALPINE PERMANENT CONTROL MONUMENTS PER SURVEY BY KUUKPIK /LCMF, OCTOBER 2005 4. DATES OF AS -BUILT SURVEYS: WELL CONDUCTORS CD4 -208, CD4 -209, CD4 -210 CD4 -318A, CD4 -319, 10/11/05, FB 2005 -26 PGS. 30 -31; CD4 -05, CD4 -306, CD4 -07, 04/13/06, FB 2006 -10, PGS 26, CD4 -320, 04/14/06, PG 29; CD4 -302, CD4 -303. CD4 -304, CD4 -16, CD4 -17, 04/18/06, PG 47; CD4 -211, CD4 -213, CD4 -214, CD4 -215, 04- 26 -06, FB 2006 -10, PGS 65 -66; CD4 -301B, CD4 -321, 5/13/06, FB 2006 -13, PG. 27; CD4 -322, CD4 -X23, CD4 -X24 CD4 -X25, 03/30/07, FB 2007 -08, PGS. 4 -5; CD4 -X26, 5/3/07, FB 2007 -09, PG. 42; CD4 -X98 & CD4 -X99, 4/2/09, FB 2009 -05, PG. 41; CD4 -X27 & CD4 -X28, 4/9/09, FB2009 -05, PG. 55. 5. CD4 -212 IS EXISTING WELL NANUQ #5. REFERENCE DRAWING CE -AP00 -162. CD4 -227 IS EXISTING WELL NANUQ #3 (ABANDONED). REFERENCE DRAWING CEA -M1 XX- 60D380. SURVEYOR'S CERTIFICATE 4 .�����r��, 11 I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND •�� P„•• .. F '•A.gSir �• AS -BUILT REP ESE TS SURVEY MADE T BY E MEE OR UNDER MY DIRECT `. ••. • SUPERVISION, THAT THE MONUMENTS SHOWN HEREON ACTUALLY EXIST • �� * AS DESCRIBED, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE 49th • CORRECT. • • / DATE: REGISTRATION NO. LS -5077 • • / Donald G. Bruce L ••• sue' No. LS -5077 F • <"P '•• •• •' � � KUUKPIK IIIIIMILS*114 " ;. 1CM F � 130 E61 ,tAv,. A Am. 88509 (801)219.1890 0330, Office (Ace Alpine Survey Office ALPINE MODULE: CD40 UNIT: CD C.noc.Phillips ALPINE PROJECT CD -4 WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05- 03- 03 -1B -3 10/11/05 CE -CD40 -121 3 OF 3 6 • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 April 01, 2011 Commissioner Dan Seamount QQ y ! �� Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 x :-. 4 }, LP N � p 6 , F A �+ Anchorage, AK 99501 �? <� l� Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and 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 March 13 -15 and March 27 -28, 2011. 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, 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 04/01/2011 CD4 PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal CD4 -07 50103205530000 2071180 6" n/a 16" n/a 3.8 3/13/2011 CD4 -12 50103204140100 2100910 13" n/a 36" n/a 11.9 3/13/2011 CD4 -23 50103206210000 2100670 28" n/a 28" n/a 8.5 3/13/2011 CD4 -24 50103206020000 2090970 16" n/a 16" n/a 4.3 3/13/2011 CD4 -26 50103206000000 2090490 26" n/a 26" n/a 8.5 3/13/2011 CD4 -209 50103205320000 2060650 SF n/a 16" n/a 4.2 3/13/2011 3 < 50103205400000 2061730 13" n/a 18" n/a 4.3 3/13/2011 CD4 -322 50103205510000 2071010 SF n/a 16" n/a 4.7 3/13/2011 .a ~ .~ ,,~`~ ~~ ~ - ,~ ~~ '"' •~~ °~ '` ~x~ ~~_ ?~ ~` ~~ V , `~ ~' ~,~~ ~ ~° mot: ,~. ~- r MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER.THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~ ~~~ ~ ~ ~ ~ DATA SUBMITTAL COMPLIANCE REPORT 613/2010 Permit to Drill 2061730 Well Name/No. COLVILLE RIV NAN-N CD4-213 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20540-00-00 MD 8305 TVD 6201 Completion Date 4!1/2008 Completion Status SUSP Current Status SUSP UIC REQUIRED INFORMATION ., d Mud Log No Samples No Directional Survey ~YesJ DATAINFORMATpN Types Electric or Other Logs Run: GR / RES Well log Information: Log/ Electr Data Digital Dataset (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Ty mea/rant rvumoer Name scale meaia No Start Stop cM Keceivetl comments og Cement Evaluation 5 Col 1 3560 7860 Case 2/20/2007 CBL, SCMT, GR, CCL 28-~ Jan-2007 ED D Asc Directional Survey 0 8305 Open 3/27/2007 ~E D C Lis 15008 nduction/Resistivity 2678 8305 Open 4/13/2007 LIS Veri, GR, FET, ROP ! jj .L'og Induction/Resistivity 25 Col 114 8305 Open 11/5/2008 MD ROP, DGR, EWR 4- Dec-2008 z og Induction/Resistivity 25 Col 114 8305 Open 11/5/2008 TVD ROP, DGR, EWR 4- Dec-2008 ED C 17133,Jfnduction/Resistivity 1143 8305 Open 11/5/2008 PDS, EMF and CGM of EWR logs ~ Well CoreslSamples Information: Name Sample Interval Set Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? "'~:/ Daily History Received? lJ' N Chips Received? Formation Tops Analysis ~LLDJ^ Received? DATA SUBMITTAL COMPLIANCE REPORT 613/2010 Permit to Drill 2061730 Well Name/No. COLVILLE RIV NAN-N CD4-213 Operator CONOCOPHILLIPS ALASKA INC MD 8305 ND 6201 Completion Date 4/1/2008 Completion Status SUSP Current Status SUSP Comments: Compliance Reviewed By: _ Date: _ ~~~ API No. 50-103-20540-00-00 UIC Y r ~ L_J ~a . ~ G. C. Alvord Alpine Drilling Team Leader Drilling & Wells ConocoPhillips March 12, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for CD4-213 Dear Commissioner: P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 RECEIVED MAR 1 3 2008 qua 0+1 & Gas Cons. Commission Anclnora9e Per the request from AOGCC, ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the Alpine well CD4-213. We have received authorization to suspend the well on 2/19/2008, approval #308-052. Attached to this completion report are letters to AOGCC from ConocoPhillips communicating the request to suspend. We have already submitted the daily operations summary and the directional survey. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad 4 ~ WELL COMPLETION OR RECOMPLETION~REPORT AI~RL~oo8 STATE OF ALASKA ~ RECEIVEC~ ALASKA OIL AND GAS CONSERVATION COMMISSION 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned Suspended / 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: ~:~ Gas vvrw~ Development ~nchorratory Service / Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp Susp. ~, /. D~ or Aband.: February 19, 2008 12. Permit to Drill Number: 206-173 / 308-052 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: December 26, 2006 13. API Number: , 50-103-20540-00 4a. Location of Well (Governmental Section): Surface: 2942' FNL, 303' FEL, Sec. 24, T11 N, R4E, UM ~ 7. Date TD Reached: January 3, 2007 14. Well Name and Number. CD4-213 ' Top of Productive Horizon: 305' FNL, 3132' FEL, Sec. 25, T11 N, R4E, UM 8. KB (ft above MSL): 36' RKB Ground (ft MSL): 55' AMSL ~,1.1. 15. Field/Pool(s): Colville River Field Total Depth: 305' FNL, 3132' FEL, Sec. 25, T11 N, R4E, UM 9. Plug Back Depth (MD + TVD): 8207' MD / 6191' ND Nanuq-Nanuq Oil Pool • 4b. Location of Well (State Base Plane Coordinates): Surface: x- 377941 y- 5957470' Zone- 4 10. Total Depth (MD + TVD): 8305' MD / 6201' TVD 16. Property Designation: ALK 380077, 3642os, 3soo75 TPI: x- 375070 y- 5954875 Zone- 4 Total Depth: x- 375070 - 5954875 Zone- 4 11. SSSV Depth (MD + TVD): none 17. Land Use Permit: ALK 380077 16. Directional Survey: Yes ^ No 0 (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): 1500' TVD ' 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): cop of window @ a~ oa• GR/RES 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD 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" pre-installed 9-5/8" 40# L-80 36' 2713' 36' 2389' 12.25" 349 sx AS Lite, 234 sx Class G 7" 26# L-80 36' 8295' 36' 6201' 8.75" 187 sx LiteCRETE, 287 sx Class G 23. Open to production or injection? Yes ^ No / If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" kill string 2309' none none 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED none 26. PRODUCTION TEST Date First Production none Method of Operation (Flowing, gas lift, etc.) suspended Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No ^/ 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 2/2007 =~~(~ ~~,~-„CONTINUED ON REVERSE SIDE ~ ~ ~ ~• OS 28. GEOLOGIC MARKERS (List all formations and ma ers encountered): 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 1547' 1500' needed, and submit detailed test information per 20 AAC 25.071. C-30 2747' 2414' C-20 3284' 2808' K-3 4692' 3841' K-2 5040' 4095' Nanuq 8206' 6191' • N/A Formation at total depth: Nanuq 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Nina WOOds @ 265-6403 Printed Nam Chi Alvord Title: Drillino Team Leader Signaturehone 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 2/2007 r CD4-213 Well Events Summary • DATE Summary 1/26/07 Pulled BPV with FMC -well on slight vacuum 1/28/07 CEMENT BOND LOG RAN USING AN SCMT W/ ROLLER STEM BETWEEN TOOL JOINTS. TOOL STOPPED @ 7860' ELM AND 70 DEGREE DEVIATION -BEGAN LOG UP FROM THAT POINT TO TOP OF CEMENT @ 3842' ELM. APPEARED TO BE A GOOD CEMENT JOB. JOB COMPLETE. f~ ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 February 27, 2008 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ConocoPhillips ~~~~~~~ F F~3 ~ r; 2008 ,~1a~ka ()i1 ~ Gas Cars. Ca~r,~ f ~,... -.:r Re: Sundry Permit: Suspend CD4-213 Requested Documents q~a~g Dear Sir or Madam: ConocoPhillips Alaska, Inc. received approval to suspend drilling operations on CD4- 213. (Approved Sundry # 308-052). Please find attached the survey reports as requested on the approved Sundry. If you have any questions or require further information, please contact Nina Anderson at 265-6403. Sincerely, r Nina And son Drilling E gineer Attachment: 1) CD4-213 Final Survey cc: CD4-213 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1577 Liz Galiunas ATO 1704 Jack Walker ATO 1740 • • Halliburton Company Survey Report Company:. ConocoPhillips Alaska Inc . Date: 2/5/2007 Time: 08:46:47 Page: 1 Field: Colville River Unit Co-ordinate(N~) Reference: Well; CD4-213, True North . .Site:. Alpine CD4 Vertical (TVD) Reference: CD4-213: 56.6 Well:. CD4-213 Section (VS) Reference: Well (O.OON,O.OOE,300.64Azi), Wellpath: CD4-213 Survey Calculation Method: Minimum Curvature Db:' Oracle 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 Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: CD4-213 Slot Name: Alpine CD4 Well Position: +N/-S -59.84 ft Northing: 5957470.04 ft Latitude: 70 17 32.377 N +E/-W -232.69 ft Easting : 377941.09 ft ~ Longitude: 150 59 17.544 W Position Uncertainty: 0.00 ft Wellpath: CD4-213 Drilled From: Well Ref. Point 501032054000 Tie-on Depth: 36.75 ft Current Datum: CD4-213: Height 56.65 ft " Above System Datum: Mean Sea Level Magnetic Data: 12/25/2006 Declination: 22.94 deg Field Strength: 57555 nT Mag Dip Angle: 80.67 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.75 0.00 0.00 300.64 Survey Program for Definitive Wellpath Date: 11/14/2006 Validated: No Version: 4 Actual From To Survey Toolcode Tool Name ft ft 70.00 530.00 CD4-213 gyro (70.00-530.00) CB-GYRO-SS Camera based gyro single shot 568.46 8265.01 CD4-213 ( 568.46-8265.01) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 36.75 0.00 0.00 36.75 -19.90 , 0.00 0.00 5957470.04 377941.09 TIE LINE 70.00 0.75 171.00 70.00 13.35 -0.21 0.03 5957469.82 377941.12 CB-GYRO-SS 167.00 1.25 141.50 166.98 110.33 -1.67 0.79 5957468.36 377941.85 CB-GYRO-SS 258.00 1.50 140.00 257.96 201.31 -3.36 2.18 5957466.65 377943.21 CB-GYRO-SS 349.00 1.65 168.00 348.93 292.28 -5.55 3.21 5957464.44 377944.21 CB-GYRO-SS 441.00 2.00 199.50 440.88 384.23 -8.36 2.95 5957461.63 377943.91 CB-GYRO-SS 530.00 2.55 206.00 529.81 473.16 -11.61 1.57 5957458.41 377942.47 CB-GYRO-SS 568.46 2.53 207.22 568.23 511.58 -13.13 0.80 5957456.90 377941.68 MWD+IFR-AK-CAZ-SC 656.91 2.50 204.70 656.60 599.95 -16.62 -0.90 5957453.44 377939.92 MWD+IFR-AK-CAZ-SC 750.29 3.89 200.28 749.83 693.18 -21.44 -2.84 5957448.65 377937.90 MWD+IFR-AK-CAZ-SC 839.69 6.59 202.20 838.85 782.20 -29.04 -5.83 5957441.11 377934.79 MWD+IFR-AK-CAZ-SC 935.12 10.79 201.13 933.16 876.51 -42.44 -11.13 5957427.79 377929.28 MWD+IFR-AK-CAZ-SC 1030.28 14.18 196.94 1026.06 969.41 -61.91 -17.74 5957408.43 377922.35 MWD+IFR-AK-CAZ-SC 1125.54 17.92 197.02 1117.59 1060.94 -87.09 -25.43 5957383.38 377914.25 MWD+IFR-AK-CAZ-SC 1220.37 21.15 199.65 1206.95 1150.30 -117.16 -35.45 5957353.48 377903.74 MWD+IFR-AK-CAZ-SC 1315.68 25.66 203.39 1294.40 1237.75 -152.32 -49.44 5957318.56 377889.19 MWD+IFR-AK-CAZ-SC 1410.89 27.60 207.22 1379.51 1322.86 -190.86 -67.71 5957280.33 377870.30 MWD+IFR-AK-CAZ-SC 1505.93 27.53 207.82 1463.77 1407.12 -229.86 -88.03 5957241.66 377849.35 MWD+IFR-AK-CAZ-SC 1600.93 30.55 209.17 1546.81 1490.16 -270.37 -110.05 5957201.52 377826.67 MWD+IFR-AK-CAZ-SC 1695.41 33.81 209.78 1626.77 1570.12 -314.16 -134.82 5957158.14 377801.20 MWD+IFR-AK-CAZ-SC 1790.50 35.67 210.00 1704.91 1648.26 -361.14 -161.82 5957111.61 377773.44 MWD+IFR-AK-CAZ-SC 1885.75 38.10 209.90 1781.09 1724.44 -410.67 -190.36 5957062.55 377744.10 MWD+IFR-AK-CAZ-SC 1980.86 40.99 210.02 1854.42 1797.77 -463.13 -220.60 5957010.59 377713.02 MWD+IFR-AK-CAZ-SC 2075.81 42.69 210.79 1925.16 1868.51 -517.75 -252.66 5956956.51 377680.08 MWD+IFR-AK-CAZ-SC 2171.35 41.85 210.34 1995.85 1939.20 -573.08 -285.34 5956901.72 377646.51 MWD+IFR-AK-CAZ-SC 2266.96 42.13 211.16 2066.92 2010.27 -628.05 -318.04 5956847.29 377612.92 MWD+IFR-AK-CAZ-SC 2362.76 44.81 212.12 2136.44 2079.79 -684.14 -352.62 5956791.77 377577.43 MWD+IFR-AK-CAZ-SC 2457.65 44.68 211.93 2203.83 2147.18 -740.78 -388.05 5956735.72 377541.10 MWD+IFR-AK-CAZ-SC 2553.05 43.57 211.55 2272.31 2215.66 -797.26 -422.99 5956679.82 377505.25 MWD+IFR-AK-CAZ-SC • • Halliburton Company Survey Report Company:' ConocoPhillipSAlaska Inc. Date: 2/5/2007 Tim e: 0$:46:47 Page: 2 Field: Colville River Unit Co-ordinate(NE) Reference:. WeIL' CD4-213; True North Site: Alpine CD4 Vertical (TVD) Reference: CD4-213: 56.6 Well: CD4-213 Section (VS) Reference: Well (O.OON,O.Ot)E,300.64Azi) Wellpath: CD4-213 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Iacl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 2648.19 43.19 211.49 2341.46 2284.81 -852.96 -457.15 5956624.68 377470.19 MWD+IFR-AK-CAZ-SC 2674.92 43.05 210.54 2360.97 2304.32 -868.62 -466.57 5956609.18 377460.52 MWD+IFR-AK-CAZ-SC 2771.55 42.49 210.49 2431.91 2375.26 -925.15 -499.88 5956553.20 377426.29 MWD+IFR-AK-CAZ-SC 2866.79 41.69 210.32 2502.58 2445.93 -980.21 -532.19 5956498.68 377393.10 MWD+IFR-AK-CAZ-SC 2962.13 43.26 209.65 2572.90 2516.25 -1035.97 -564.36 5956443.45 377360.03 MWD+IFR-AK-CAZ-SC 3057.19 43.25 209.74 2642.13 2585.48 -1092.56 -596.63 5956387.40 377326.85 MWD+IFR-AK-CAZ-SC 3152.63 43.32 209.61 2711.61 2654.96 -1149.41 -629.03 5956331.09 377293.54 MWD+IFR-AK-CAZ-SC 3247.56 43.10 209.27 2780.80 2724.15 -1206.02 -660.97 5956275.01 377260.68 MWD+IFR-AK-CAZ-SC 3342.50 42.58 209.38 2850.41 2793.76 -1262.30 -692.59 5956219.26 377228.15 MWD+IFR-AK-CAZ-SC 3437.81 42.24 209.19 2920.79 2864.14 -1318.36 -724.03 5956163.72 377195.81 MWD+IFR-AK-CAZ-SC 3532.67 42.80 209.88 2990.70 2934.05 -1374.14 -755.64 5956108.46 377163.30 MWD+IFR-AK-CAZ-SC 3628.03 43.05 212.03 3060.53 3003.88 -1429.83 -789.04 5956053.33 377129.00 MWD+IFR-AK-CAZ-SC 3723.88 42.75 211.83 3130.75 3074.10 -1485.20 -823.55 5955998.53 377093.60 MWD+IFR-AK-CAZ-SC 3818.89 42.29 211.74 3200.77 3144.12 -1539.78 -857.37 5955944.51 377058.90 MWD+IFR-AK-CAZ-SC 3914.00 43.02 212.15 3270.72 3214.07 -1594.47 -891.47 5955890.39 377023.92 MWD+IFR-AK-CAZ-SC 4009.09 43.32 210.80 3340.07 3283.42 -1649.95 -925.44 5955835.47 376989.06 MWD+IFR-AK-CAZ-SC 4104.53 42.84 211.41 3409.78 3353.13 -1705.77 -959.11 5955780.21 376954.49 MWD+IFR-AK-CAZ-SC 4199.41 43.01 210.30 3479.26 3422.61 -1761.24 -992.25 5955725.29 376920.46 MWD+IFR-AK-CAZ-SC 4294.71 42.31 210.38 3549.34 3492.69 -1816.97 -1024.87 5955670.10 376886.94 MWD+IFR-AK-CAZ-SC 4389.88 41.90 209.69 3619.95 3563.30 -1872.21 -1056.81 5955615.39 376854.11 MWD+IFR-AK-CAZ-SC 4485.70 42.50 209.80 3690.93 3634.28 -1928.09 -1088.74 5955560.04 376821.28 MWD+IFR-AK-CAZ-SC 4581.04 43.18 208.84 3760.84 3704.19 -1984.62 -1120.48 5955504.04 376788.62 MWD+IFR-AK-CAZ-SC 4676.17 43.85 211.45 3829.84 3773.19 -2041.24 -1153.38 5955447.96 376754.82 MWD+IFR-AK-CAZ-SC 4771.37 43.11 211.00 3898.91 3842.26 -2097.26 -1187.34 5955392.51 376719.95 MWD+IFR-AK-CAZ-SC 4867.55 42.42 210.63 3969.52 3912.87 -2153.35 -1220.80 5955336.98 376685.60 MWD+IFR-AK-CAZ-SC 4962.88 43.28 209.71 4039.41 3982.76 -2209.40 -1253.37 5955281.47 376652.11 MWD+IFR-AK-CAZ-SC 5058.19 44.13 211.28 4108.31 4051.66 -2266.13 -1286.80 5955225.29 376617.78 MWD+IFR-AK-CAZ-SC 5153.36 43.38 211.04 4177.06 4120.41 -2322.45 -1320.85 5955169.53 376582.82 MWD+IFR-AK-CAZ-SC 5248.47 43.04 211.10 4246.38 4189.73 -2378.23 -1354.46 5955114.31 376548.31 MWD+IFR-AK-CAZ-SC 5343.70 43.26 211.96 4315.85 4259.20 -2433.74 -1388.52 5955059.36 376513.36 MWD+IFR-AK-CAZ-SC 5439.23 43.39 211.99 4385.35 4328.70 -2489.34 -1423.23 5955004.34 376477.75 MWD+IFR-AK-CAZ-SC 5534.51 42.51 211.41 4455.09 4398.44 -2544.58 -1457.34 5954949.67 376442.75 MWD+IFR-AK-CAZ-SC 5629.95 42.91 209.76 4525.22 4468.57 -2600.30 -1490.28 5954894.49 376408.92 MWD+IFR-AK-CAZ-SC 5723.54 43.02 209.52 4593.71 4537.06 -2655.74 -1521.82 5954839.57 376376.48 MWD+IFR-AK-CAZ-SC 5820.01 43.59 210.00 4663.91 4607.26 -2713.18 -1554.67 5954782.68 376342.71 MWD+IFR-AK-CAZ-SC 5913.96 42.82 210.14 4732.39 4675.74 -2768.85 -1586.89 5954727.55 376309.58 MWD+IFR-AK-CAZ-SC 6011.06 42.11 210.38 4804.02 4747.37 -2825.47 -1619.93 5954671.48 376275.64 MWD+IFR-AK-CAZ-SC 6106.45 42.76 210.29 4874.42 4817.77 -2881.02 -1652.43 5954616.47 376242.24 MWD+IFR-AK-CAZ-SC 6200.90 43.45 210.60 4943.38 4886.73 -2936.66 -1685.14 5954561.37 376208.63 MWD+IFR-AK-CAZ-SC 6297.30 42.39 210.08 5013.97 4957.32 -2993.32 -1718.30 5954505.27 376174.56 MWD+IFR-AK-CAZ-SC 6392.30 42.98 212.83 5083.81 5027.16 -3048.24 -1751.91 5954450.90 376140.07 MWD+IFR-AK-CAZ-SC 6487.51 42.02 216.06 5154.01 5097.36 -3101.28 -1788.27 5954398.46 376102.85 MWD+IFR-AK-CAZ-SC 6582.58 40.32 220.76 5225.59 5168.94 -3150.32 -1827.09 5954350.06 376063.24 MWD+IFR-AK-CAZ-SC 6677.89 38.05 232.22 5299.56 5242.91 -3191.73 -1870.50 5954309.37 376019.17 MWD+IFR-AK-CAZ-SC 6772.89 37.59 240.10 5374.65 5318.00 -3224.13 -1918.79 5954277.76 375970.37 MWD+IFR-AK-CAZ-SC 6868.25 36.81 248.97 5450.66 5394.01 -3248.90 -1970.71 5954253.84 375918.06 MWD+IFR-AK-CAZ-SC 6963.55 37.79 256.87 5526.52 5469.87 -3265.78 -2025.82 5954237.85 375862.68 MWD+IFR-AK-CAZ-SC 7058.75 38.87 265.71 5601.25 5544.60 -3274.65 -2084.06 5954229.93 375804.31 MWD+IFR-AK-CAZ-SC 7153.96 40.43 273.34 5674.60 5617.95 -3275.09 -2144.71 5954230.48 375743.66 MWD+IFR-AK-CAZ-SC 7248.96 43.03 278.84 5745.52 5688.87 -3268.31 -2207.53 5954238.27 375680.97 MWD+IFR-AK-CAZ-SC 7344.46 46.38 285.71 5813.42 5756.77 -3253.93 -2273.06 5954253.71 375615.69 MWD+IFR-AK-CAZ-SC 7439.43 48.19 293.34 5877.89 5821.24 -3230.58 -2338.70 5954278.13 375550.44 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report Company: ConocoPhillips Alaska Ina Date: 2/5/2007 Tim e: 08:46:47 Page;. 3 Field: Colville River Unit Co-ordinate(NE) Reference: Well: CD4-213,. True North Site: Alpine CD4 Vertical ('TVI)) Reference: CD4-213: 56.6 Well: CD4-213 Section (VS)'Reference: Well (O.OON,O.OOE 300.64Azi) Wellpath: CD4-213 Survey Calculation Method: Minimum Curvature I)b: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/VV MapN MapE Tooi ft deg deg ft ft ft ft ft ft 7534.48 51.88 301.54 5939.00 5882.35 -3196.94 -2403.18 5954312.80 375486.52 MWD+IFR-AK-CAZ-SC 7629.56 55.72 307.79 5995.18 5938.53 -3153.26 -2466.16 5954357.50 375424.26 MWD+IFR-AK-CAZ-SC 7724.91 60.42 314.28 6045.63 5988.98 -3100.10 -2527.06 5954411.63 375364.24 MWD+IFR-AK-CAZ-SC 7820.05 66.38 316.66 6088.22 6031.57 -3039.46 -2586.65 5954473.23 375305.65 MWD+IFR-AK-CAZ-SC 7915.27 70.99 321.55 6122.84 6066.19 -2972.41 -2644.64 5954541.20 375248.76 MWD+IFR-AK-CAZ-SC 8010.48 74.23 326.54 6151.31 6094.66 -2898.88 -2697.94 5954615.59 375196.67 MWD+IFR-AK-CAZ-SC 8105.71 78.03 331.04 6174.14 6117.49 -2819.83 -2745.79 5954695.40 375150.10 MWD+IFR-AK-CAZ-SC 8200.64 82.13 336.16 6190.50 6133.85 -2736.11 -2787.33 5954779.78 375109.94 MWD+IFR-AK-CAZ-SC 8265.01 85.09 336.30 6197.67 6141.02 -2677.57 -2813.11 5954838.72 375085.12 MWD+IFR-AK-CAZ-SC 8305.00 85.09 336.30 6201.09 6144.44 -2641.09 -2829.12 5954875.45 ~ 375069.70 PROJECTED to TD ~~ ~~ ~ ~d ~' '~ ~ ~ ALASI~ OIL A1~TD GAS COI~TSERQA7`IOl'IT COMI~IISSIOrIT Chip Alvord Alpine Drilling Lead Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Colville River Field, Nanuq Nanuq Oil Pool, CD4-213 Sundry Number: 308-052 Dear Mr. Alvord: 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 ~ day of February, 2008 Encl. ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 February 13, 2008 Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry Permit: Suspend CD4-213 Dear Sir or Madam: ConocoPhillips ~~~ ~?~j 193~f,+iF.v M ConocoPhillips Alaska, Inc. applied for a sundry permit for operational shutdown on CD4-213. (Approved Sundry # 307-009). At the time the permit was submitted, the decision to temporarily shut down drilling operations on CD4-213 was due to ice road/pad timing and the desire to maximize rig time at Fiord during the winter season. Due to uncertainty with the Nanuq development, ConocoPhillips Alaska, Inc. is requesting a change to the status of CD4-213 to suspend. The asset will.. continue to re- evaluate and conduct studies of the geology and productivity of the Nanuq reservoir. Studies based on earlier wells drilled in the Nanuq are on going and will contribute to this evaluation. Additionally, CD4-213 continues to compete with stronger wells on the current rig schedule and the earliest estimated date for commencing operations would be third quarter 2009. CD4-213 is secured with Intermediate casing run and cemented. The wellbore has future utility and a new program will be submitted once the development team has completed current studies and can present a plan forward for the Nanuq development. Please find attached the form 10-403 and a current schematic. If you have any questions or require further information, please contact Nina Woods 265-6403. Sincer u~ ~~~Z Nin nders n Drilli g Engineer Attachments: 1) CD4-213 Well Completion Report 2) CD4-213 Current Schematic cc: CD4-213 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1700 Vern Johnson ATO 1702 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation RIGINAL r ~~~"0~ R~C~I'1I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ jt~® ~~ 1 ~ t~~ APPLICATION FOR SUNDRY APPROVAL B `~ 20 AAC 25.280 Al~lska Oil ~ ~'~~ ~OR~, ~~l'ttmi sign 1. Type of Request: Abandon ^ Suspend 0 Operational Shutdown ^ Perforate ^ Waiv~'ft~i?~QSf Other ^ Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 206-173 - 3. Address: Stratigraphic ^ Service Q ~ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20540-00 - 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? Y6S ^ NO ~ CD4-213 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 380077, 384209, 380075' 55' BPMSL Colville River Field /Nanuq Nanuq Oil Pool - 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8305' 6201' 8207' Casing Length Size MD ND Burst Collapse Conductor 77' 16" 114' 114' Surface 2713' 9.625" 2713' 2398' Intermediate 8295' ~ 7" 8295' 6200' Kill String 4.5" 2309' 2104' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None none Packers and SSSV MD (ft) no packer no SSSV 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 3rd quarter 2009 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ~ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Nina Anderson @ 265-6403 Printed Name C. Alvord Title: Alpine Drilling Lead Engineer Signature Phone 265-6120 Date ~' Low Commission Use Onl Sundry Numbe~~~ ^~ resentative ma Commission so that a re witness ~~ ~ ~ L-~ Conditions of a roval: Notif y p y pp Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~`„~7~~~ U.~ ~(c Svh3~ ~ 0~~~~ ~ ~~:~ ~ ~~ ~ 5 ~3~j v"K ~ ~~ ~ ~'\~.~~ ~°, tr.U ~;~~,,~<o~~:.\ ~ ~ ~--~ ~ v.~.~ ~~c~s~ ~t~~~ss -~oc-t~`~rr~ s`~~~~='l~~~ Subsequent Form Required: ~-~V~ S ~I°~; FHB 2 Q 2008 ~ APPROVED BY ~ ~ , ~~ Approved by' COMMISSIONER THE COMMISSION Date: Form 1 03 R ised 06/2006 Submit in Duplicate ~,~' /~ Z ~ ~"' da Fior~CD3) Colville River Fib CD4-213 Production Well -Suspend Schematic Top Nanuq 8210' MD / 6192' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 8295' MD / 6200' TVD , Ca-no~aPhillips Time Log Summary VJeiNJew Web Re~ortmg Well Name: CD4-213 Job Type: DRILLING ORIGINAL ~~ Time Logs _ _-- _ __- -- Date From To Dur S. De th E. De th Phase Code Subcod_e T COM 12/25/2006 16:30 23:45 7.25 0 114 MIRU MOVE MOB P Rigged down and moved from CD4-215 to CD4-213. Ri ed u . 23:45 00:00 0.25 114 114 MIRU MOVE RURD P Nippled up riser. 12/26/2006 00:00 03:30 3.50 0 0 MIRU MOVE RURD P Continue to NU riser - RU and take on s ud mud. 03:30 07:15 3.75 0 0 SURFA DRILL PULD P MU BHA #1. Orient tools and uplink data. 07:15 07:45 0.50 0 0 SURFA DRILL SFTY P Pre spud meeting with rig team. Review wireline and diverterless o erations. 07:45 09:00 1.25 0 0 SURFA DRILL RURD P Fill riser -Check for leaks -Pressure test lines. 09:00 12:00 3.00 0 273 SURFA DRILL DDRL P Spud well at 900 hrs. Drill 12-1/4" hole from 123' to 273' MD ADT 0.99 -ART 0.99 WOB 10/15 RPM 60 GPM 400 @ 680 psi String Wt: PU 100 - SO 100 -Rot 100 Trq on/off btm = 6000/3500 ft/Ibs Ran G ro Surve 12:00 00:00 12.00 273 1,245 SURFA DRILL DDRL P Drill 12-1/4" hole from 273' to 1245' MD 1230' TVD ADT 7.78 -ART 3.28 -AST 4.50 WOB 15/20 RPM 60 GPM 500 @ 1310 psi String Wt: PU 115 - SO 115 -Rot 115 Trq on/off btm = 5000/4000 ft/Ibs Last G ro sunre 531' 12!27/2006 00:00 12:00 12.00 1,245 2,321 SURFA DRILL DDRL P Drill 12-1/4" hole f/1245' t/2321' MD 2107 TVD ADT 7.79 -ART 5.89 -AST 1.9 WOB 25/30 RPM 60 GPM 600 @ 1810 psi String Wt: PU 133 - SO 128 -Rot 132 Tr on/off btm = 7500/6000 fUlbs 12:00 19:15 7.25 2,321 2,723 SURFA DRILL DDRL P Drill 12-1/4" hole f/2321' U2723' MD 2396' TVD ADT 5.92 -ART 5.40 -AST 0.52 WOB 25/30 RPM 60 GPM 600 @ 1980 psi String Wt: PU 135 - SO 130 -Rot 135 Trq on/off btm = 7000/7000 ft/Ibs Encountered tight spot & heavy clays 2500' MD. 19:15 20:15 1.00 2,723 2,723 SURFA DRILL CIRC P Circ BU. Bring Mud wt up to 9.8 ppg. Observe well -static. F~~~ 1 flf 8 • Time Lo s Date_____ From To Dur S _C>e th E._D~th Phase Code Subcode T COM 12/27/2006 20:15 23:00 2.75 2,723 1,650 SURFA DRILL WPRT P Wiper trip pumping out from 2723' to 1650' MD 130 SPM; 550 GPM. 23:00 00:00 1.00 1,650 1,570 SURFA DRILL WPRT P Continue pumping out to HWDP from 1650' to 1570' MD @ 95 SPM; 400 GPM. 12/28/2006 00:00 01:15 1.25 1,570 871 SURFA DRILL WPRT P Continue POOH with pump 60 GPM 400 GPM to 871'. 01:15 02:30 1.25 871 2,630 SURFA DRILL WPRT P RIH to 2,630'. 02:30 03:45 1.25 2,630 2,730 SURFA DRILL CIRC P Wash to 2,723' and circulated hole clean. 03:45 08:45 5.00 2,730 167 SURFA DRILL TRIP P Blew down top drive and POOH on TT from 2,723' to 167'. 08:45 12:00 3.25 167 0 SURFA DRILL PULD P Laid down BHA and flex collars. Cleared floor. 12:00 13:30 1.50 0 0 SURFA CASIN RURD P RU to run casing - LD Drilling Elevs, MU fill up tool -Install casing elev, bails & slipe - RU casing tongs & work lattorm. 13:30 13:45 0.25 0 0 SURFA CASINC SFTY P Pre job safety meeting 13:45 16:30 2.75 0 1,348 SURFA CASINC RNCS P Run 9 5/8" 40# L-80 BTC csg as follows: Float shoe (Ray oil tools silver bullet) - 2 jts csg, Weatherford FC - 68 jts csg. First 4 connections made up with Baker Loc -filled pipe & checked floats. Bowspring tantalizers on jts 1-12 and every other after that. Stop rin son 'ts 1 & 2. 16:30 17:30 1.00 1,348 1,348 SURFA CASINC CIRC P Circulate & Cond thick mud @ 1348'. Cont RIH. 17:30 19:45 2.25 1,348 2,713 SURFA CASINC RNCS P Continue RIH 9-5/8" csg. Land on han er 2713' MD. 19:45 20:15 0.50 2,713 2,713 SURFA CASINC RNCS P LD Fill up tool - PU Cement e ui ment. 20:15 22:00 1.75 2,713 2,713 SURFA CASINC CIRC P Circulate mud from 2 bpm to 7 bpm. 22:00 00:00 2.00 2,713 2,713 SURFA CASINC CIRC NP Continue to circulate - WO Rig trucks to offload & haul fluid to the injection skid. Cold temps causing mechanical difficulties. 12/29/2006 00:00 02:00 2.00 2,713 2,713 SURFA CASINC CIRC NP Circulated and conditioned mud while making enough room in pits for cement returns. Injection skid had canceled Little Red injection without our knowled e. F~age 2 of 8 a • Time Logs Date From Jo Dur S Depth E. De th Phase Code Subcode T_ _COM 12/29/2006 02:00 04:30 2.50 2,713 0 SURFA CEME~ _ DISP P Cement 9 5/8" csg as follows :Rig Pumped 40 bbls Biozan water w/nut plug as marker -Pumped 10 bbls water w/ Dowell -Tested lines to 2500 psi -Pumped 10 bbls water -Dropped btm plug - Pumped 50 bbls MudPush @ 10.5 ppg -Mixed & pumped 276 bbls lead slurry (ASL) @ 10.7 ppg (* Observed nut plug marker @ shakers w/ 272 bbls lead pumped -pumped .down surge can) Pumped 49 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/ 184 bbls 9.7 ppg water base mud -Displaced @ 7.0 bbls/min for first 170 bbls - slowed to 4 bbls/min for last 14 bbls - Bumped plug w/ 1100 psi (pre bump pressure 560 psi) Check float (held OK) CIP @ 04:15 hrs. -Full circulation throughout job w/ 160 bbls 10.7 ppg cmt returns to surface -reciprocated pipe while circulating & through cement job until last 90 bbls of dis lacement. 04:30 05:15 0.75 0 0 SURFA CASIN( DHEQ P Tested casing to 2,500 psi for 30 min. 05:15 06:30 1.25 0 0 SURFA CASIN RURD P Rigged down casing and cement tools. Laid down landin Jt. 06:30 14:30 8.00 0 0 SURFA CASIN NUND P ND Riser - NU BOP -Change out Junk Sub 14:30 19:30 5.00 0 0 SURFA WELC BOPE P Test BOPE Annular 250 / 3000 psi. Lwr & Blind rams, upper rams with 4" - 4.5" - 5". Tested HCR & Man choke, kill choke, Valves 1-16, Auto and manual IBOP, dart & TIW to 250 / 3000 si. 19:30 20:30 1.00 0 0 SURFA DRILL RURD P Blow dwn choke & kill, Install wear rin . PU Bails & Elevators. 20:30 00:00 3.50 0 715 SURFA DRILL PULD P PU BHA #2 for 8-3/4" hole -Orient plug - PU NMFC, Jars, & HWDP to 715'. 12/30/2006 00:00 01:30 1.50 715 2,525 SURFA CEME TRIP P Shallow tested tools and continued RIH to 2,525'. 01:30 03:00 1.50 2,525 2,723 SURFA CEME~ COCF P Washed down and drilled out plugs and shoe track. Cleaned out rathole to 2,723'. 03:00 03:30 0.50 2,723 2,743 SURFA DRILL DDRL P Drill 8-3/4" hole f/2,723' t/2'743' MD 2,409' TVD ADT .25 -ART .25 -AST 0. WOB 5/10 RPM 60 GPM 600 @ 1800 psi String Wt: PU 135 - SO 120 -Rot 130 Tr on/off btm = 7000/5000 fUlbs 03:30 04:00 0.50 2,743 2,743 SURFA DRILL CIRC P CBU. Page 3 oaf ~ ~~ Time Logs i Date From To Dur S De th E. D~th Phase Code Subcode T COM 12/30/2006 04:00 05:15 1.25 2,743 2,743 SURFA CEME~ FIT P Rigged up and performed FIT to 18 PPG EMW. 05:15 12:00 6.75 2,743 3,476 INTRMI DRILL DDRL P Drill 8-3/4" hole f/2,743' t/3,476' MD 2,949' TVD ADT 3.54-ART 3.44-AST 0.1 WOB 10/15 RPM 80 GPM 600 @ 1810 psi String Wt: PU 145 - SO 125 -Rot 133 Tr on/off btm = 8000/6500 ft/Ibs 12:00 18:00 6.00 3,476 4,238 INTRM1 DRILL DDRL P Drill 8-3/4" hole f/3476' t/4238' MD 3507' TVD WOB 16/20 RPM 80 GPM 600 @ 2400 psi String Wt: PU 162 - SO 130 -Rot 145 Tr on/off btm = 8500/8000 ft/Ibs 18:00 19:00 1.00 4,238 4,238 INTRM1 RIGMN' SVRG T Standback 1 stand - CO SVR Sub to re air washout. 19:00 00:00 5.00 4,238 4,645 INTRMI DRILL DDRL P Drill 8-3/4" hole f/4238' t/4645' MD 3807' TVD ADT 6.64 -ART 5.67 -AST 0.97 WOB 15/20 RPM 80 GPM 600 @ 2550 psi String Wt: PU 162 - SO 130 -Rot 145 Tr on/off btm = 8500/8000 fUlbs 12/31/2006 00:00 01:30 1.50 4,645 4,882 INTRM1 DRILL DDRL P Drill 8-3/4" hole f/4645' t/4882' MD 3980' TVD ADT 1.18 -ART 1.18 -AST 0. WOB 15/20 RPM 80 GPM 600 @ 2550 psi String Wt: PU 162 - SO 130 -Rot 145 Tr on/off btm = 8500/8000 ft/Ibs 01:30 04:30 3.00 4,882 4,882 INTRM1 RIGMN' RGRP T IBOP and saver sub washed out. POOH to 4,715' and changed both subs. Tested sub and RIH to 4882'. 04:30 12:00 7.50 4,882 5,504 INTRM1 DRILL DDRL P Drill 8-3/4" hole f/4,882' t/5,504' MD 4432' TVD ADT 1.18 -ART 3.48 -AST 0.75 WOB 15/20 RPM 80 GPM 600 @ 2780 psi String Wt: PU 181 - SO 138 -Rot 155 Tr on/off btm = 10000/8500 ft/Ibs 12:00 14:30 2.50 5,504 5,764 INTRM1 DRILL DDRL P Drill 8-3/4" hole f/5,504' t/5,764' MD 4623' TVD ADT 2.11 -ART 1.74 -AST 0.37 WOB 10/15 RPM 80 GPM 650 @ 2950 psi String Wt: PU 190 - SO 137 -Rot 159 Tr on/off btm = 10500/9000 ft/Ibs 14:30 15:30 1.00 5,764 5,764 INTRMI DRILL CIRC P Circulate & condition mud for short trip - 465 gpm @ 1660 psi, 100 rpm - Wash out in Mud Pump #2 -shut down to troubleshoot. 15:30 20:00 4.50 5,764 2,620 INTRM1 DRILL WPRT P Flow check well -static. POOH on TT from 5764' - 2620' MD. Flow check - static. 20:00 00:00 4.00 2,620 2,620 INTRM1 RIGMN RGRP T Monitor well on TT -Change out fluid end of MP #2. P~qe 4 ~f 3 • • Time Low Date From To Dur S_,_ Depth E. De th Phase Code Subcode T COM 01/01/2007 00:00 02:45 2.75 2,620 2,620 INTRM1 RIGMN' RGRP T Continue CO fluid end of mud pump #2 -monitor well on TT -Pressure test pump to 3500 psi -Circ @ 80 spm, 700 si -Good test. 02:45 05:30 2.75 2,620 5,764 INTRM1 DRILL TRIP P RIH from 2620' to 4524' -Fill pipe and establish circulation -RIH to 5668' - Wash/Ream to btm 5764'. 05:30 06:30 1.00 5,764 5,859 INTRM1 DRILL DDRL P Drill 8-3/4" hole from 5764' - 5859' MD 4893' TVD ADT 0.71 -ART 0.51 -AST - 0.2 WOB 15 RPM 100 GPM 600 @ 2950 psi String wt: PU 190 - SO 140 -Rot 157 Tr on/off btm = 10,000/9,000 ft/Ibs 06:30 07:30 1.00 5,859 5,859 INTRMI RIGMN RGRP T #2 MP Washout, R&R with #1 MP @ 110 SPM, 1730 PSI - Blow do TD. 07:30 10:45 3.25 5,859 2,715 INTRM1 RIGMN RGRP T Flow check well -static - POH on TT to 2715' -Flow check -static. 10:45 17:00 6.25 2,715 2,715 INTRMI RIGMN RGRP T MU TD orient with 450 GPM - 1030 psi. Circ @ reduced rate of 300 gpm to conserve MWD battery -Fix Mud um . 17:00 20:30 3.50 2,715 5,764 INTRM1 RIGMN' RGRP T Blow DN TD -Thaw Iron Roughneck - RIHfrom 2715' to 5764" -Establish circulation -Test #2 MP to 3500 si. 20:30 21:00 0.50 5,764 5,859 INTRM1 RIGMN RGRP T Wash dwn to 5859' - 600 gpm @ 2800 si -That TD Grabs/IBOP. 21:00 00:00 3.00 5,859 6,070 INTRM1 DRILL DDRL P Drill 8-3/4" hole from 5859' - 6070' MD 4848' TVD ADT 1.47 -ART 1.06 -AST - 0.41 WOB 20 RPM 80 GPM 650 @ 3550 psi String wt: PU 192 - SO 142 -Rot 162 Tr on/off btm = 10,000/9,000 ft/Ibs 01/02/2007 00:00 12:00 12.00 6,070 7,002 INTRMI DRILL DDRL P Drill 8 3/4" hole w/motor f/ 6070' to 7002' MD - 5558' TVD ADT - 7.52 hrs = AST 4.42 hrs ART - 3.08 hrs ECD = 10.43 ppg WOB 15/20 k RPM 80 GPM 600 @ 3120 psi String wt. PU 180 SO 160 Rot 171 Tor ue on/off btm - 10,000/8,000 ft/Ibs 12:00 00:00 12.00 7,002 7,724 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/motor f/ 7002' to 7724' MD - 6046' TVD ADT - 8.20 hrs = AST 7.78 hrs ART - 0.42 hrs ECD = 102 ppg WOB 12/25 k RPM 80 GPM 500 @ 2370 psi String wt. PU 195 - SO 160 -Rot 180 Tor ue on/off btm -11,000/9,000 ftllbs t'~ge 5 of 3 ~~ ~; Time Logs __ _ _ _ Date From To Dur S De th E. De th Phase Code Subcode T COM 01/03/2007 00:00 12:00 12.00 7,724 8,001 INTRM1 DRILL DDRL P Drill 8 3/4" hole w! motor f/ 7724' to 8001' MD 6148' TVD ADT - 9.07 hrs. =ART .8 hrs AST 8.27 hrs -ECD 10.04 ppg WOB 15/20 k RPM 80 GPM 550 @ 2350 psi String wt. PU 200 SO 157 Rot 180 Torque on/off btm. - 11,000/10,000 fUlbs 12:00 17:30 5.50 8,001 8,305 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ motor f/ 8001' to 8305' MD 6201' TVD ADT - 4.19 hrs. ART - 0.97 hrs AST - 3.22 hrs ECD 10.36 ppg WOB 10/15 k RPM 80 GPM 650 @ 3350 psi String wt. PU 190 SO 155 Rot 175 Tor ue on/off btm. - 11,000/9,500 fUlbs 17:30 19:30 2.00 8,305 8,049 INTRM1 DRILL CIRC P Circulate 3x BU @ 650 gpm, 70 RPM, 3170 psi. -Standing back 1 std DP eve 30 mins. to 8049' MD. 19:30 22:30 3.00 8,049 6,907 INTRM1 DRILL WPRT P Flow check static -Wiper trip with pump from 8049' - 6907'. 500 GPM, 70 RPM, 1910 psi -Flow check static - Blow Down TD. 22:30 23:00 0.50 6,907 8,240 INTRMI DRILL WPRT P RIH from 6907' - 8240'. Hole in good condition 23:00 00:00 1.00 8,305 8,035 INTRMI DRILL CIRC P Precautionary wash f/ 8240' to 8305' - Circand Condition for tri out. 01/04/2007 00:00 00:15 0.25 8,035 8,035 INTRM1 DRILL CIRC P Continue circulating hole @ 650 GPM - 3280psi - 70 rpm. Fill pipe with Wellbore Strengthing pill and casing runnin ills. Flow check -static. 00:15 03:00 2.75 8,035. 6,431 INTRM1 DRILL TRIP P POOH to 6431' spotting 35 BBLS of WBS pill and 135 bbls of lubricating pill @ 3 bpm and 350 psi. Flow check static. Blow dwn TD. 03:00 09:00 6.00 6,431 262 INTRM1 DRILL TRIP P Zero TT, POOH 10 stands on TT from 6431' - 5478'. Flow check static. Hole taking proper fill and no tight spots observed. Pump 40 bbls dry job. Chase with 8 bbls mud. SD pumps, blow down TD. Continue POOH on TT t/HWDP. (Flow check static at shoe). Cont POOH & LD BHA to 262'. 09:00 09:30 0.50 262 0 INTRM1 DRILL PULD P LD NMFC's. 09:30 12:00 2.50 0 0 INTRM1 DRILL PULD P LD BHA -Download MWD Data - LD MWD tools. Clear Ri Floor. 12:00 14:30 2.50 INTRM1 CASIN OTHR P Pull wear bushing. and install test plug. CO upper pipe rams to 7"and test to 250 / 5000 psi. Pull test plug and install thin wall wear rin . 14:30 15:30 1.00 INTRM1 CASIN( RURD P RU to run 7" casing. RU scaffolding & tongs, CO elevators & slips. PU Franks fill u Tool. PJSM. Page 6 of ~ ./ ~~ Time Logs D e From To D_ur S De th E. De th Phase Code Subcode T COM 01/05/2007 07:45 10:15 2.50 0 0 INTRM1 CEME~ RURD P _ Blow down cement lines - RD lines & head - LD landing jt. -Pull thin wall wear bushing -Set 7" X 9 5/8" pack Off & test to 5000 si 10:15 11:15 1.00 0 0 INTRM1 CASIN OTHR P Change top pipe rams f/ 7" to 3 1/2" X 6" VBR -Test to 250 & 5000 si 11:15 13:00 1.75 0 0 INTRMI RPCOti RURD X Clear rig floor. Pick up and rig up 4-1/2" Tb a ui ment -kill strin . 13:00 16:00 3.00 0 2,309 INTRMI RPCOh RCST X RIH with 4-1/2" 12.6# L-80 IBTM tubing (kill string) to 2309' MD as follows: 4-1/2" WL entry guide, 56 jts total - PU FMC 4-1/2" Gen V Tbg Hanger w/pup -Land tbg in wellhead wMIEG 2307' MD. 16:00 17:00 1.00 2,309 2,309 INTRM1 RPCOh PULD P RI LDS -Install two way check and test han er seals to 5000 si. 17:00 17:30 0.50 0 0 INTRM1 RPCOb RURD P LD Tbg equipment, clear rig floor. 17:30 20:30 3.00 0 0 INTRM1 RPCO NUND P ND BOPE. NU Tree and test to 5000 si. Pull 2 wa check. 20:30 22:30 2.00 0 0 INTRM1 RPCO CIRC P PJSM for Diesel displace. RU to pump down the tbg taking returns out the 4-1/2" x 7" annulus to the pits. Fluid pack lines and PT. Displace brine with a total of 68 bbls diesel to freeze protect the tbg and annulus. Blow down lines and RD. 22:30 00:00 1.50 0 0 INTRM1 RPCOh OTHR P FMC set BPV to secure well. RU to la down i e in the i e shed. 01/06/2007 00:00 00:30 0.50 0 0 INTRM1 RPCO OTHR X Finish securing well -Clean up cellar area -set mouse hole 00:30 12:00 11.50 0 0 INTRM1 DRILL PULD X LD 4" drill pipe f! derrick via mouse hole for ri move 91 stds 12:00 16:30 4.50 0 0 INTRM1 DRILL PULD X LD 5" HW & DP using the mouse hole for ri move. 273 'ts total 16:30 18:00 1.50 0 0 INTRMI DRILL OTHR X Service and inspect top drive. 18:00 19:00 1.00 0 0 INTRM1 RPCOh OTHR X PJSM; Cut and slip drilling line. 19:00 00:00 5.00 0 0 INTRM1 RPCO OTHR X Prep For rig move. Release rig @ 2359hrs. Page 8 of ~ ConocoPhilli S Casing Detail 9 5/8" Surface Casing • Well: CD4-213 Date: 12/1 /2005 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.67 FMC Gen V Hanger 2.22 36.67 Jts 3 to 70 68 Jts 9-5/8" 40# L-80 BTC Csg 2594.19 38.89 HOWCO Float Collar 1.16 2633.08 Jts 1 to 2 2 Jts 9-5/8" 40# L-80 BTC Csg 76.63 2634.24 Ray Oil Tools "Silver Bullet" Float Shoe 2.25 2710.87 2713.12 TD 12 1/4" Surface Hole 2723.12 TOTAL BOWSPRING CENTRALIZERS -40 1 per jt on Jt #1 - #12 (stop ring on Jt #1 ~ 2 ) and over collars on jts# 14, 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38, 40, 42, 44, 46, 48, 50, 52, 54, 56, 58, 60, 62 64, 66, 68. 78 joints in the pipe shed. Run 70 joints - 8 joints stay out Casing shoe Q 2713.55' MD/ 2389' TVD Hole TD 2723' MD 2396' TVD ~r~ COCA ~p r ~ ^J d-~c ~ ~. ~ -~ Use Best-o-Life 2000 pipe dope MU torgue ^- 8600 ft/Ibs Remarks: Up Wt - 170 k Dn Wt - 130k Block Wt - 75k Supervisor: Hill/VVoods ~ ~ ConocoPhilli s p CASING TALLY PAGE: 1 of 2 WELL NUMBER: CD4-213 RIG: Doyon 19 CASING DESCRIPTION: 9 5/8", 40# L-80 BTC DATE: 12/01 /05 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 36.94 26 39.09 51 36.91 76 36.49 101 126 151 176 2 39.69 27 39.07 52 39.79 77 36.55 102 127 152 177 3 39.65 28 38.97 53 39.51 78 36.05 103 128 153 178 4 36.52 29 38.61 54 38.79 79 104 129 154 179 5 38.01 30 39.01 55 38.19 80 105 130 155 180 6 38.82 31 39.57 56 36.66 81 106 131 156 181 7 36.35 32 36.15 57 37.79 82 107 132 157 182 8 38.23 33 38.80 58 37.95 83 108 133 158 183 9 39.52 34 39.53 59 35.37 84 - 109 134 159 184 10 39.81 35 40.50 60 37.93 85 - 110 135 160 185 11 37.66 36 37.22 61 37.31 86 - 111 136 161 186 12 39.03 37 38.39 62 38.12 87 - 112 137 162 187 13 39.27 38 39.21 63 38.80 88 - 113 138 163 188 14 35.17 39 38.45 64 38.69 89 - 114 139 164 189 15 38.40 40 39.27 65 36.78 90 - 115 140 165 190 16 36.94 41 38.43 66 38.35 91 116 141 166 191 17 39.19 42 39.22 67 34.46 92 117 142 167 192 18 39.28 43 38.79 68 37.42 93 118 143 168 193 19 37.40 44 36.72 69 38.64 94 119 144 169 194 20 38.51 45 37.21 70 39.23 95 120 145 170 195 21 38.87 46 36.18 71 37.40 96 121 146 171 196 22 38.85 47 36.24 72 38.80 97 122 147 172 197 23 38.48 48 38.84 73 36.20 98 123 148 173 198 24 38.37 49 36.32 74 38.75 99 124 149 174 199 25 37.00 50 38.38 75 37.21 100 125 150 175 200 Tot 955.96 Tot 958.17 Tot 945.05 Tot 109.09 Tot TOTAL LENGTH THIS PAGE = 2968.27 DIRECTIONS: TOTAL JOINTS THIS PAGE = 78 FLOAT SHOE Tot Tot Tot 2.25 FLOAT COLLAR 1.16 HANGER 2.22 RKB 36.67 :' ~ Cement Detail Report CD4-213 i, Surface Casing Cement Primary Job Type Job Category AFE / RFE / Maint.# Actual Start Date Spud / KO Date End Date DRILLING ORIGINAL DRILLING 10151446 12/25/2006 12/26/2006 1/7/2007 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 12/29/2006 02:50 12/29/2006 04:15 CD4-213 Comment Cement Stages - _ _ __ - _ _ - Sta a#1 Description Objective Top (ftK6) Bottom (ftKB) Full Return? Cmnt Rtrn (.. Top Plug? Btm Plug? Surface Casing Cement 36.7 2,713.1 No Yes Yes Q (start) (bbl/min) Q (end) (bbl/min) O (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? _ Stroke (ft) Rotated? Pipe RPM (rpm) 7 4 6 560.0 1,100.0 Yes 20.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives -- - - _ _ _-_ _ - - _- Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Cfass Volume Pumped (bbl) Lead Cement 36.7 2,213.1 349 G 276.0 Yield (ft'/sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs} CmprStr 7 (psi) 4.45 20.77 Additives Additive Type Concentration Conc Unit label Fluid __ _ - - _ - -- --- _ _ _ Fluid Type Fluid Description _ - Estimated Top (ftK6) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 2,213.1 2,713.1 234 G 49.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 7 (psi) 1.17 5.10 Additives Additive Type Concentration Conc Unit label Page 1/3 Report Printed: 7/27/2007 Security Level: Development Daily Drilling Report CD4-213 Report Number: 5 zig: DOYON 19 Report Date: 12/29/2006 NetworkllD# T t I ~FE~'o~J,. 10151446 6,930,090.00 Wellbore Well Type Field Name Original Spud Date DFS (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) CD4-213 Development NANUO 12/26/2006 3.63 2,723.0 2,723.0 0.00 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 5,629.79 49,876.81 178,729.14 1,093,107.61 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Surface, 2,713.1ftKB Ops and Depth ~ Morning Report 24hr Forecast Drilling 8-314" @ 2743' Drill 8-3/4" intermediate Last 24hr Summary Cement 9-5/8" Casing -Test Casing to 2500 psi - ND Riser, NU BOP -Test BOPE - PU BHA #2. General Remarks Weather Head Count Cold 47.0 - - - culJpeNI50f T ~.1 F Larry Hill, Rig Supervisor Rig Supervisor Nina Woods, Rig Supervisor Rig Supervisor Time Log -- - _ _ Start Or; Dur i ina ' Depth Start Dec 67 Li ~ ~' s (ftKB) I~.Y.HI Operation Tin lime ~, Pha~:e Op Code ,7~SuP ~,~ac- ~ N-~ _'~ ^blCode TiolCla s _ _ 00:00 02:00 2.00 SURFAC CASING CIRC NP Operational Human 2,713.01 2,713.0 Circulated and conditioned mud while Error making enough room in pits for cement returns. Injection skid had canceled Little Red injection without our knowledge. 02:00 04:30 2.50 SURFAC CEMENT DISP P 2,713.0 0.0 Cement 9 5/8" csg as follows :Rig Pumped 40 bbls Biozan water w/ nut plug as marker -Pumped 10 bbls water w/ Dowell -Tested lines to 2500 psi - Pumped 10 bbls water -Dropped btm plug - Pumped 50 bbls MudPush @ 10.5 ppg -Mixed & pumped 276 bbls lead slurry (ASL) @ 10.7 ppg (" Observed nut plug marker @ shakers w/ 272 bbls lead pumped -pumped down surge can) Pumped 49 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/ 184 bbls 9.7 ppg water base mud -Displaced @ 7.0 bbls/min for first 170 bbls -slowed to 4 bbls/min for last 14 bbls -Bumped plug w/ 1100 psi (pre bump pressure 560 psi) Check float (held OK) CIP @ 04:15 hrs. - Fup circulati¢r- job. w! 160 bbls 10.7 ppg cmt'returns to surface - reciprocated pipe while circulating & through Cerr~ent job until last 90 bbls of displacement. 04:30 05:15 0.75 SURFAC CASING DHEQ P 0.0 0.0 Tested casing to 2,500 psi for 30 min. 05:15 06:30 1.25 SURFAC CASING RURD P 0.0 0.0 Rigged down casing and cement tools. Laid down landing Jt. 06:30 14:30 8.00 SURFAC CASING NUND P 0.0 0.0 ND Riser - NU BOP -Change out Junk Sub 14:30 19:30 5.00 SURFAC WELCTL BOPE P 0.0 0.0 Test BOPE Annular 250 / 3000 psi. Lwr & Blind rams, upper rams with 4" - 4.5" - 5". Tested HCR & Man choke, kill choke, Valves 1-16, Auto and manual IBOP, dart & TIW to 250 / 3000 psi. Latest BOP Test Data - _ - - o;,~r 12/28/2006 250/5000 Page 1/2 Report Printed: 7/27/2007 Security Level: Development tig: DOYON 19 __ ___-- -- ---- -- Time Log Trn~ i Tire ~ i ~ ~ ' F Op Code Or Daily Drilling Report CD4-213 19:3020:301 1.OO~SURFAC (DRILL RURD T~r•,,e~ --~ r r,-T I t Lo~~~~ r~~~ C, , P I ~ Report Number: 5 Report Date: 12/29/2006 ~~, Dept}' ,~... ~ ~,r, F:,d-,~ - _. I ~NhF~ ~iKR! .~,,arduon 0.0 0.0 Blow dwn choke & kill, Install wear ring. IPU Bails & Elevators. 20:30 00:00 3.50 SURFAC DRILL PULD P 0.0 715.0 PU BHA #2 for 8-3/4" hole -Orient plug - PU NMFC, Jars, & HWDP to 715'. Mud Cher.k Data I ~ ~ YP Cal 3sI (10s '. =1 (10m) Gel (30m) HTHP Filt Drm i T np I ~ .;r.r. Typo Depth iftF F Dens - Vis (slgt) t y+. PV Calc (cp) Qbf/10011 Ti~100ft•1 '~ It,ri1~~JOft') - {IbH100fl~) MBT ~~brLal) (mL130min) - p}{ h Spud 2,713.0 9.70 60 28.0 16.000 6.0 _-- 22.0 58.000 ---- ---- 30.0 - -- 9.3 6.6 Wellbores - - Wellbore Name ----_ Wellbore APIIUWI CD4-213 501032054 000 Sr~ctiorr Size (in) Act Top ( ftK6) nst Btm (fitKBj Start Date End Date COND1 16 114.0 12/25/2006 PROD1 6 1/8 SURFAC 12 1 /4 114.0 2,723.0 12/26!2006 12/27/2006 INTRM1 8 3/4 2,723.0 8,305.0 12/30/2006 1/3/2007 Cement Surface Casin Cement -Started 12/29/2006 Type Wellbore Cemented String Cement Evaluation Results casing CD4-213 Surface, 2,713.1ftKB 160 Bbls ro surface. Stg No. Description Top (ftK6) Bottom (ftK6) Q (end) (bbl/... P (final) (psi) 1 Surface Casing Cement 36.7 2,713.1 4 560.0 _ ___ Fluid Class Amount (sacks) V {bbl) Density (iblgap Yield (ft'lsack) - Est T op (ftKB} Est Bim (ftKB) Lead Cement G 349 276.0 4.45 36.7 2,213.1 Tail Cement G 234 49.0 1.17 2,213.1 2,713.1 Page 2/2 Report Printed: 7/27/2007 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4-213 Rig: Doyon 19 Date: 12/30/2006 Drilling Supervisor: L. Hill / N. Woods Pump used: #2 Mud-Pump _ ~ Volume Input Volume/Stroke Pump Rate: strokes ~ 0.1000 Bbls/strk ~ I 8.0 strk/min ~ Type of Test: OpenholeTest SOT/Frr ~ Pumping down annulus and DP. ~ Casin Test Pressure In tegrity Test Hole Size: s-3/4" ~ Casin Shoe Depth Hole Depth Pum pin Shut-in Pumping Shut-in RKB-CHF: 36.7 Ft 2,713 Ft-MD 2,389 Ft-TVD 2,743 Ft-MD 2,411 Ft-TVD Strks psi Min psi Strks psi Min psi Casing Size and Description: 9-5/s" 4o#/Ft L-8o BTC ' ~ 0 0 0 2500 1 60 0 1070 Casin Test Pressure Int e rit Test 2 100 1 2500 2 100 0.25 1060 Mud Weight: 9.7 ppg Mud Weight: 9.4 ppg 4 250 2 2500 3 160 0.5 1040 Mud 10 min Gel: 31.0 Lb/100 Ft2 Mud 10 min Gel: 40.0 Lb/100 Ft2 6 500 3 2500 4 260 1 1020 Test Pressure: 2,500 psi Rotating Weight: 135,000 Lbs 8 750 4 2500 5 360 1.5 1 c)O: Rotating Weight: 75,000 Lbs Blocks/Top Drive Weight: 75,000 Lbs 10 900 5 2500 6 480 2 1000 Blocks/Top Drive Weight: 75,000 Lbs Desired PIT EMW: 18.0 ppg 12 1050 6 2500 7 580 2.5 990 Estimates for Test: 1.9 bbls Estimates for Test: 1068 psi 0.7 bbls 14 1250 7 2500 8 690 3 980 - - . -- ~ ~ 16 1400 8 2500 9 780 3.5 980 EMW =Leak-off Pressure + Mud Weight = 1080 4 PIT 15 Second 18 1600 9 2500 10 860 4 980 + 0.052 x TVD 0.052 x 2389' Shut-in Pressure, psi 20 1800 10 2500 11 920 4.5 970 713 Ft-MD (2389 Ft-ND) = 18.1 EMW at 2 loco 22 2000 15 2500 12 980 5 960 _ . sooo - Lost 0 psi during test, held 24 2200 20 2500 13 1040 5.5 960 __ _ - _ 100 % of te st pre ssure. 26 2400 25 2500 14 1080 6 960 -- -- 27 2500 30 2500 6.5 960 z5oo - 7 950 - 7.5 950 8 940 - zooo - 8 5 940 - - . ~ - - 9 940 ~ _ 9.5 940 ~ 1500 w 10 94 ~ - - - a 1000 _ _ _ - -- - ,a - - - ~ - - -- ~ - - ~ - -- - 0 2 3 0 5 1 0 1 5 2 0 2 5 3 0 0 CASING TEST 1 Barrels f-L EAK-OFF TEST S hut-I O PI n tim T Poin e, M t inute s Volume PUm ed Volume Bled Back Volume PUm ed Volume Bled Back s s s s Comments: Casing tested after bumping plugs on cement job. i ~ Conocol~i~~i S Casing Detail 7" Casin_g Well: CD4-213 Date: 1 /4/2007 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Lower lock down 34.42 FMC Gen V Hanger 2.62 34.42 Jts 3 to 193 191 Jts 7 " 26# L-80 BTCM Csg 8170.94 37.04 Halliburton Float Collar 1.01 8207.98 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 84.27 8208.99 Ray Oil Tools Float Shoe 2:08 8293.26 7" Shoe @ 8295.34 TD 8 3/4" Hole 8305.00 8 3/4" Hole TD @8305' MD /6201 'TVD 7" Shoe @ 8295.34' MD / 6200' TVD Total Centralizers: 56 Centralizer one per jt on jts # 1-14 Centralizers jts # 71 - 78 (200' Above/below K2) Centralizers jts # 128-130 (Above/Below 9-5/8" shoe) Centralizer one per jt on every other joint from#132-190&191 Top Nanuq - 8210' MD - 6192' TVD K2 -Top 5040' MD 4095 TVD Base 5080'MD 4124'TVD 203 joints in shed - 193 total jts. to run Last 10 jts. out Use Run & Seal i e do e Average MU torque 6500 ft/Ibs Remarks: Up Wt -275 k DnWt-150k Block Wt - 75k Supervisor: D. Mickey / N. Woods ConocoPh i l l i s p CASING TALLY PAGE: 1 of 2 WELL NUMBER: CD4-213 RIG: Doyon 19 TUBING DESCRIPTION: 7", 26# L-80 BTCM DATE: 01/04/07 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 43.23 26 43.94 51 43.47 76 42.76 101 41.21 126 43.46 151 42.65 41.95 2 41.04 27 41.89 52 43.51 77 43.66 102 43.04 127 42.44 43.38 177 43.52 3 42.98 28 43.45 53 43.45 78 43.11 103 41.90 128 42.64 153 42.20 43.34 4 42.84 29 43.54 54 43.48 79 40.19 104 43.51 129 43.52 44.07 179 43.50 5 43.49 30 43.03 55 42.56 80 43.48 105 43.17 130 43.53 155 43.51 43.38 6 41.06 31 43.50 56 43.12 81 43.59 106 42.28 131 43.23 43.60 181 43.39 7 43.45 32 43.51 57 42.64 82 43.39 107 42.08 ~ 40.30 157 42.24 37.19 8 43.42 33 42.28 58 42.69 83 43.17 108 43.60 133 41.98 42.29 183 43.50 9 43.05 34 42.22 59 42.90 84 43.45 109 41.85 43.04 159 43.58 43.08 10 42.87 35 43.40 60 43.52 85 43.06 110 43.55 135 43.09 41.63 185 42.54 11 42.04 36 43.51 61 43.33 86 41.99 111 43.31 43.06 161 43.46 42.44 12 42.38 37 43.49 62 41.72 87 43.10 112 43.16 137 43.37 43.45 187 43.46 13 43.00 38 43.22 63 41.65 88 41.38 113 43.64 42.59 163 43.37 42.65 14 40.09 39 42.10 64 43.81 89 42.13 114 41.98 139 40.78 ~ 41.99 189 43.20 15 42.60 40 43.35 65 43.39 90 40.13 115 42.22 41.97 165 43.40 190 42.19 16 43.44 41 42.90 66 42.58 91 43.34 116 43.35 141 42.48 166 41.05 191 43.43 17 42.97 42 42.12 67 37.23 92 43.09 117 42.18 43.58 167 43.35 192 42.93 18 43.48 43 42.81 68 41.44 93 42.69 118 41.72 143 43.39 = 42.36 193 43.18 19 43.14 44 39.58 69 43.30 94 43.55 119 43.49 42.92 169 43.35 194 4^~`' 20 43.01 45 43.59 70 41.52 95 43.51 120 43.59 145 43.38 43.39 195 43;~ 21 43.50 46 43.42 71 42.18 96 43.36 121 43.58 43.51 171 41.71 196 43-5.1- 22 43.33 47 43.62 72 43.33 97 43.38 122 43.59 147 43.39 42.28 197 41 ~92 23 43.21 48 37.60 73 43.39 98 43.54 123 43.49 41.38 173 42.32 198 4344 24 41.99 49 43.49 74 43.16 99 43.51 124 43.36 149 42.80 174 43.24 199 434 25 42.50 50 43.35 43.14 100 43.57 125 42.56 150 42.70 175 42.87 200 4348 Tot 1068.11 Tot 1068.91 Tot 1066.51 Tot 1072.13 Tot 1071.41 Tot 1068.53 Tot 1070.74 Tot 1068.70 TOTAL LENGTH THIS PAGE = 8555.04 DIRECTIONS: TOTAL JOINTS THIS PAGE = 200 FLOAT SHOE 2.1 FLOAT COLLAR 1 HANGER 2.6 RKB 34 ConocoPhilli s p CASING TALLY PAGE: 2 of 2 WELL NUMBER: CD4-213 RIG: Doyon 19 TUBING DESCRIPTION: 7", 26# L-80 BTCM DATE: 01 /04/07 Column 9 Column 10 Column 11 Column 12 Column 13 Column 14 Column 15 Column 16 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 201 4~ 226 251 276 301 326 351 376 202 427 227 252 277 302 327 352 377 203 43~ 228 253 278 303 328 353 378 204 229 254 279 304 329 354 379 205 230 255 280 305 330 355 380 206 231 256 281 306 331 356 381 207 232 257 282 307 332 357 382 208 233 258 283 308 333 358 383 209 234 259 284 309 334 359 384 210 235 260 285 310 335 360 385 211 236 261 286 311 336 361 386 212 237 262 287 312 337 362 387 213 238 263 288 313 338 363 388 214 239 264 289 314 339 364 389 215 240 265 290 315 340 365 390 216 241 266 291 316 341 366 391 217 242 267 292 317 342 367 392 218 243 268 293 318 343 368 393 219 244 269 294 319 344 369 394 220 245 270 295 320 345 370 395 221 246 271 296 321 346 371 396 222 247 272 297 322 347 372 397 223 248 273 298 323 348 373 398 224 249 274 299 324 349 374 399 225 250 275 300 325 350 375 400 Tot 127.11 Tot Tot TOTAL LENGTH THIS PAGE _ TOTAL LENGTH = TOTAL JOINTS THIS PAGE _ TOTAL JOINTS = AVERAGE JT = Tot Tot Tot Tot i of 127.11 8682.15 DIRECTIONS: 3.00 203.00 42.77 l J ~ Cement Detail Report CD4-213 Intermediate Casing Cement Primary Job Type Job Category AFE / RFE I Maint.# Actual Start Date Spud / KO Date End Date DRILLING ORIGINAL DRILLING 10151446 12/25/2006 12/26/2006 1/7/2007 - Cement Details - - -- --- _ __ Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 1/5/2007 04:30 1/5/2007 07:00 CD4-213 Comment - ,Cement Stages - _ - - - 'Stage # 1 Description Objective ___ ___ Top (ftKB) Bottom (ftKB Full Return? Cmnt Rtm (... Top Piug? Btm Plug? Intermediate Casing 4,540.0 8,295.0 Yes 0.0 Yes Yes Cement O (start) (bbl/min) Q (end) (bbl/min) O (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 4 7 1,020.0 1,500.0 Yes 25.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB ^ Drill Out Diameter (in) Comment Cement Fluids & Additives - Fluid r-- --- _ __ Fluid Type Fluid Description -- - Estimated Top (ftK6) Est Btm (ftKB) Amount (sacks) _ - -- - Class Volume Pumped (bbl) Lead Cement 4,540.0 6,741.0 187 Litecrete 87.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 3.35 11.22 11.00 Additives Additive Type Concentration Conc Unit label Fluid - - -- - Fluid Type Fluid Description - __ Estimated Top (ftK6) Est Btm (ftKB) Amount (sacks) Glass Volume Pumped (bbq Lead Cement 6,741.0 8,295.0 287 G 64.0 Yield (ft /sack) Mix H2O Ratio (ga l/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.09 15.80 Additives Additive Type Concentration Conc Unit label Page 1/3 Report Printed: 7/27/2007 n Security Level: Development Daily Drilling Report CD4-213. .T~- - Report Number: 12 Rig: DOYON 19 Report Date: 1/5/2007 - __ -- - _ -- - - ---- _- 10151446 6,930,090.00 Wellbore Well Type Field Name Original Spud Date DFS (days) Depth Start. (ftKB) Depth End (ftKB) Depth Progress (ft) CD4-213 Development NANUQ 12!26/2006 10.63 8,305.0 8,305.0 0.00 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 2,317.47 180,984.70 485,062.82 2,678,324.85 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Intermediate, 8,295.OftKB Ops and Depth ~ Morning Report 24hr Forecast Lay Down DP from Pipe Shed LD DP, Prep rig to move. Last 24hr Summary Run 7" csg to 8295' MD -Cement casing and PT to 3500 psi -Run 4-1/2" kill string to 2309' MD -FIT to 21.2 ppg - ND BOPE - NU Tree & test to 5000 psi - FP Tbg and annulus w/diesel -Set BPV to secure. General Remarks Weather Head Count -24, SE @ 3 mph 46.0 - -- - -- Supervisui - Title Don Mickey, Rig Supervisor Rig Supervisor Nina Woods, Rig Supervisor - Rig Supervisor __ Time Log . - - - -- , ~ SY 1 Fnd Dur : ; , Tine C F I '.art C ~ 1 F i Time pica n~s~ P ,.- j ~~~;~.~~de _FSut,o~~e PN-T TrbiCode Trb'. .la.s '. F.E~~ FR! ~>~ :r~iian __... I. 00:00 01:15 1.25 INTRMI CASING CIRC P 6,847.0 6,847.0 Break Circula5on -Stage pump up to 5 bbls/min -Circ btms up + 01:15 02:45 1.50 INTRM1 CASING RNCS P 6,847.0 8,295.0 Continue Running 7" 26# L-80 BTCM f/6847' to 8258' MD - 193 jts total - PU FMC fluted hanger & landing jt. -Land casing in wellhead w/ Shoe @ 8295' & FC @ 8207' 02:45 03:15 0.50 INTRM1 CASING RURD P 8,295.0 8,295.0 LD fill up tool &csg spider -Blow down TD - RU cmt head & lines 03:15 04:30 1.25 INTRMI CEMENT CIRC P 8,295.0 8,295.0 Establish circ @ 2 bbls/min @ 420 psi - Stage pump up to 6 bbls/min @ 460 PSI - Circ & condition for cmt job PU wt 265 SO wt - 155 04:30 07:00 2.50 INTRM1 CEMENT DISP P 8,295.0 8,295.0 Held PJSM -Flush mud pumps w/ brine Cement 7" csg as follows: Pumped 10 bbls CW-100 -Pressure test lines to 3850 psi -Pumped 10 bbls CW-100 - Mixed & pumped 30 bbls 10.5 ppg MudPush @ 4 bbls/min @ 280 psi - Dropped btm plug -Mixed & Pumped 87 bbls 11.0 ppg Lead slurry (LiteCrete) @ 6 bbls/min @ 430 psi followed by 64 bbl 15.8 ppg tail slurry (Class G w/ additives) @ 5 bbls/min @ 200 psi -Dropped top plug w/ 20 bbls water f/ Dowell - Switched over to rig pumps & displaced cmt w/ 294 bbls 9.2 ppg brine @ 7 bbls /min for 230 bbls @ 720 psi -slowed pump to 5 bbls/min for next 20 bbls @ 730 psi -slowed pumps to 4 bbls/min for next 20 bbls @ 850 psi -slowed pumps to 3.5 bbls for last 24 bbls @ 1020 psi pre bump pressure -Bumped plug w/1500 psi -Bleed off pressure & checked floats - OK Full circulation throughout job - Recip. pipe for first 170 bbls of displacement - CIP @ 0700 hrs Latest BOP Test Data - -- - -- - -- - - -- I_ ,-,, Comment Page 1/2 Report Printed: 7l27/2007I Security Level: Development Daily Drilling Report CD4-213 ~ Report Number: 12 Rig : DOYON - - 19 - - -- Report Date: 1/5/2007 - - Time Lo g _. - -- - -~ __. - ---- - ,.-.- Sta ~ C)..~ ~---.. _ _ - ~ _ _ - _ Ti i e TC I tan i ` D t~. Ei d ~ ~irc I i~~~c Iii) Fhase ~, ,; G ode p ' O Su`-~oc,a F N t 1 t Code TrblGass ~F~, L aoeraticn ~H' ' -- - ----- - - 07:00 07:45 0.75 INTRMI - ~ CEMENT - - - OTHR P 8,295.0 -- -- 8,295.0 RU & test 7" csg to 3500 psi for 30 mins. - RD 07:45 10:15 2.50 INTRMI CEMENT RURD P 0.0 0.0 Blow down cement lines - RD lines & head - LD landing jt. -Pull thin wall wear bushing -Set 7" X 9 5/8" pack Off & test to 5000 psi 10:15 11:15 1.00 INTRM1 CASING OTHR P 0.0 0.0 Change top pipe rams f/ 7" to 3 1/2" X 6" VBR -Test to 250 & 5000 psi 11:15 13:00 1.75 INTRM1 RPCOMP RURD X 0.0 0.0 Clear rig floor. Pick up and rig up 4-1 /2" Tbg equipment -kill string. 13:00 16:00 3.00 INTRMI RPCOMP RCST X 0.0 2,309.0 RIH with 4-1/2" 12.6# L-80 IBTM tubing (kill string) to 2309' MD as follows: 4-1/2" WL entry guide, 56 jts total - PU FMC 4-1/2" Gen V Tbg Hanger w/pup -Land tbg in wellhead w/WEG @ 2307' MD. 16:00 17:00 1.00 INTRMI RPCOMP PULD P 2,309.0 2,309.0 RI LDS -Install two way check and test hanger seals to 5000 psi. 17:00 17:30 0.50 INTRMI RPCOMP RURD P 0.0 0.0 LD Tbg equipment, clear rig floor. 17:30 20:30 3.00 INTRM1 RPCOMP NUND P 0.0 0.0 ND ROPE. NU Tree and test to 5000 psi. Pull 2 way check. 20:30 22:30 2.00 INTRM1 RPCOMP CIRC P 0.0 0.0 PJSM for Diesel displace. RU to pump down the tbg taking returns out the 4-1/2" x 7" annulus to the pits. Fluid pack lines and PT. Displace brine with a total of 68 bbls diesel to freeze protect the tbg and annulus. Blow down lines and RD. 22:30 00:00 1.50 INTRMI RPCOMP OTHR P 0.0 0.0 FMC set BPV to secure well. RU to lay down pipe in the pipe shed. Mud Check Data ~, YP Czl~ 3el (10s; o~i ' gin; Gel (3~m) HTHP Fd[ Uci~s i, Tmp ~~ h ~ :or t Type Depth (fiFB '~ Guns i lt~~a~j ~bi i~q--~' PV GIs ~,spi Iuf:~~~CHt; ~'~bN100ft°~ ilfl~~ft'1 rl'~f1~00ft'j MBd (JbJbbl) rL :min ~ ohl _.. _'°F 1_ -- KCL Brine 9.20 - Weflbores Wellbore Nam _ e Wellbore APIIUWI CD4-213 501032054000 - - - - -- se lio~ Size(tnl ActT~pfflk"K~ A~~tCr ,nKRi Start Date EndDaiE~ COND1 PROD1 16 6 1/8 114.0 12/25!2006 SURFAC 12 1 /4 114.0 2,723.0 12/26/2006 12/27/2006 INTRM1 - - -- 8 3/4 2,723.0 8.305.0 12/30/2006 1/3/2007 ___ !Cement _ -- - - - -- - Intermediate Casin Cement -Started 1/5/2007 Type Wellbore Cemented String Cement Evaluation Results casing CD4-213 Intermediate, 8,295.OftK6 Stg No. Description Top (ftKB) Bottom (ftKB) O (end) (bbl/... P (final) (psi) 1 Intermediate Casing Cement 4,540.0 8,295.0 4 1,020.0 Flui Lead Cement d l;las, ~ Ai inr Litecrete s: acs) V (bell Density Qblgap Yield (ft ::.; Cs.. 1 s 187 87.0 11.00 3.35 ;RKBj Est Btm f H. F3i 4,540.0 6,741.0 Lead Cement ~ G 287 64.0 15.80 1.16 6,741.0 8,295.0 ',Tubing Strin s ---- -_ - - -- - Tubin -Kill Strin set at 2,308.6ftKB on 1/5/2007 00:00 Tubing Description OD (in) Weight/Length (Ibs/ft) String Grade Set Depth (ftKB) Tubing -Kill String 4 1/2 12.60 L-80 2,308.6 Page 2/2 Report Printed: 7/27/2007 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4-213 Rig: Doyon 19 Date: 1/5/2007 Drilling Supervisor: D. Mickey / N. Woods Pump used: Cement. Unit ~ Volume Input Pump Rate: Barrels ~ Bbls/strk ~ 0.8 Bbl/min ~ Type Of Test: Annulus Leak Off Test for Disposal Adequacy ~ Pumping down annulus. ~ Casin Test Pressure In te rity Test Hole Size: 8-3/4" ~ Casin Shoe Depth Hole Depth Pum ping Shut-in Pumpin Shut-in RKB-CHF: 34.4 Ft 2,713 Ft-MD 2,389 Ft-TVD 4,540 Ft-MD 3,760 Ft-TVD Bbls psi Min psi Bbls psi Min psi Casing Size and Description: 9-5/8" 40#/Ft L-80 BTC ~ 0 0 0 0 563 Chan es for Annula r Ade ua c Test Pressure Int e rit Test 1 0.5 168 0.25 563 uter casing shoe test results in comments Mud Weight: 9.8 ppg 2 1 382 0.5 547 Description references outer casing string. Inner casing OD: 7.0 In. 3 1.5 589 1 536 ize is that drilled below outer casing. 4 2 738 1.5 `~3° - timated TOC for Hole Depth. 5 2.5 898 2 52 Enter inner casing OD at right Desired PIT EMW: 16.0 ppg 6 3 1055 2.5 527 Estimates for Test: 770 psi 0.4 bbls 7 3.5 1183 3 528 - - --- ~ ~ 8 4 1325 3.5 526 EMW =Leak-off Pressure + Mud Weight = 1438 _ PIT 15 Second 9 4.5 1438 4 524 + 9 8 0.052 x TVD 0.052 x 2389 Shut-in Pressure, psi 10 5 635 4.5 525 EMW at 2713 Ft-MD (2389 Ft-ND) = 21.4 563 15 5.5 638 5 522 2000 - --- - - --- 20 6 647 5.5 521 - 25 6.5 658 6 519 -- - - - 30 7 7.5 648 7 517 _ 7 5 516 1500 - - - -- - . 8 512 - w 8.5 511 ~ 9 503 ~ N - -- - 9.5 507 looo rn - - ~ _ ___ 10 5 - - _- _ . ~ ~ ~+ . 500 - , , t - -- - ~ ~ 'Z - - - 0 0 1 2 3 4 5 6 7 8 0 5 1 0 1 5 2 0 2 5 3 0 ~~ CASING T EST Barrel s f LEAK-O FF TEST Shut-I O P n tim IT Poi e, M nt inute s Volume PUm ed Volume Bled Back Volume PUm ed Volume Bled Back s s s s Comments: 9 5/8" casing shoe PIT = 18.1 ppg r WELL LOG TRANSMITTAL To: State of Alaska December 4, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-213 AK-MW-4802638 CD4-213 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Logs 50-103-20540-00 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Logs 50-103-20540-00 Digital Log Images: 1 CD Rom 50-103-20540-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Bryan Burinda Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 907-273-3536 Date._~~ Signed: ~?~ ao~ t~3 t~~33 -, WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`" Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-213, April 5, 2007 AK-MW-4802638 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention o£ Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API#: 5 0-103 -20540-00. :~ ~ ~~: ,,.2:~~ Zfl ~~ ~ ,` n ~- ~e~ -1~3 '~ Cs~o~ ~ r 14-Feb-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD4-213 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 36.75' MD Window /Kickoff Survey 0.00' MD (if applicable) Projected Survey: 8,305.00' 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 ~ Dirt 7 Si ned Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) 20~-173 02/16/07 ~chl~mb~erger Schlumberger-DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 Attn: Beth ~O(o - ~~3 Well. Job # Log Description N0.4153 Company: Alaska Oil 8~ Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Date BL Prints CD CD4-213 11663827 SCMT 01/28/07 1 SIGNED: DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. ~ ~g:~~ STATE OF ALASKA ~- = ~ ?~ ~i 2 ~ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION'S ~ ' ~~ `~"°~ ~'~~s. ~~m~6ssion 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ ~ Operat. Shutdown0 Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5: Permit to Drill Number: COnOCOPhillips Alaska, InC. Development ^ Exploratory ^ 206-173 / 307-009 • 3. Address: Stratigraphic ^ Service ^~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20540-00 • 7. KB Elevation (ft): 9. Well Name and Number: 55' BPMSL CD4-213 8. Property Designation: _ 10. Field/Pool(s): ADL 380077, 384209, 380075 Colville River Field /Nanuq Nanuq Oil Pool 11. Present Well Condition Summary: Total Depth measured 8305' feet true vertical 6201' feet Plugs (measured) Effective Depth measured 8207' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 114' 114' Surface 2678' 9.625" 2715' 2400' Intermediate 8204' 7" 8295' 6200' Production 2271' 4.5" 2308' 2000' Perforation depth: Measured depth: None true vertical depth: None Tubing (size, grade, and measured depth) 4.5", L-80, 2309' MD. Packers &SSSV (type & measured depth) no packer no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation no Subsequent to operation na 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas ^ WAG ^~ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: ~41~~~ contact Vern Johnson @ 265-6081 Printed Name C. Alvord Title Alpine Drilling Lead Engineer "'` Signature ~ o L~y~L~~7 Phone ~~~ ~ / / Z O D t t/ pre ared b Sharon All u Drake 263-4612 Form 10-404 Revised 04/2004 ~ f .,~.,1 Submit , rigin~~0~~ ~f ~~~ ~ J ~~~5 ~~~ FAR ~ R fnn~ • ,~ ~c~nocciPhillips Time Log Summary iNetly~w Web fieporting Well Name: CD4-213 Job Type: DRILLING ORIGINAL - - -- __ - - Time Logs Gate From To Dur S. Depth E Depth Phase Code Subcode T COtvt _ 12/25/2006 16:30 23:45 7.25 0 114 MIRU MOVE MOB P Rigged down and moved from CD4-215 to CD4-213. Ri ed u . 23:45 00:00 0.25 114 114 MIRU MOVE RURD P Nippled up riser. 12/26/2006 00:00 03:30 3.50 0 0 MIRU MOVE RURD P Continue to NU riser - RU and take on s ud mud. 03:30 07:15 3.75 0 0 SURFA DRILL PULD P MU BHA #1. Orient tools and uplink data. 07:15 07:45 0.50 0 0 SURFA DRILL SFTY P Pre spud meeting with rig team. Review wireline and diverterless o erations. 07:45 09:00 1.25 0 0 SURFA DRILL RURD P Fill riser -Check for leaks -Pressure test lines. 09:00 12:00 3.00 0 273 SURFA DRILL DDRL P Spud well at 900 hrs. Drill 12-1/4" hole from 123' to 273' MD ADT D.99 -ART 0.99 WOB 10/15 RPM 60 GPM 400 @ 680 psi String Wt: PU 100 - SO 100 -Rot 100 Trq on/off btm = 6000/3500 ft/Ibs Ran G ro Surve 12:00 00:00 12.00 273 1,245 SURFA DRILL DDRL P Drill 12-1/4" hole from 273' to 1245' MD 1230' TVD ADT 7.78 -ART 3.28 -AST 4.50 WOB 15/20 RPM 60 GPM 500 @ 1310 psi String Wt: PU 115 - SO 115 -Rot 115 Trq on/off btm = 5000/4000 ft/Ibs Last G ro surve 531' 12/27/2006 00:00 12:00 12.00 1,245 2,321 SURFA DRILL DDRL P Drill 12-1/4" hole f/1245' t/2321' MD 2107' TVD ADT 7.79 -ART 5.89 -AST 1.9 WOB 25/30 RPM 60 GPM 600 @ 1810 psi String Wt: PU 133 - SO 128 -Rot 132 Tr on/off btm = 7500/6000 ft/Ibs 12:00 19:15 7.25 2,321 2,723 SURFA DRILL DDRL P Drill 12-1/4" hole f/2321' t/2723' MD 2396' TVD ADT 5.92 -ART 5.40 -AST 0.52 WOB 25/30 RPM 60 GPM 600 @ 1980 psi String Wt: PU 135 - SO 130 -Rot 135 Trq on/off btm = 7000/7000 fUlbs Encountered tight spot & heavy clays -2500' MD. 19:15 20:15 1.00 2,723 2,723 SURFA DRILL CIRC P Circ BU. Bring Mud wt up to 9.8 ppg. Observe well -static. • • Time Low Date From To Dur S_ Ce th E. ~eRth Phase Code Subcode T COM 12/27/2006 20:15 23:00 2.75 2,723 1,650 SURFA DRILL WPRT P Wiper trip pumping out from 2723' to 1650' MD 130 SPM; 550 GPM. 23:00 00:00 1.00 1,650 1,570 SURFA DRILL WPRT P Continue pumping out to HWDP from 1650' to 1570' MD @ 95 SPM; 400 GPM. 12/28/2006 00:00 01:15 1.25 1,570 871 SURFA DRILL WPRT P Continue POOH with pump 60 GPM 400 GPM to 871'. 01:15 02:30 1.25 871 2,630 SURFA DRILL WPRT P RIH to 2,630'. 02:30 03:45 1.25 2,630 2,730 SURFA DRILL CIRC P Wash to 2,723' and circulated hole clean. 03:45 08:45 5.00 2,730 167 SURFA DRILL TRIP P Blew down top drive and POOH on TT from 2,723' to 167'. 08:45 12:00 3.25 167 0 SURFA DRILL PULD P Laid down BHA and flex collars. Cleared floor. 12:00 13:30 1.50 0 0 SURFA CASIN( RURD P RU to run casing - LD Drilling Elevs, MU fill up tool -Install casing elev, bails & slipe - RU casing tongs & work latform. 13:30 13:45 0.25 0 0 SURFA CASIN( SFTY P Pre job safety meeting 13:45 16:30 2.75 0 1,348 SURFA CASIN< RNCS P Run 9 5/8" 40# L-80 BTC csg as follows: Float shoe (Ray oil tools silver bullet) - 2 jts csg, Weatherford FC - 68 jts csg. First 4 connections made up with Baker Loc -filled pipe & checked floats. Bowspring tantalizers on jts 1-12 and every other after that. Stop rin son 'ts 1 & 2. 16:30 17:30 1.00 1,348 1,348 SURFA CASINC CIRC P Circulate & Cond thick mud @ 1348'. Cont RIH. 17:30 19:45 2.25 1,348 2,713 SURFA CASINC RNCS P Continue RIH 9-5/8" csg. Land on han er 2713' MD. 19:45 20:15 0.50 2,713 2,713 SURFA CASINC RNCS P LD Fill up tool - PU Cement e ui ment. 20:15 22:00 1.75 2,713 2,713 SURFA CASIN< CIRC P Circulate mud from 2 bpm to 7 bpm. 22:00 00:00 2.00 2,713 2,713 SURFA CASINC CIRC NP Continue to circulate - WO Rig trucks to offload & haul fluid to the injection skid. Cold temps causing mechanical difficulties. 12/29/2006 00:00 02:00 2.00 2,713 2,713 SURFA CASINC CIRC NP Circulated and conditioned mud while making enough room in pits for cement returns. Injection skid had canceled Little Red injection without our knowled e. __ ____.~ • • Time Logs Date From To Dur S Depth E. De th_ Phase Code Subcode T COM _ _ 12/29/2006 02:00 04:30 2.50 2,713 0 SURFA CEME~ DISP P Cement 9 5/8" csg as follows :Rig Pumped 40 bbls Biozan water w/nut plug as marker -Pumped 10 bbls water w/ Dowell -Tested lines to 2500 psi -Pumped 10 bbls water -Dropped btm plug - Pumped 50 bbls MudPush @ 10.5 ppg -Mixed & pumped 276 bbls lead slurry (ASL) @ 10.7 ppg (" Observed nut plug marker @ shakers w/ 272 bbls lead pumped -pumped down surge can) Pumped 49 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/ 184 bbls 9.7 ppg water base mud -Displaced @ 7.0 bbls/min for first 170 bbls - slowed to 4 bbls/min for last 14 bbls - Bumped plug w/ 1100 psi (pre bump pressure 560 psi) Check float (held OK) CIP @ 04:15 hrs. -Full circulation throughout job w/ 160 bbls 10.7 ppg cmt returns to surface -reciprocated pipe while circulating & through cement job until last 90 bbls of dis lacement. 04:30 05:15 0.75 0 0 SURFA CASIN( DHEO P Tested casing to 2,500 psi for 30 min. 05:15 06:30 1.25 0 0 SURFA CASIN( RURD P Rigged down casing and cement tools. Laid down landin Jt. 06:30 14:30 8.00 0 0 SURFA CASIN( NUND P ND Riser - NU BOP -Change out Junk Sub 14:30 19:30 5.00 0 0 SURFA WELC1 BOPE P Test ROPE Annular 250 / 3000 psi. Lwr & Blind rams, upper rams with 4" - 4.5" - 5". Tested HCR & Man choke, kill choke, Valves 1-16, Auto and manual IBOP, dart & TIW to 250 / 3000 si. 19:30 20:30 1.00 0 0 SURFA DRILL RURD P Blow dwn choke & kill, Install wear rin . PU Bails & Elevators. 20:30 00:00 3.50 0 715 SURFA DRILL PULD P PU BHA #2 for 8-3/4" hole -Orient plug - PU NMFC, Jars, & HWDP to 715'. 12/30/2006 00:00 01:30 1.50 715 2,525 SURFA CEME~ TRIP P Shallow tested tools and continued RIH to 2,525'. 01:30 03:00 1.50 2,525 2,723 SURFA CEME~ COCF P Washed down and drilled out plugs and shoe track. Cleaned out rathole to 2, 723'. 03:00 03:30 0.50 2,723 2,743 SURFA DRILL DDRL P Drill 8-3/4" hole f/2,723' t/2'743' MD 2,409' TVD ADT .25 -ART .25 -AST 0. WOB 5/10 RPM 60 GPM 600 @ 1800 psi String Wt: PU 135 - SO 120 -Rot 130 Tr on/off btm = 7000/5000 ftllbs 03:30 04:00 0.50 2,743 2,743 SURFA DRILL CIRC P CBU. ~ --- ~ _ ~ ~ ~l d.1?4: CJ~ ~ 3~3 ._ _..J n Time Logs Date From 7o Dur S,_De th E. Depth Phase Code S~Ebcode T COM ___ _ __ _ _. -- 12/30/2006 04:00 05:15 1.25 2,743 2,743 SURFA CEMEh FIT P Rigged up and performed FIT to 18 PPG EMW. 05:15 12:00 6.75 2,743 3,476 INTRM1 DRILL DDRL P Drill 8-3/4" hole f/2,743' t/3,476' MD 2,949' TVD ADT 3.54 -ART 3.44 -AST 0.1 WOB 10/15 RPM 80 GPM 600 @ 1810 psi String Wt: PU 145 - SO 125 -Rot 133 Tr on/off btm = 8000/6500 ft/Ibs 12:00 18:00 6.00 3,476 4,238 INTRM1 DRILL DDRL P Drill 8-3/4" hole f/3476' t/4238' MD 3507 TVD WOB 16/20 RPM 80 GPM 600 @ 2400 psi String Wt: PU 162 - SO 130 -Rot 145 Tr on/off btm = 8500/8000 fUlbs 18:00 19:00 1.00 4,238 4,238 INTRM1 RIGMN SVRG T Standback 1 stand - CO SVR Sub to re air washout. 19:00 00:00 5.00 4,238 4,645 INTRM1 DRILL DDRL P Drill 8-3/4" hole f/4238' t/4645' MD 3807' TVD ADT 6.64 -ART 5.67 -AST 0.97 WOB 15/20 RPM 80 GPM 600 @ 2550 psi String Wt: PU 162 - SO 130 -Rot 145 Tr on/off btm = 8500/8000 ft/Ibs 12/31/2006 00:00 01:30 1.50 4,645 4,882 INTRM1 DRILL DDRL P Drill 8-3/4" hole f/4645' t/4882' MD 3980' TVD ADT 1.18 -ART 1.18 -AST 0. WOB 15/20 RPM 80 GPM 600 @ 2550 psi String Wt: PU 162 - SO 130 -Rot 145 Tr on/off btm = 8500/8000 ft/Ibs 01:30 04:30 3.00 4,882 4,882 INTRM1 RIGMN RGRP T IBOP and saver sub washed out. POOH to 4,715' and changed both subs. Tested sub and RIH to 4882'. 04:30 12:00 7.50 4,882 5,504 INTRM1 DRILL DDRL P Drill 8-3/4" hole f/4,882' U5,504' MD 4432' TVD ADT 1.18 -ART 3.48 -AST 0.75 WOB 15/20 RPM 80 GPM 600 @ 2780 psi String Wt: PU 181 - SO 138 -Rot 155 Tr on/off btm = 10000/8500 ft/Ibs 12:00 14:30 2.50 5,504 5,764 INTRM1 DRILL DDRL P Drill 8-3/4" hole f/5,504' t/5,764' MD 4623' TVD ADT 2.11 -ART 1.74 -AST 0.37 WOB 10/15 RPM 80 GPM 650 @ 2950 psi String Wt: PU 190 - SO 137 -Rot 159 Tr on/off btm = 10500/9000 fUlbs 14:30 15:30 1.00 5,764 5,764 INTRM1 DRILL CIRC P Circulate & condition mud for short trip - 465 gpm @ 1660 psi, 100 rpm - Wash out in Mud Pump #2 -shut down to troubleshoot. 15:30 20:00 4.50 5,764 2,620 INTRM1 DRILL WPRT P Flow check well -static. POOH on TT from 5764' - 2620' MD. Flow check - static. 20:00 00:00 4.00 2,620 2,620 INTRM1 RIGMN RGRP T Monitor well on TT -Change out fluid end of MP #2. r~~t3 i l~ __._ l~ Time Logs _. _- - - - __ --- - --_ --- --- Date From To Dur_ S. Depth E Depth Phase .Code Subcode-- T COM _--- 01/01/2007 00:00 02:45 2.75 2,620 2,620 INTRM1 RIGMN RGRP T Continue CO fluid end of mud pump #2 -monitor well on TT -Pressure test pump to 3500 psi -Circ @ 80 spm, 700 si -Good test. 02:45 05:30 2.75 2,620 5,764 INTRM1 DRILL TRIP P RIH from 2620' to 4524' -Fill pipe and establish circulation - RIH to 5668' - Wash/Ream to btm 5764'. 05:30 06:30 1.00 5,764 5,859 INTRM1 DRILL DDRL P Drill 8-3/4" hole from 5764' - 5859' MD 4893' TVD ADT 0.71 -ART 0.51 -AST - 0.2 WOB 15 RPM 100 GPM 600 @ 2950 psi String wt: PU 190 - SO 140 -Rot 157 Tr on/off btm = 10,000/9,000 ft/Ibs 06:30 07:30 1.00 5,859 5,859 INTRM1 RIGMN RGRP T #2 MP Washout, R&R with #1 MP @ 110 SPM, 1730 PSI -Blow do TD. 07:30 10:45 3.25 5,859 2,715 INTRM1 RIGMN RGRP T Flow check well -static - POH on TT to 2715' -Flow check -static. 10:45 17:00 6.25 2,715 2,715 INTRM1 RIGMN RGRP T MU TD orient with 450 GPM - 1030 psi. Circ @ reduced rate of 300 gpm to conserve MWD battery -Fix Mud um . 17:00 20:30 3.50 2,715 5,764 INTRM1 RIGMN RGRP T Blow DN TD -Thaw Iron Roughneck - RIH from 2715' to 5764" -Establish circulation -Test #2 MP to 3500 si. 20:30 21:00 0.50 5,764 5,859 INTRM1 RIGMN RGRP T Wash dwn to 5859' - 600 gpm @ 2800 si -That TD Grabs/IBOP. 21:00 00:00 3.00 5,859 6,070 INTRM1 DRILL DDRL P Drill 8-3/4" hole from 5859' - 6070' MD 4848' TVD ADT 1.47 -ART 1.06 -AST - 0.41 WOB 20 RPM 80 GPM 650 @ 3550 psi String wt: PU 192 - SO 142 -Rot 162 Tr on/off btm = 10,000/9,000 ft/Ibs 01/02/2007 00:00 12:00 12.00 6,070 7,002 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/motor f! 6070' to 7002' MD - 5558' TVD ADT - 7.52 hrs = AST 4.42 hrs ART - 3.08 hrs ECD = 10.43 ppg WOB 15/20 k RPM 80 GPM 600 @ 3120 psi String wt. PU 180 SO 160 Rot 171 Tor ue on/off btm - 10,000/8,000 ft/Ibs 12:00 00:00 12.00 7,002 7,724 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/motor f! 7002' to 7724' MD - 6046' TVD ADT - 8.20 hrs = AST 7.78 hrs ART - 0.42 hrs ECD = 10.2 ppg WOB 12/25 k RPM 80 GPM 500 @ 2370 psi String wt. PU 195 - SO 160 -Rot 180 Tor ue on/off btm - 11,000/9,000 ft/Ibs 1'~~~ ~ ~rf ~ [~ n U L~ Time Logs _ __ __ _ - Date From To_ --- - Dur - S. Depth -- E De th Phase Code - Subcode _ _ T _ ___ - COM i 01/03/2007 00:00 12:00 ___ 12.00 7,724 8,001 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ motor f/ 7724' to 8001' MD 6148' TVD ADT - 9.07 hrs. =ART .8 hrs AST 8.27 hrs -ECD 10.04 ppg WOB 15/20 k RPM 80 GPM 550 @ 2350 psi String wt. PU 200 SO 157 Rot 180 Torque on/off btm. - 11,000/10,000 ft/Ibs 12:00 17:30 5.50 8,001 8,305 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ motor f/ 8001' to 8305' MD 6201' ND ADT - 4.19 hrs. ART - 0.97 hrs AST - 3.22 hrs ECD 10.36 ppg WOB 10/15 k RPM 80 GPM 650 @ 3350 psi String wt. PU 190 SO 155 Rot 175 Tor ue on/off btm. - 11,000/9,500 ft/Ibs 17:30 19:30 2.00 8,305 8,049 INTRM1 DRILL CIRC P Circulate 3x BU @ 650 gpm, 70 RPM, 3170 psi. -Standing back 1 std DP eve 30 mins. to 8049' MD. 19:30 22:30 3.00 8,049 6,907 INTRM1 DRILL WPRT P Flow check static -Wiper trip with pump from 8049' - 6907'. 500 GPM, 70 RPM, 1910 psi -Flow check static - Blow Down TD. 22:30 23:00 0.50 6,907 8,240 INTRM1 DRILL WPRT P RIH from 6907' - 8240'. Hole in good condition 23:00 00:00 1.00 8,305 8,035 INTRMI DRILL CIRC P Precautionary wash f/ 8240' to 8305' - Circand Condition for tri out. 01/04/2007 00:00 00:15 0.25 8,035 8,035 INTRMI DRILL CIRC P Continue circulating hole @ 650 GPM - 3280psi - 70 rpm. Fill pipe with Wellbore Strengthing pill and casing runnin ills. Flow check -static. 00:15 03:00 2.75 8,035 6,431 INTRM1 DRILL TRIP P POOH to 6431' spotting 35 BBLS of WBS pill and 135 bbls of lubricating pill @ 3 bpm and 350 psi. Flow check static. Blow dwn TD. 03:00 09:00 6.00 6,431 262 INTRM1 DRILL TRIP P Zero TT, POOH 10 stands on TT from 6431' - 5478'. Flow check static. Hole taking proper fill and no tight spots observed. Pump 40 bbls dry job. Chase with 8 bbls mud. SD pumps, blow down TD. Continue POOH on TT t/HWDP. (Flow check static at shoe). Cont POOH & LD BHA to 262'. 09:00 09:30 0.50 262 0 INTRM1 DRILL PULD P LD NMFC's. 09:30 12:00 2.50 0 0 INTRM1 DRILL PULD P LD BHA -Download MWD Data - LD MWD tools. Clear Ri Floor. 12:00 14:30 2.50 INTRM1 CASIN( OTHR P Pull wear bushing. and install test plug. CO upper pipe rams to 7" and test to 250 / 5000 psi. Pull test plug and install thin wall wear rin . 14:30 15:30 1.00 INTRM1 CASIN( RURD P RU to run 7" casing. RU scaffolding & tongs, CO elevators & slips. PU Franks fill u Tool. PJSM. s ~~ ~ ~'arJe ~ ~t • Time Logs _ --- Date From To ____ Dur S. De th E. De th Phase Code__ Subcode T - _ _ COM ___ _ 01/04/2007 15:30 _ 20:00 4.50 0 3,419 INTRM1 CASIN( RNCS P Run 7" 26# L-80 BTCM Casing as follows: Float Shoe (Ray oil tools) 2 jts - Halliburton float collar - 2 jts. First 4 jts made up w/ BakerLoc - Filled pipe & checked floats) 76 jts to 3419' for 80 'ts total 20:00 20:30 0.50 3,419 3,419 INTRM1 CASIN( CIRC P Break circulation and stage pumps to 5 bpm. Circ & condition csg vol. + ICP - 340 si, FCP - 300 si. 20:30 00:00 3.50 3,419 6,847 INTRM1 CASIN( RNCS P Continue Running 7" 26# L-80 BTCM Casing f/3419' to 6847' MD. (160 jts total 01/05/2007 00:00 01:15 1.25 6,847 6,847 INTRM1 CASIN( CIRC P Break Circulation -Stage pump up to 5 bbls/min -Circ btms u + 01:15 02:45 1.50 6,847 8,295 INTRM1 CASIN( RNCS P Continue Running 7" 26# L-80 BTCM f/6847' to 8258' MD - 193 jts total - PU FMC fluted hanger & landing jt. - Land casing in wellhead w/Shoe @ 8295' & FC 8207' 02:45 03:15 0.50 8,295 8,295 INTRM1 CASIN( RURD P LD fill up tool & csg spider -Blow down TD - RU cmt head & lines 03:15 04:30 1.25 8,295 8,295 INTRM1 CEME~ CIRC P Establish Circ @ 2 bbls/min @ 420 psi - Stage pump up to 6 bbls/min @ 460 PSI -Circ & condition for cmt job PU wt 265 SO wt - 155 04:30 07:00 2.50 8,295 8,295 INTRM1 CEME~ DISP P Held PJSM -Flush mud pumps w/ brine Cement 7" csg as follows: Pumped 10 bbls CW-100 -Pressure test lines to 3850 psi -Pumped 10 bbls CW-100 - Mixed & pumped 30 bbls 10.5 ppg MudPush @ 4 bbls/min @ 280 psi - Dropped btm plug -Mixed & Pumped 87 bbls 11.0 ppg Lead slurry (LiteCrete) @ 6 bbls/min @ 430 psi followed by 64 bbl 15.8 ppg tail slurry (Class G w/ additives) @ 5 bbls/min @ 200 psi -Dropped top plug w/ 20 bbls water f/ Dowell -Switched over to rig pumps & displaced cmt w/ 294 bbls 9.2 ppg brine @ 7 bbls /min for 230 bbls @ 720 psi -slowed pump to 5 bbls/min for next 20 bbls @ 730 psi -slowed pumps to 4 bbls/min for next 20 bbls @ 850 psi -slowed pumps to 3.5 bbls for last 24 bbls @ 1020 psi pre bump pressure -Bumped plug w/1500 psi -Bleed off pressure & checked floats - OK Full circulation throughout job - Recip. pipe for first 170 bbls of displacement - CIP 0700 hrs 07:00 07:45 0.75 8,295 8,295 INTRM1 CEME~ OTHR P RU & test 7" csg to 3500 psi for 30 mins. - RD ~ m ~ P~a~e 7 z~F ~ • • Time logs Date From To Dur S. De th E De th Ph_ase Code Subcod_e ~ T COM 01/05/2007 07:45 10:15 2.50 0 0 _ INTRM1 CEME~ RURD P Blow down cement lines - RD lines & head - LD landing jt. -Pull thin wall wear bushing -Set 7" X 9 5/8" pack Off & test to 5000 si 10:15 11:15 1.00 0 0 INTRM1 CASIN< OTHR P Change top pipe rams f/ 7" to 3 1/2" X 6" VBR -Test to 250 & 5000 si 11:15 13:00 1.75 0 0 INTRM1 RPCOh RURD X Clear rig floor. Pick up and rig up 4-1/2" Tb a ui ment -kill strin . 13:00 16:00 3.00 0 2,309 INTRM1 RPCOh RCST X RIH with 4-1/2" 12.6# L-80 IBTM tubing (kill string) to 2309' MD as follows: 4-1/2" WL entry guide, 56 jts total - PU FMC 4-1/2" Gen V Tbg Hanger w/pup -Land tbg in wellhead wNVEG 2307' MD. 16:00 17:00 1.00 2,309 2,309 INTRM1 RPCOh PULD P RI LDS -Install two way check and test han er seals to 5000 si. 17:00 17:30 0.50 0 0 INTRM1 RPCOh RURD P LD Tbg equipment, clear rig floor. 17:30 20:30 3.00 0 0 INTRM1 RPCOh NUND P ND BOPE. NU Tree and test to 5000 si. Pull 2 wa check. 20:30 22:30 2.00 0 0 INTRM1 RPCOh CIRC P PJSM for Diesel displace. RU to pump down the tbg taking returns out the 4-1/2" x 7" annulus to the pits. Fluid pack lines and PT. Displace brine with a total of 68 bbls diesel to freeze protect the tbg and annulus. Blow down lines and RD. 22:30 00:00 1.50 0 0 INTRM1 RPCOh OTHR P FMC set BPV to secure well. RU to la down i e in the i e shed. 01/06/2007 00:00 00:30 0.50 0 0 INTRM1 RPCOh OTHR X Finish securing well -Clean up cellar area -set mouse hole 00:30 12:00 11.50 0 0 INTRM1 DRILL PULD X LD 4"drill pipe f/derrick via mouse hole for ri move 91 stds 12:00 16:30 4.50 0 0 INTRM1 DRILL PULD X LD 5" HW & DP using the mouse hole for ri move. 273 'ts total 16:30 18:00 1.50 0 0 INTRM1 DRILL OTHR X Service and inspect top drive. 18:00 19:00 1.00 0 0 INTRM1 RPCOR OTHR X PJSM; Cut and slip drilling line. 19:00 00:00 5.00 0 0 INTRM1 RPCOA OTHR X Prep For rig move. Release rig @ 2359hrs. '~` ~ ~ ______ _~ e~ ~~ F f ~~ ~ • ®1~T~EIt~~°I`I®1~T C 5SI®19T Chip Alvord Exploration Team Lead ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Nanuq Oil Pool, CD4-213 Sundry Number: 307-009 Dear Mr. Alvord: • SARAH PALIIV, GO!/ERA/OR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 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. 4in~erely DATED this day of January, 2007 Encl. Chairman .~ ~ ~ ~~ STATE OF ALASKA \r~~ ~~ ~ ~ ~ Zu , ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVA~j~s~ ~$~ CIS Canso ~: 7n AAC: ~S 7Rf1 n,.,.f,...>...... 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^~ Perforate ^ Other ^ ^ Waiver Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drilf Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 206-173 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20540-00 7. KB Elevation (ft): 9. Well Name and Number: 55.1 ft BPMSL CD4-213 8. Property Designation: 10. Field/Pools(s): 380077, 384209, 380075 / ALK 380077 Nanuq Nanu Oil Pool 11. PRESENT WELL CONDIT ION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured) Junk (measured): 8305' 6201' Casing Length Size MD TVD Burst Collapse Structural Conductor 77 16" 114' 114' Surface 2678 9.625" 2715 2400' Intermediate 8204 7" 8241 6201 Production 2271 4.5" 2308 2000 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None 4.5" L-80 2300 Packers and SSSV Type: Packers and SSSV MD (ft): None None 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ^ Exploratory ^ Development ^ Service^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/5/2007 Oil ^ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Da /07 WAG^ GINJ ^ WINJ ^ WDSPL ^ ~~ Commission Representative: T. Maunder 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact V Johnson Printed Nacre C. AIVOfd Exploration Team Lead Signature ~i,_,_;~~ ~ Phone 265-6120 ~ ~ S_~ y 7g Date 1/5/2007 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: . ~'.J~~GU~`< Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~~ ~ ~"~ ~`S<J~"`1~ J P~~~~~~' ``~ ~i~s~.~~`~ ~~, `~r~' ?I7t1~i ~ ~ iA~Q~ ~ ` ~~ Subsequent Form Required: `~ ~ ~- O ~SC~MN~~ ~ ~- " "' " MMISSIONER APPROVED BY THE COMMISSION Date: ~ ~~ "'a Approved by: ~ f. m ~~ sia~~ ~ 1 20D V t 1~ V t ,t~ ~ r/,b/o7 Form 10-403 Revised 7/2005 t ~ ~-- SUBMIT IN UPLICATE Alpine: CD4-213 Temporary Shutdown of Drilling Operations -Program outline 1. Run and cement 7" casing per program, displace cement with 9.2 ppg brine. 2. Test casing to 3500 psi for 30 min 3. RD from cement job. 4. RIH with +/- 2308' 4.5" tubing and land hanger. Test seals. 5. Set two-way-check. 6. ND BOPE. NU and test tree. 7. Pull two-way-check. 8. Displace to diesel freeze protection. 9. Install BPV. 10. LD excess drillpipe. 11. RDMO to CD3. OR161N:1L ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 January 5, 2007 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ~.~~. .JAN 0 ~ ZOCi Re: Sundry Permit: Operational Shutdown CD4-213 Alaska Oi! ~ Gay Irons. C~r~ s~=a'>i6r~ Dear Sir or Madam: Anchorage ConocoPhillips Alaska, Inc. hereby applies for a sundry permit for operational shutdown on CD4-213. It was decided to temporarily shut down drilling operations on CD4-213 due to ice road/pad timing and the desire to maximize rig time at Fiord this winter `' season. Operations will resume on CD4-213 after the ice road season at Fiord, in early May, 2007. Please find attached the form 10-403 and plan of operations. If you have any questions or require further information, please contact Liz Galiunas 265-6247. Sincerely, Liz a iuna Drilling Engineer Attachments cc: CD4-213 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1700 Vern Johnson ATO 1702 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation Co ocoPhillips ORIGINAL SARAH PALIN, GOVERNOR 333 W. 7`h AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 F.aX (907) 276-75423 Chip Alvord WNS Drilling Team Lead ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Nanuq Oil Pool, CD4-213 ConocoPhillips Alaska, Inc. Permit No: 206-173 Surface Location: 2942' FNL, 303' FEL, SEC. 24, T11N, R4E Bottomhole Location: 5252' FNL, 567' FEL, SEC. 14, T11N, R4E Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service 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. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation. or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (9071 659-3607 (pager). DATED this day of December, 2006 cc: Department of Fish & Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ PERMIT TO DRILL FtE~E~~ ~~ ~~. DEC 0 ~ ~~~~ k Oil & Gas Cans. ~~;1~issiott 20 AAC 25.005 ~~~~ a 1a. Type of Work: Drill /^ - Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil ^ Stratigraphic Test ^ Service /^ Development Gas ^ Multiple Zone^ Single Zone /^ 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: CD4-213 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 14537' TYD: 6201' 12. Field/Pool(s): Colville River Field 4a. Location of Well (Governmental Section): Surface: 2942` FNL, 303' FEL,. Sec 24 T11 N R4E 7. Properly Designation: ADL 380077, 3842og, 380075 Nanuq Nanuq Oil Pool Top of Productive Horizon: ~ ~ fq. ~3,~(0 347' FNL 3097' FEL, Sec.~T11 N R4E 8. Land Use Permit: ALK 380077 13. Approximate Spud Date: 12123!2006 Total Depth: 5252' FNL 567' FEL, Sec. 14 T11 N R4E 9. Acres in Property: 2560 14. Distance to Nearest Properly:15868' FSL Nanuq PA 4b. Location of Well (State Base Plane Coordinates): Surtace: x- 377941 ' y- 5957470 Zone- 4 10. KB Elevation (Height above GL): 3T RKB feet 15. Distance to Nearest Well within Pool: Nanuq 3 , 24T 16. Deviated wells: Kickoff depth: 400 ~ ft. Maximum Hole Angle: 92.5° deg 17. Maximum Anticipated Pressures in psig (see zo AAC 25.035) Downhole: 2806 psig ' Surface: 2186 psig ' 18. Casing Program f Setting Depth Quantity of Cement Size ications Speci Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (inGuding stage data) 24" '6" 62 5~ H-40 ~flelde~ 77 37 37 114 114' pre-installed 12.26" 9-518" 40~# L-80 BTC 2678 37 37 2715 2400 525 sx AS Lite3, 230 sx 15.8 G 8.75" 7" 26# L-80 BTCM 8204 37 37 8241 6201 137 sx LiteCrete lead 2$7sx cl G Tail 6.125 4.5" 12.6# L-80 SLHT 6436 8091 6176 14527 6202 Slotted Liner 4.5" 12.6 L-80 IBT-M 8069 32 32 8101 6168 tubing 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Proplelrty P at ^ DivertOeP Sketch ^ Sealbed Report ^ Drill g F uid Prtogralm /^ 20 AAC 25.050 equAemenlts ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact V Johnson Printed Name C~./A,~lvord Title WNS Drilling Team Lead Signature ~,,~ ~ ~!~„' ~ Phone ~ G .~ :' ~ i 2 v Date ~ ~ ~ ~ /c '` ~ t~ Commission Use Only Permit to Drill / Number: ~GO ~ ~7 ' API Number: 50- ~~3 -~.~~Q '~ ~ Permit Approval Date: See cover letter for other requirements Conditions Of approval : If box is checked, well may not be used to explore for, test, or produce Coalbedrmeythane, gas hydrates, or gas contained in shales: ~' ~'T'~ ~~.~,~,~.~--- ~uGl~~ ~~ ~ Samples req'd: Yes ^ No LJ Mud log req'd: Ye~ No~ Other: H2S measures: Yes ^ No Qi ' Directional sv~eq'd: Yes [~ No ^ \ Aso©P s ~ ~.,,~ ~..,~op -4~ a-- v tt: ~.,~,.~ o ra z©~~ ~,~ ~ ~/ ~~v ~~ , D;~~~~~-~~,;~~ ~c'~Ar~La-s,o35~h~~> ~~~ ti -~ ~~s ~~~E3 ~~ V Y THE COMMISSION ~ DATE: ,COMMISSIONER Form 10-401 Revised 12/2005 ~2'~ ubmit in Duplicate • ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 December 8, 2006 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD4-213 Dear Sir or Madam: COl'1000~11~~1 S p ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injector well from the Nanuq (CD4) drilling pad. The intended spud date for this well is 12/23/2006. It is intended that Doyon Rig 19 be used to drill the well. After setting 7" intermediate casing, the undulating horizontal section will be drilled and the well completed as a slotted liner injector. At the end of the rig work program, the well will be flowed back for 2-3 days to mitigate reservoir damage: The well will then be closed in awaiting completion of well work and facilities connection that will allow the well to begin injection. It is expected that the K2 (Qannik) sand could be considered a significant hydrocarbon bearing zone." Pending LWD log results, it is planned to isolate the Qannik with cement. ~' It is also requested that the packer placement requiremen a relaxed to place the completion packer +/- +/- 250 ft TVD above the Nanuq reservoir. This will place the completion at a maximum inclination less than 65° and allow access to the completion with standard wireline tools for future intervention. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. There have been 8 surface holes drilled at CD4 and there has not been a significant show of shallow gas or gas hydrates. 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 drilling fluids program summary. 5. Pressure information as required by 20 ACC 25.035 (d)(2). 6. 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: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. • • If you have any questions or require further information, please contact Vern Johnson at 265- 6081, or Chip Alvord at 265-6120. Sin ly, ~- ~ . rn Johnson Drilling Engineer Attachments cc: CD4-213 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1700 Vern Johnson ATO 1702 Liz Galiunas ATO 1704 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation • • CD4-213 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1 /4" Hole / 9-5/8" Casing Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuous) Burin 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' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low densit cement slurries 8-3/4" Hole / 7" Casing 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 H2S 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 H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers , ~?RIGIN.AL • • Nanug : CD4-213 Procedure 1) Move on Doyon 19, dewater cellar as needed. 2) Rig up riser. 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 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) BOPE test to 5000 psi. 12) Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 13) Displace well to Flo-Pro drilling mud. 14) Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD/Sonic tool for cement evaluation). 15) Circulate the hole clean and pull out of hole. 16) Run lower completion with slotted liner and liner hanger, set hanger and pull out of hole. 17) Run 4-'/2, 12.6#, L-80 tubing with DB injection nipple, gas lift mandrels, packer and stinger assembly. Sting in, space out and 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) Circulate tubing to inhibited brine and diesel freeze protection in the annulus. 21) Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 22) Set BPV and secure well. Move rig off. "?!GINAL • Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. Nanuq 5 is the closest well. Well separation is 21.9 @ 250' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. ~' Lost circulation: Faulting within the Nanuq 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 Pumping Operations: Incidental fluids developed from drilling operations on well CD4-213 will be injected into a permitted annulus on CD4 pad or the class 2 disposal well on CD1 pad. The CD4-213 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The significant hydrocarbon zones are the Nanuq reservoir and the Qannik reservoir. There will be 500' of cement fill above the top of the Nanuq and Qannik reservoirs. ~' Upon completion of CD4-213 form 10-403, Application for Sundry Operations, will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi _ (12.0 ppg) " (0.052)'` (2400') + 1,500 psi = 2998 psi Pore Pressure = 1,086 psi Therefore Differential = 2998 - 1086 = 1912 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular .pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 9-5/8" 40 L-80 3 BTC 9,090 psi 1,717 psi 5,750 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi ^^!GINAL • DRILLING FLUID PROGRAM SPUD to 9-5/8"surface casing point - 12'/" Intermediate hole to 7" casing point - 8 3/" 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 KCL 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. There is potential for lost circulation, particularly after the reservoir is penetrated. 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-1 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 • CD4-213 Nanuq Injector Completion 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 2715' MD / 2400' TVD Sperry Sun Directional Plan WPO5 12/07/06 To~MD TVD ~~ 1) Tubing Hanger 32' 32' 2) 4-'/i' 12.6 #/ft IBT-Mod Tubing 3) Camco DB nipple (3.813") 2165' 2000' 4) 4-'/2' 12.6 #/ft IBT-Mod Tubing 5) Camco KBG- GLM (3.833" ID) w/DCK-2 7640' 6049' 6) 4-''/i' 12.6 #/ft IBT-Mod Tubing (2) 7) Baker Premier Packer 7740' 5954' TOC 8) 4-'/i' 12.6 #/ft IBT-Mod Tubing (1) +/-4559' MD / 9) HES "XN" (3.750")- 64.0° inc 7800' 6077' ' 3742' TVD 10) 4-'/i' 12.6 #/ft IBT-Mod Tubing +/- 12 jts 11) BOT Stinger with Fluted WLEG/ stinger 8087' 6165' Stung into tieback extension 10', WLEG bottom at 8101' K2/Qannik sand '' +/-5059' MD / 4106' TVD Lower Completion: Tom ND Item 12) Baker 5" x 7" Flexlock Liner Hanger w/ tieback sleeve 8091' 6176' 13) 4 Y~', 12.6#/ft, SLHT Tubing +/- 4 jts 14) 4 '/2' 12.6#/ft L-80 SLHT liner w/ blank across shale and slots across sand 15) Baker Shoe 14527' 6202' 4-'/z' 12.6#/ft L-80 SLHT Mod Slotted Liner Pattern: 32 slots/ft, 2 '/," x 1 /8" slots Top Reservoir at +/- U ---------------- Nanuq 8154' MD / 6189' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ +/-86° 8241' MD, 6201' TVD - -- 15 -- TD 6-1 /8" hole 14537 MD / 6201' TVD ORIGINAL A CD4-213 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 (c) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient lbs. / al Pore pressure si ASP Drilling psi 16 114 / 114 10.9 52 53 9 5/8 2715 / 2400 14.5 1086 1570 7" 8241 / 6201 16.0 2806 2186 N/A 14537 / 6201 16.0 2806 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) = 1086 - (0.1 x 2400') = 846 psi Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1] D _ ((14.5 x 0.052) - 0.1 ] x 2400 = 1570 psi OR ASP =FPP - (0.1 x D) = 2806 = (0.1 x 6201') = 2186 psi ' 3. Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 2806 = (0.1 x 6201') = 2186 psi ' ORIGINAL • Cementing Program: 9 5/8" Surface Casing run to 2715' MD / 2400' TVD. Cement from 2715' MD to 2215' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2215' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1000' MD). Lead slurry: (2215'-1653') X 0.3132 ft3/ft X 1.5 (50% excess) = 264 ft3 below permafrost 1653' X 0.3132 ft3/ft X 4 (300% excess) = 2070.9 ft3 above permafrost Total volume = 264 + 2070.9 = 2334.9 ft3 => 525 Sx @ 4.45 ft3/sk System: 525 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% 5001 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% 5001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 8241' MD / 6201' TVD: Cemented in two stages Cement from 8241' MD to 6741' MD with Class G + adds @ 15.8 PPG and from 6741' MD to 4559' MD (+/- 500' above the K2) with LiteCRETE @ 11.0 ppg. Assume 40% excess annular volume. Lead: (6741' - 4559') X 0.1503 ft3/ft X 1.4 (40% excess) = 459.1 ft3 annular volume Total volume = 459.1 ft3 => 137 Sx @ 3.35 ft3/sk System: 137 Sx LiteCrete with 0.4% D046 antifoamer, 1.0 % D065 dispersant, 0.010% B155 retarder, 0.25% D167 fluid loss @ 11.0 PPG yielding 3.35 ft3/sk Tail: (8241' -6741') X 0.1503 ft3/ft X 1.4 (40% excess) = 315.6 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 315.6 + 17.2 = 332.8 ft3 => 287 Sx @ 1.16 ft3/sk System: 287 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 ' By Weight Of mix Water, all other additives~e~V1(O~e~~ryl ~ t • • CD4-213 Nanuq Injector Completion 16" Insulated Conductor to 114' 4-'/z' 12.6 ppf L-80 IBT Mod Tubing 3.813" DB Landing Nipple 9-5/8" 40 ppf L-80 BTCM Surface Casing 2715' MD / 2400' TVD Sperry Sun Directional Plan WP05 12/07/06 Uooe r Completion: Top MD TVD Item 1) Tubing Hanger 32' 32' 2) 4-'/z' 12.6 #/ft IBT-Mod Tubing 3) Camco DB nipple (3.813") 2165' 2000' 4) 4-'/2' 12.6 #/ft IBT-Mod Tubing 5) Camco KBG- GLM (3.833" ID) w/DCK-2 7640' 6049' 6) 4-'/2' 12.6 #/ft IBT-Mod Tubing (2) 7) Baker Premier Packer 7740' 5954' TOC 8) 4-''/z' 12.6 #/ft IBT-Mod Tubing (1) +/-4559' MD / 9) HES "XN" (3.750")- 64.0° inc 7800' 6077' 3742' TVD 10) 4-'/2' 12.6 #/ft IBT-Mod Tubing +/- 12 jts 11) BOT Stinger with Fluted WLEG/ stinger 8087' 6165' Stung into tieback extension 10', WLEG bottom at 8101' K2/Qannik sand +/-5059' MD / 4106' TVD Lower Completion: Too MD TVD Item 12) Baker 5" x 7" Flexlock Liner Hanger w/tieback sleeve 8091' 6176' 13) 4-'/z', 12.6#/ft, SLHT Tubing +/- 4 jts 14) 4-'/i' 12.6#/ft L-80 SLHT liner w/blank across shale and slots across sand 15) Baker Shoe 14527' 6202' 4-'/2' 12.6#/ft L-80 SLHT Mod Slotted Liner Pattern: 32 slots/ft, 2-'/4" x 1/8" slots ------- 14 -- - -- ---- --- -~ 13 =__________~ ~__________-~ Top Reservoir at +/- Nanuq 8154' MD / 6189' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ +/-86° 8241' MD, 6201' TVD - - -- TD 6-1/8" hole ' 14537' MD / 6201' TVD ' ORIGINAL OnOCOPhllll s Alaska Inc. P CPAI Report Company: ConocoPhillips Alaska Inc. Date: 11/30!2006 Time: 14:50:56 Pager 1 Field: Colville River Unit Co-ordinate(NE) Reference: Well: Plan: CD4-213, True North Site: Alpine CD4 Vertical (TVD) Reference: Plan:. CD4-213 56.2 Well: Plan: CD4-213 Section (VS) Reference: We1F (Q.OON,O.OOE,300.64Azi) Wellpath: Plan: CD4-213 Survey Calculation Method: Minimum Curvature Db: Oracle Plan: CD4-213wp05 Date Composed: 11/14/2006 Version: 7 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 Zoue: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Site: Alpine CD4 Site Position: Northing: 5957526.10 ft Latitude: 70 17 32.966 N From: Map Easting: 378174.70 ft Longitude: 150 59 10.763 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -0.93 deg Well: Plan: CD4-213 Slot Name: Alpine CD4 Well Position: +N/-S -59.84 ft Northing: 5957470.04 ft 'Latitude: 70 17 32.377 N +E/-W -232.69 ft Easting : 377941.09 ft ' Longitude: 150 59 17.544 W Position Uncertainty: 0.00 ft Wellpath: Plan: CD4-213 Drilled From: Well Ref. Point Tie-on Depth: 36.30 ft Current Datum: Plan: CD4-213 Height 56.20 ft Above System Datum: Mean Sea Level Magnetic Data: 12/1/2004 Declination: 23.79 deg Field Strength: 57501 nT Mag Dip Angle: 80.61 deg Vertcal Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.30 0.00 0.00 300.64 Survey Program for Definitive Wellpath Date: 11/14/2006 Validated: No Version: 3 Actual From To Survey Toolcode Tool Name ft ft Plan Section Information MD ft Inc! deg Azim deg TVD ft +N/-S ft +E/-W ft DLS Build Turn deg/100ft deg/100ft deg/100ft TFO deg Target 36. 30 0. 00 0. 00 36. 30 0. 00 0. 00 0.00 0.00 0.00 0.00 400. 00 0. 00 0. 00 400. 00 0. 00 0. 00 0.00 0.00 0.00 0.00 1000. 00 12. 00 196. 50 995. 62 -60. 02 -17. 78 2.00 2.00 0.00 196.50 2059. 09 43. 30 210. 63 1922. 87 -489. 13 -239. 83 3.00 2.96 1.33 18.55 6449. 90 43. 30 210. 63 5118. 39 -3080. 15 -1774. 26 0.00 0.00 0.00 0.00 8240. 60 84. 00 334. 07 6201. 20 -2684. 25 -2794. 67 6.00 2.27 6.89 119.55 CD4-213wp04 T1 8338. 20 86. 93 334. 07 6208. 92 -2596. 77 -2837. 21 3.00 3.00 0.00 0.00 9038. 12 86. 93 334. 07 6246. 45 -1968. 21 -3142. 82 0.00 0.00 0.00 0.00 9140. 53 90. 00 334. 07 6249 .20 -1876. 16 -3187. 57 3.00 3.00 0.00 0.00 CD4-213wp04 T2 9249. 22 93. 26 334. 07 6246 .11 -1778. 45 -3235. 08 3.00 3.00 0.00 -0.01 9931. 60 93. 26 334. 07 6207 .29 -1165. 77 -3532. 98 0.00 0.00 0.00 0.00 10040. 30 90. 00 334. 08 6204 .20 -1068. 06 -3580. 48 3.00 -3.00 0.01 179.89 CD4-213wp04 T3 10149. 00 86. 74 334. 08 6207 .29 -970. 35 -3627. 98 3.00 -3.00 0.00 180.00 10831. 32 86. 74 334. 08 6246 .11 -357. 68 -3925. 79 0.00 0.00 0.00 0.00 10940. 03 90. 00 334. 07 6249 .20 -259. 97 -3973. 28 3.00 3.00 0.00 -0.03 CD4-213wp04 T4 11022. 12 92. 46 334. 07 6247 .44 -186. 15 -4009. 16 3.00 3.00 0.00 0.00 12057. 04 92. 46 334. 07 6202 .96 743. 75 -4461. 21 0.00 0.00 0.00 0.00 12139. 13 90. 00 334. 07 6201 .20 817. 56 -4497. 09 3.00 -3.00 -0.01 -179.90 CD4-213wp04 T5 12256. 31 86. 48 334. 07 6204 .79 922. 88 -4548. 30 3.00 -3.00 0.00 -180.00 12921. 90 86 .48 334. 07 6245 .61 1520. 34 -4838. 79 0.00 0.00 0.00 0.00 13039 .08 90 .00 334. 07 6249 .20 1625. 66 -4889. 99 3.00 3.00 0.00 0.00 CD4-213wp04 T6 13101 .58 91 .87 334. 07 6248 .18 1681. 85 -4917. 32 3.00 3.00 0.00 0.00 14537 .37 - 91 .87 334. 07 6201 .20 - 2972. 41 -5544 .80 0.00 0.00 0.00 0.00 CD4-213wp04 T7 ^?!GINAL WELL DETAILS lame +N/-S +E/-W Northing Easting Latitude Longitude Slot lan: CD4-213 -59.84 -232.69 5957470.04 377941.09 70°1T32.377N 150°59'17.544W N/A WELLPATH DETAILS Plan: CD4-213 Rig: Doyon 19 Ref. Datum: Plan: CD4-213 56.20ft V.Section Origin Origin Starting Angle +N/-S +E/-W From TVD 300.64° 0.00 0.00 36.30 T M Azimuths to True North Magnetic North: 23.79° Magnetic Field Strength: 57501 nT Dip Angle: 80.61 ° Date: 12/1/2004 Model: bggm2006 SURVEY PROGRAM Depth Fm Depth To Survey/Plan Tool 36.30 1000.00 Planned: CD4-213wp05 V7 CB-GYRO-SS 1000.00 14537.37 Planned: CD4-213vvp05 V7 MWD+IFR-AK-CAZ-SC 4001 200 -200 i i i o~ ,.e i ~ -400 CD4-213 OS 4 ' ~~ 3~Op pp0 Op o~ b~ g00o S~ Op 30 200 o a u 43° F 400 b0 600 0~0 ° ~ CD4-213 OS W C N o o w o ~ -2000 0 2000 4000 6000 8000 Vertical Section at 300.64° [2000fVin] -bUVU -4VUU -000U v West(-)/East(+) [2000fl/in] PLAN DETAILS CD4-213vvp05 Version 7 11/14/2006 Start Point MD Inc Azi TVD +N/-S +E/-W 36.30 0.00 0.00 36.30 0.00 0.00 HpLLIBUATDN ~QnO~ Phillips -- Sperry DrHling Sowicss -- ,A~aSIC~ REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Centre: Plan: CD4-213, True North Vertical (TVD) Reference: Plan: CD4-213 56.20 Section (VS) Reference: Slot- (O.OON,O.OOE) Measured Depth Reference: Plan: CD4-213 56.20 Calculation Method: Minimum Curvature • ConocoPhillips Alaska, Inc. CPAI Report Company: Field: ConocoPhillips Alaska Inc. Colville River Unit Date: 11/30/2006 Time: 14:50:56 Co-ordinate(NE) Reference: Well: Plan: CD4-213, True Page: 2 North - Site: Alpine CD4 Vertical (TVD) Reference: Plan: CD4-213 56 .2 Well: Plan: CD4-2 13 Section (VS) Reference: Well (O.OON,O.OOE,300.64Azi) Wellpath: Plan: CD4-2 13 Survey Calculation Method: .Minim um Curvature - Db: Oracle Survey MD Incl Azim 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 36. 30 0.00 0.00 36.30 -19.90 0.00 0.00 5957470.04 377941.09 0.00 0.00 100. 00 0.00 0.00 100.00 43.80 0.00 0.00 5957470.04 377941.09 0.00 0.00 200. 00 0.00 0.00 200.00 143.80 0.00 0.00 5957470.04 377941.09 0.00 0.00 300. 00 0.00 0.00 300.00 243.80 0.00 0.00 5957470.04 377941.09 0.00 0.00 400. 00 0.00 0.00 400.00 343.80 0.00 0.00 5957470.04 377941.09 0.00 0.00 KOP; 2 DLS, 40 ' 500. 00 2.00 196.50 499.98 443.78 -1.67 -0.50 5957468.38 377940.57 2.00 -0.43 600. 00 4.00 196.50 599.84 543.64 -6.69 -1.98 5957463.38 377939.00 2.00 -1.70 700. 00 6.00 196.50 699.45 643.25 -15.05 -4.46 5957455.07 377936.39 2.00 -3.83 800. 00 8.00 196.50 798.70 742.50 -26.73 -7.92 5957443.44 377932.74 2.00 -6.81 900. 00 10.00 196.50 897.47 841.27 -41.73 -12.36 5957428.52 377928.05 2.00 -10.63 1000. 00 12.00 196.50 995.62 939.42 -60.02 -17.78 5957410.32 377922.34 2.00 -15.29 Build; 3 DLS, 10 1100. 00 14.87 200.22 1092.88 1036.68 -82.04 -25.17 5957388.43 377914.59 3.00 -20.16 1200. 00 17.79 202.75 1188.83 1132.63 -108.18 -35.51 5957362.46 377903.83 3.00 -24.58 1300. 00 20.73 204.58 1283.23 1227.03 -138.37 -48.79 5957332.49 377890.07 3.00 -28.54 1378. 43 23.04 205.70 1356.00 1299.80 -164.82 -61.22 5957306.25 377877.21 3.00 -31.33 Base Permafrost 1400. 00 23.68 205.98 1375.80 1319.60 -172.52 -64.95 5957298.61 377873.36 3.00 -32.04 1500. 00 26.65 207.08 1466.30 1410.10 -210.55 -83.96 5957260.90 377853.73 3.00 -35.07 1600. 00 29.62 207.97 1554.48 1498.28 -252.35 -105.76 5957219.46 377831.26 3.00 -37.62 1700. 00 32.59 208.72 1640.09 1583.89 -297.80 -130.29 5957174.42 377805.99 3.00 -39.67 1800. 00 35.57 209.35 1722.91 1666.71 -346.78 -157.49 5957125.89 377778.00 3.00 -41.23 1900. 00 38.55 209.90 1802.70 1746.50 -399.16 -187.29 5957074.01 377747.36 3.00 -42.29 2000. 00 41.54 210.38 1879.25 1823.05 -454.79 -219.59 5957018.91 377714.16 3.00 -42.84 2059. 09 43.30 210.63 1922.87 1866.67 -489.13 -239.83 5956984.91 377693.37 3.00 -42.94 Sail; 43.3° for 43 2100. 00 43.30 210.63 1952.64 1896.44 -513.27 -254.12 5956961.01 377678.69 0.00 -42.94 2200. 00 43.30 210.63 2025.42 1969.22 -572.28 -289.07 5956902.58 377642.79 0.00 -42.95 2300. 00 43.30 210.63 2098.20 2042.00 -631.29 -324.02 5956844.15 377606.89 0.00 -42.95 2400. 00 43.30 210.63 2170.98 2114.78 -690.30 -358.96 5956785.72 377571.00 0.00 -42.96 2448. 13 43.30 210.63 2206.00 2149.80 -718.70 -375.78 5956757.60 377553.72 0.00 -42.96 C-40 2500. 00 43.30 210.63 2243.75 2187.55 -749.31 -393.91 5956727.29 377535.10 0.00 -42.96 2600. 00 43.30 210.63 2316.53 2260.33 -808.32 -428.86 5956668.86 377499.20 0.00 -42.97 2700. 00 43.30 210.63 2389.31 2333.11 -867.33 -463.80 5956610.43 377463.31 0.00 -42.98 2714. 69 43.30 210.63 2400.00 2343.80 -876.00 -468.94 5956601.84 377458.03 0.00 -42.98 9 5/8" 2722. 94 43.30 210.63 2406.00 2349.80 -880.86 -471.82 5956597.03 377455.07 0.00 -42.98 C-30 2800. 00 43.30 210.63 2462.09 2405.89 -926.34 -498.75 5956552.00 377427.41 0.00 -42.98 2900. 00 43.30 210.63 2534.86 2478.66 -985.35 -533.70 5956493.57 377391.51 0.00 -42.99 3000. 00 43.30 210.63 2607.64 2551.44 -1044.36 -568.64 5956435.14 377355.61 0.00 -43.00 3100. 00 43.30 210.63 2680.42 2624.22 -1103.37 -603.59 5956376.71 377319.72 0.00 -43.00 3200 .00 43.30 210.63 2753.19 2696.99 -1162.38 -638.53 5956318.28 377283.82 0.00 -43.01 3224 .47 43.30 210.63 2771.00 2714.80 -1176.82 -647.08 5956303.98 377275.04 0.00 -43.01 C-20 3300 .00 43.30 210.63 2825.97 2769.77 -1221.39 -673.48 5956259.85 377247.92 0.00 -43.02 3400 .00 43.30 210.63 2898.75 2842.55 -1280.40 -708.43 5956201.42 377212.03 0.00 -43.02 3500 .00 43.30 210.63 2971.53 2915.33 -1339.41 -743.37 5956142.99 377176.13 0.00 -43.03 3600 .00 43.30 210.63 3044.30 2988.10 -1398.42 -778.32 5956084.56 377140.23 0.00 -43.04 3700 .00 43.30 210.63 3117.08 3060.88 -1457.43 -813.27 5956026.13 377104.33 0.00 -43.04 3800 .00 43.30 210.63 3189.86 3133.66 -1516.44 -848.21 5955967.70 377068.44 0.00 -43.05 3900 .00 43.30 210.63 3262.64 3206.44 -1575.45 -883.16 5955909.27 377032.54 0.00 -43.06 4000 .00 43.30 210.63 3335.41 3279.21 -1634.46 -918.11 5955850.84 376996.64 0.00 -43.06 4100 .00 43.30 210.63 3408.19 3351.99 -1693.47 -953.05 5955792.41 376960.75 0.00 -43.07 4200 .00 43.30 210.63 3480.97 3424.77 -1752.48 -988.00 5955733.98 376924.85 0.00 -43.08 4300 .00 43.30 210.63 3553.75 3497.55 -1811.49 -1022.95 5955675.55 376888.95 0.00 -43.08 4400 .00 43.30 210.63 3626.52 3570.32 -1870.50 -1057.89 5955617.12 376853.06 0.00 -43.09 4500 .00 43.30 210.63 3699.30 3643.10 -1929.51 -1092.84 5955558.69 376817.16 0.00 -43.09 4600 .00 43.30 210.63 3772.08 3715.88 -1988.52 -1127.79 5955500.26 376781.26 0.00 -43.10 D ~ ORIGINAL onocoPhillips Alaska, Inc. CPAI Report Company: Field: ConocoPhillips Alaska Inc. Colville River Unit Date: 11/30/2006 Time: 14 Co-ordinate(NE} Reference:. Well: :50:56 Plan: CD4-213, True Page: 3 North Site: Alpine CD4 Vertica l (TVD) Reference: Pl an: CD4-213 56.2 We1L• Plan: CD4-213 Section (VS}Reference: Well (O.OON,O.OOE,300.64Azi) Wellpatb: Plan: CD4-213 Survey Calculation Metbod: Minimum Curvature Db: Oracle Survey MD Iucl Azim 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 4694. 70 43. 30 210. 63 3841. 00 3784. 80 -2044. 40 -1160.88 5955444.92 376747. 27 0.00 -43.11 K-3 4700. 00 43. 30 210. 63 3844. 86 3788. 66 -2047. 53 -1162.73 5955441.83 376745. 36 0.00 -43.11 4800. 00 43. 30 210. 63 3917. 63 3861. 43 -2106. 54 -1197.68 5955383.40 376709. 47 0.00 -43.11 4900. 00 43. 30 210. 63 3990. 41 3934. 21 -2165. 55 -1232.63 5955324.97 376673. 57 0.00 -43.12 5000. 00 43. 30 210. 63 4063. 19 4006. 99 -2224. 56 -1267.57 5955266.54 376637. 67 0.00 -43.13 5058. 83 43. 30 210. 63 4106. 00 4049. 80 -2259. 27 -1288.13 5955232.17 376616. 56 0.00 -43.13 K-2 (Qannik) 5100. 00 43. 30 210. 63 4135. 97 4079. 77 -2283. 57 -1302.52 5955208.11 376601. 78 0.00 -43.13 5200. 00 43. 30 210. 63 4208. 74 4152. 54 -2342. 58 -1337.47 5955149.68 376565. 88 0.00 -43.14 5216. 84 43. 30 210. 63 4221. 00 4164. 80 -2352. 52 -1343.35 5955139.84 376559. 83 0.00 -43.14 K-2_Base 5300. 00 43. 30 210. 63 4281. 52 4225. 32 -2401. 59 -1372.41 5955091.25 376529. 98 0.00 -43.15 5400. 00 43. 30 210. 63 4354. 30 4298. 10 -2460. 60 -1407.36 5955032.82 376494. 08 0.00 -43.15 5500. 00 43. 30 210. 63 4427. 08 4370. 88 -2519. 61 -1442.31 5954974.39 376458. 19 0.00 -43.16 5600. 00 43. 30 210. 63 4499. 85 4443. 65 -2578. 62 -1477.25 5954915.96 376422. 29 0.00 -43.17 5700. 00 43. 30 210. 63 4572. 63 4516. 43 -2637. 63 -1512.20 5954857.53 376386. 39 0.00 -43.17 5800. 00 43. 30 210. 63 4645. 41 4589. 21 -2696. 64 -1547.14 5954799.10 376350. 50 0.00 -43.18 5900. 00 43. 30 210. 63 4718. 18 4661. 98 -2755. 65 -1582.09 5954740.67 376314. 60 0.00 -43.19 6000. 00 43. 30 210. 63 4790. 96 4734. 76 -2814. 66 -1617.04 5954682.24 376278. 70 0.00 -43.19 6100 .00 43. 30 210. 63 4863. 74 4807. 54 -2873. 67 -1651.98 5954623.81 376242. 80 0.00 -43.20 6200 .00 43. 30 210. 63 4936. 52 4880. 32 -2932. 68 -1686.93 5954565.38 376206. 91 0.00 -43.21 6300 .00 43. 30 210. 63 5009. 29 4953. 09 -2991. 69 -1721.88 5954506.95 376171. 01 0.00 -43.21 6400 .00 43. 30 210. 63 5082. 07 5025. 87 -3050 .70 -1756.82 5954448.52 376135. 11 0.00 -43.22 6449 .90 43. 30 210. 63 5118. 39 5062. 19 -3080 .15 -1774.26 5954419.36 376117. 20 0.00 -43.22 Build; 6 DLS for 6500 .00 41. 88 214 .55 5155. 28 5099. 08 -3108 .71 -1792.51 5954391.10 376098. 50 6.00 -42.08 6600 .00 39. 49 223 .00 5231. 16 5174. 96 -3159 .50 -1833.16 5954340.98 376057. 03 6.00 -32.99 6700 .00 37. 76 232 .21 5309. 34 5253. 14 -3201 .56 -1879.09 5954299.68 376010. 43 6.00 -14.91 6800 .00 36. 81 242 .00 5388. 98 5332. 78 -3234 .41 -1929.78 5954267.65 375959. 21 6.00 11.97 6900 .00 36. 68 252 .04 5469 .18 5412. 98 -3257 .71 -1984.69 5954245.25 375903. 93 6.00 47.34 7000 .00 37. 39 261 .94 5549 .08 5492. 88 -3271 .19 -2043.22 5954232.72 375845 .20 6.00 90.82 7100 .00 38. 88 271 .35 5627 .80 5571. 60 -3274 .71 -2104.71 5954230.20 375783 .67 6.00 141.93 7200 .00 41. 08 280 .05 5704 .48 5648. 28 -3268 .23 -2168.50 5954237.72 375719 .99 6.00 200.12 7300 .00 43. 88 287 .92 5778 .28 5722 .08 -3251 .82 -2233.89 5954255.18 375654 .88 6.00 264.74 7400 .00 47. 16 294 .97 5848 .38 5792 .18 -3225 .67 -2300.16 5954282.41 375589 .05 6.00 335.09 7426 .14 48. 08 296 .68 5866 .00 5809 .80 -3217 .25 -2317.54 5954291.10 375571 .82 6.00 354.33 Albian 97 7500 .00 50. 82 301 .26 5914 .03 5857 .83 -3190 .04 -2366.59 5954319.11 375523 .22 6.00 410.40 7600 .00 54 .79 306 .92 5974 .49 5918 .29 -3145 .35 -2432.45 5954364.86 375458 .10 6.00 489.84 7700 .00 59 .00 312 .02 6029 .12 5972 .92 -3092 .07 -2497.01 5954419.18 375394 .42 6.00 572.54 7800 .00 63 .39 316 .69 6077 .31 6021 .11 -3030 .79 -2559.57 5954481.46 375332 .86 6.00 657.60 7900 .00 67 .93 321 .01 6118 .52 6062 .32 -2962 .18 -2619.44 5954551.02 375274 .12 6.00 744.08 8000 .00 72 .57 325 .05 6152 .32 6096 .12 -2887 .00 -2675.98 5954627.11 375218 .81 6.00 831.04 8100 .00 77 .28 328 .89 6178 .33 6122 .13 -2806 .07 -2728.55 5954708.88 375167 .57 6.00 917.52 8153 .79 79 .84 330 .90 6189 .00 6132 .80 -2760 .46 -2754.99 5954754.90 375141 .88 6.00 963.50 Top Nanuq 8200 .00 82 .05 332 .60 6196 .27 6140 .07 -2720 .26 -2776.58 5954795.44 375120 .94 6.00 1002.57 8240 .60 84 .00 334 .07 6201 .20 6145 .00 -2684 .25 -2794.67 5954831.74 375103 .44 6.00 1036.49 CD4-213wp04 T 8300 .00 85 .78 334 .07 6206 .49 6150 .29 -2631 .05 -2820.54 5954885.35 375078 .44 3.00 1085.86 8338 .20 86 .93 334 .07 6208 .92 6152 .72 -2596 .77 -2837.21 5954919.89 375062 .33 3.00 1117.67 8400 .00 86 .93 334 .07 6212 .23 6156 .03 -2541 .26 -2864.19 5954975.82 375036 .26 0.00 1169.18 8500 .00 86 .93 334 .07 6217 .60 6161 .40 -2451 .46 -2907.85 5955066.32 374994 .06 0.00 1252.51 8600 .00 86 .93 334 .07 6222 .96 6166 .76 -2361 .66 -2951.52 5955156.81 374951 .86 0.00 1335.85 8700 .00 86 .93 334 .07 6228 .32 6172 .12 -2271 .85 -2995.18 5955247.30 374909 .67 0.00 1419.18 8800 .00 86 .93 334 .07 6233 .68 6177 .48 -2182 .05 -3038.85 5955337.80 374867 .47 0.00 1502.52 8900.00 86 .93 334 .07 6239 .05 6182 .85 -2092 .25 -3082.51 5955428.29 374825 .27 0.00 1585.85 9000.00 86 .93 334 .07 6244 .41 6188 .21 -2002 .44 -3126.17 5955518.78 374783 .08 0.00 1669.19 n~+.r~RIAL ConocoPhillips Alaska., Inc. CPAI Report Company: Field: ConocoPhillips Alaska Inc. Colville River Unit Date: 11!30!2006 -Timer 14 Co-ordinate(NE) Reference: Well: :50:56 Plan: CD4-213, True Page: 4 North Site: Alpine CD4 Vertica l (TVD) Reference: Plan: CD4-213 56.2 We1L• Plan: CD4-2 13 Section (VS) Reference: Well (O.OON,O.OOE,300 .64Azi) Wellpath: Plan: CD4-2 13 Survey Calculation Method: M inimum Curvature. Db: Oracle Survey MD Inc! Azim 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 9038. 12 86. 93 334.07 6246. 45 6190. 25 -1968. 21 -3142. 82 5955553. 28 374766. 99 0.00 1700. 95 9100. 00 88. 78 334.07 6248. 77 6192. 57 -1912. 60 -3169. 86 5955609. 32 374740. 86 3.00 1752. 56 9140. 53 90. 00 334.07 6249. 20 6193. 00 -1876. 16 -3187. 57 5955646. 04 374723. 74 3.00 1786. 38 CD4-213wp04 T 9200. 00 91. 78 334.07 6248. 27 6192. 07 -1822. 68 -3213. 58 5955699. 93 374698. 61 3.00 1836. 00 9249. 22 93. 26 334.07 6246. 11 6189. 91 -1778. 45 -3235. 08 5955744. 49 374677. 83 3.00 1877. 04 9300. 00 93. 26 334.07 6243. 22 6187. 02 -1732. 86 -3257. 25 5955790. 43 374656. 41 0.00 1919. 35 9400. 00 93. 26 334.07 6237. 53 6181. 33 -1643. 08 -3300. 90 5955880. 91 374614. 22 0.00 2002. 67 9500. 00 93. 26 334.07 6231. 84 6175. 64 -1553. 29 -3344. 56 5955971. 39 374572. 03 0.00 2085. 99 9600. 00 93. 26 334.07 6226. 15 6169. 95 -1463. 50 -3388. 22 5956061. 86 374529. 84 0.00 2169. 31 9700. 00 93. 26 334.07 6220. 47 6164. 27 -1373. 71 -3431. 87 5956152. 34 374487. 65 0.00 2252. 63 9800. 00 93. 26 334.07 6214. 78 6158. 58 -1283. 93 -3475. 53 5956242. 82 374445. 46 0.00 2335. 95 9900. 00 93. 26 334.07 6209. 09 6152. 89 -1194. 14 -3519. 18 5956333. 29 374403. 27 0.00 2419. 28 9931. 60 93. 26 334.07 6207. 29 6151. 09 -1165. 77 -3532. 98 5956361. 89 374389. 94 0.00 2445. 61 10000. 00 91. 21 334.07 6204. 63 6148. 43 -1104. 30 -3562. 86 5956423. 82 374361. 06 3.00 2502. 64 10040 .30 90. 00 334.08 6204. 20 6148. 00 -1068. 06 -3580. 48 5956460. 34 374344. 04 3.00 2536. 27 CD4-213wp04 T 10100 .00 88. 21 334.08 6205. 13 6148. 93 -1014. 37 -3606. 58 5956514. 44 374318. 82 3.00 2586. 08 10149 .00 86. 74 334.08 6207. 29 6151. 09 -970 .35 -3627. 98 5956558. 80 374298. 14 3.00 2626 .93 10200 .00 86. 74 334.08 6210. 19 6153. 99 -924 .56 -3650. 23 5956604. 95 374276. 63 0.00 2669 .42 10300 .00 86. 74 334.08 6215. 88 6159. 68 -834 .76 -3693. 88 5956695. 43 374234. 45 0.00 2752 .74 10400 .00 86. 74 334.08 6221. 57 6165. 37 -744 .97 -3737 .53 5956785. 91 374192. 27 0.00 2836 .05 10500 .00 86. 74 334.08 6227. 26 6171. 06 -655 .18 -3781 .17 5956876. 39 374150. 09 0.00 2919 .36 10600 .00 86. 74 334.08 6232. 95 6176. 75 -565 .39 -3824 .82 5956966. 87 374107. 91 0.00 3002 .68 10700 .00 86. 74 334.08 6238 .64 6182. 44 -475 .59 -3868 .47 5957057. 35 374065. 73 0.00 3085 .99 10800 .00 86. 74 334.08 6244 .33 6188. 13 -385 .80 -3912 .11 5957147. 84 374023. 55 0.00 3169 .31 10831 .32 86. 74 334.08 6246 .11 6189. 91 -357 .68 -3925 .79 5957176. 18 374010 .34 0.00 3195 .41 10900 .00 88. 80 334.08 6248 .78 6192. 58 -295 .96 -3955 .79 5957238. 37 373981 .35 3.00 3252 .67 10940 .03 90. 00 334.07 6249 .20 6193. 00 -259 .97 -3973 .28 5957274. 64 373964 .44 3.00 3286 .07 CD4-213wp04 T 11000 .00 91. 80 334.07 6248 .26 6192 .06 -206 .04 -3999 .50 5957328. 98 373939 .11 3.00 3336 .11 11022 .12 92. 46 334.07 6247 .44 6191 .24 -186 .15 -4009 .16 5957349. 02 373929 .77 3.00 3354 .56 11100 .00 92. 46 334.07 6244 .09 6187 .89 -116 .18 -4043 .18 5957419. 53 373896 .89 0.00 3419 .49 11200 .00 92. 46 334.07 6239 .79 6183 .59 -26 .32 -4086 .86 5957510. 07 373854 .68 0.00 3502 .86 11300 .00 92. 46 334.07 6235 .50 6179 .30 63 .53 -4130 .54 5957600 .62 373812 .47 0.00 3586 .24 11400 .00 92. 46 334.07 6231 .20 6175 .00 153 .38 -4174 .22 5957691 .16 373770 .26 0.00 3669 .61 11500 .00 92. 46 334.07 6226 .90 6170 .70 243 .24 -4217 .90 5957781 .70 373728 .05 0.00 3752 .99 11600 .00 92 .46 334.07 6222 .60 6166 .40 333 .09 -4261 .58 5957872 .25 373685 .84 0.00 3836 .36 11700 .00 92 .46 334.07 6218 .31 6162 .11 422 .94 -4305 .26 5957962 .79 373643 .63 0.00 3919 .73 11800 .00 92 .46 334.07 6214 .01 6157 .81 512 .80 -4348 .94 5958053 .33 373601 .41 0.00 4003 .11 11900 .00 92 .46 334.07 6209 .71 6153 .51 602 .65 -4392 .61 5958143 .88 373559 .20 0.00 4086 .48 12000 .00 92 .46 334.07 6205 .42 6149 .22 692 .50 -4436 .29 5958234 .42 373516 .99 0.00 4169 .86 12057 .04 92 .46 334.07 6202 .96 6146 .76 743 .75 -4461 .21 5958286 .06 373492 .92 0.00 4217 .41 12100 .00 91 .17 334.07 6201 .60 6145 .40 782 .37 -4479 .98 5958324 .98 373474 .77 3.00 4253 .25 12139 .08 90 .00 334.07 6201 .20 6145 .00 817 .52 -4497 .07 5958360 .39 373458 .26 3.00 4285 .86 T5 12139 .13 90 .00 334.07 6201 .20 6145 .00 817 .56 -4497 .09 5958360 .44 373458 .24 3.00 4285 .90 CD4-213wp04 T 12200 .00 88 .17 334.07 6202 .17 6145 .97 872 .29 -4523 .70 5958415 .59 373432 .52 3.00 4336 .69 12256 .31 86 .48 334.07 6204 .79 6148 .59 922 .88 -4548 .30 5958466 .57 373408 .75 3.00 4383 .63 12300 .00 86 .48 334.07 6207 .47 6151 .27 962 .10 -4567 .36 5958506 .08 373390 .33 0.00 4420 .02 12400 .00 86 .48 334.07 6213 .60 6157 .40 1051 .86 -4611 .01 5958596 .54 373348 .15 0.00 4503 .32 12500 .00 86 .48 334.07 6219 .74 6163 .54 1141 .62 -4654 .65 5958686 .99 373305 .97 0.00 4586 .62 12600 .00 86 .48 334.07 6225 .87 6169 .67 1231 .39 -4698 .30 5958777 .44 373263 .79 0.00 4669 .92 12700 .00 86 .48 334.07 6232 .00 6175 .80 1321 .15 -4741 .94 5958867 .90 373221 .62 0.00 4753 .22 12800 .00 86 .48 334.07 6238 .13 6181 .93 1410 .92 -4785 .59 5958958 .35 373179 .44 0.00 4836 .52 12900 .00 86 .48 334.07 6244 .26 6188 .06 1500 .68 -4829 .23 5959048 .80 373137 .26 0.00 4919.81 12921 .90 86 .48 334.07 6245 .61 6189 .41 1520 .34 -4838 .79 5959068 .61 373128 .03 0.00 4938.05 ~~~1~~L • ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Field: Colville River Unit Date: 11/30/2006 Time: 14:50:56 Page:. 5 Co-ordinate(NE) Reference: WeIL• Plan: CD4-213, True North Site: Alpine CD4 Vertica l (TVD) Reference: Pl an: C D4-213 56.2 Well: Plan: CD4-213 Section (VS) Reference: Well (O. OON,O.OQE,300 .64Azi) Wellpath: Plan: CD4-213 Survey Calculation Method: M inimum Curvature Db: Oracle Survey MD Incl Azim 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 13000.00 88.83 334.07 6248. 80 6192. 60 1590.51 -4872.91 5959139. 33 373095. 05 3.00 5003. 18 13039.08 90.00 334.07 6249. 20 6193. 00 1625.66 -4889.99 5959174. 74 373078. 54 3.00 5035. 79 CD4-213wp04 T 13100.00 91.83 334.07 6248. 23 6192. 03 1680.43 -4916.63 5959229. 94 373052. 80 3.00 5086. 62 13101.58 91.87 334.07 6248. 18 6191. 98 1681.85 -4917.32 5959231. 37 373052. 13 3.00 5087. 94 13200.00 91.87 334.07 6244. 96 6188. 76 1770.32 -4960.33 5959320. 51 373010. 57 0.00 5170. 03 13300.00 91.87 334.07 6241. 69 6185. 49 1860.21 -5004.03 5959411. 09 372968. 33 0.00 5253. 44 13400.00 91.87 334.07 6238. 41 6182. 21 1950.09 -5047.74 5959501. 66 372926. 10 0.00 5336. 85 13500.00 91.87 334.07 6235. 14 6178. 94 2039.98 -5091.44 5959592. 24 372883. 86 0.00 5420. 26 13600.00 91.87 334.07 6231. 87 6175. 67 2129.86 -5135.14 5959682. 82 372841. 63 0.00 5503. 67 13700.00 91.87 334.07 6228. 60 6172. 40 2219.75 -5178.85 5959773. 39 372799. 40 0.00 5587. 09 13800.00 91.87 334.07 6225. 33 6169. 13 2309.63 -5222.55 5959863. 97 372757. 16 0.00 5670 .50 13900.00 91.87 334.07 6222. 05 6165. 85 2399.52 -5266.25 5959954. 54 372714. 93 0.00 5753 .91 14000.00 91.87 334.07 6218. 78 6162. 58 2489.40 -5309.96 5960045. 12 372672. 69 0.00 5837 .32 14100.00 91.87 334.07 6215. 51 6159. 31 2579.29 -5353.66 5960135. 69 372630. 46 0.00 5920 .73 14200.00 91.87 334.07 6212. 24 6156. 04 2669.17 -5397.36 5960226. 27 372588. 22 0.00 6004 .14 14300.00 91.87 334.07 6208. 97 6152. 77 2759.06 -5441.06 5960316. 84 372545. 99 0.00 6087 .55 14400.00 91.87 334.07 6205. 69 6149. 49 2848.94 -5484.77 5960407. 42 372503. 76 0.00 6170 .96 14500.00 91.87 334.07 6202. 42 6146. 22 2938.83 -5528.47 5960497. 99 372461. 52 0.00 6254 .37 -14537.37 91.87 334.07 6201 .20 ~ 6145. 00 2972.41 -5544.80 5960531. 84 372445. 74 0.00 6285 .54 CD4-213wp04 T Targets Map Map <____ Latitude ---> <--- Longitude ---> Name Descripfion TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft CD4-213wp04 T5 6201.20 817.56 -4497.09 5958360.44 373458.24 70 17 40. 405 N 151 1 28.613 W CD4-213wp04 T7 6201.20 2972.41 -5544.80 5960531.84 372445.74 70 18 1. 591 N 151 1 59.195 W CD4-213wp04 T1 6201.20 - 2684.25 -2794.67 5954831.74 375103.44 70 17 5. 973. N 151 0 38.958 W CD4-213wp04 T3 6204.20 - 1068.06 -3580.48 5956460.34 374344.04 70 17 21. 864 N 151 1 1.872 W CD4-213wp04 T2 6249.20 - 1876.16 -3187.57 5955646.04 374723.74 70 17 13. 919 N 151 0 50.414 W CD4-213wp04 T6 6249.20 1625.66 -4889.99 5959174.74 373078.54 70 17 48. 350 N 151 1 40.080 W CD4-213wp04 T4 6249.20 -259.97 -3973.28 5957274.64 373964.44 70 17 29. 810 N 151 1 13.330 W Annotation MD TVD ft ft 400.00 400.00 KOP; 2 DLS, 400' MD 1000.00 995.62 Build; 3 DLS , 1000' MD 2059.09 1922.87 Sail; 43.3° for 4390' 2714.69 2400.00 9 5/8" Csg; 2400' TVD 6449.90 5118.39 Build; 6 DLS for 1790' 8240.60 6201.20 7" Csg; 6194' TVD 9140.53 6249.20 T2 10040.30 6204.20 T3 10940.03 6249.20 T4 12139.08 6201.20 T5 13039.08 6249.20 T6 14537.36 6201.20 TD !~~!~lNAL onocoPhillips Alaska, Inc. CPAI Report Company: Field: ConocoPhillips Alaska Inc. Colville River Unit Date: 11!30/2006 Co-ordinate(NE) Reference: Time: 14:50:56 Page: 6 Well: Plan: CD4-213, True North Site: Alpine CD4 Vertical (TVD)Reference: Plan: CD4-213 56.2 WeII: Plan: CD4-213 Section (VS) Reference: Well (O.OON,O:OOE,300.64Azi) Wellpath: Plan: CD4-213 Survey Calcutafion Method: Minimum Curvature Db: Oracle Casing Points MD TVD Diameter Hole Size Name ft ft in in 2714.69 2400.00 9.625 12.250 9 5/8" 8240.60 6201.20 7.000 8.750 7" 14537.37 6201.20 6.125 6.125 6 1/8" OH Formations MD TVD Formations Lithology Dip Angle Dip Direction g ft deg deg 1378.43 1356.00 Base Permafrost 0.00 0.00 2448.13 2206.00 C-40 0.00 0.00 2722.94 2406.00 C-30 0.00 0.00 3224.47 2771.00 C-20 0.00 0.00 4694.70 3841.00 K-3 0.00 0.00 5058.83 4106.00 K-2 (Qannik) 0.00 0.00 5216.84 4221.00 K-2 Base 0.00 0.00 7426.14 5866.00 Albian 97 0.00 0.00 8153.79 6189.00 Top Nanuq 0.00 0.00 ORIGINAL i onocoPhillips Alaska, Inc. Anticollision Report Company: ConoCOPhillips Alaska Inc. Date: 11/30/2006 Time: 12:03:14 Page: I Field: Colville River Unit Reference Site: Alpine C04 Co-ordinate(NE) Refe rence: Well: Pla n: CD4-213, True North Reference Well: Plan: CD4-213 Vertical (T VD) Reference: Plan: CD4-213 56.2 Reference Wellpath: Plan: CD4-213 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Refe rence: Plan: CD4-213wp05 & NOT PLANNED P Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 36.30 to 14537.37 ft Scan Method: Trav Cylinder North Maximum Radius: 1650.11 ft Error Surface: Ellipse + Casing Casing Points MD TVD Diameter Hole Size Name ft ft in in 2714.69 2400.00 9.625 12.250 9 5/8" 8240.60 6201.20 7.000 8.750 7" 14537.37 6201.20 6.125 6.125 6 1/8" OH Plan: CD4-213wp05 Date Composed: 11/14/2006 Version: 5 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 CD2 CD2-37 CD2-37 V17 14214.49 17085.00 1243.46 184.07 1059.40 Pass: Major Risk Alpine CD2 CD2-60 CD2-60 V9 Out of range Alpine CD4 CD4-17 CD4-17 V13 300.09 300.00 80.98 6.25 74.72 Pass: Major Risk Alpine CD4 CD4-208 CD4-208 V7 450.11 450.00 99.25 7.57 91.68 Pass: Major Risk Alpine CD4 CD4-208 CD4-208P61 V6 450.11 450.00 99.25 7.46 91.79 Pass: Major Risk Alpine CD4 CD4-209 CD4-209 V4 498.50 500.00 75.53 9.01 66.52 Pass: Major Risk Alpine CD4 CD4-210 CD4-210 V3 1367.67 1375.00 59.18 18.96 40.22 Pass: Major Risk Alpine CD4 CD4-318 CD4-318 V6 351.28 350.00 101.85 7.41 94.45 Pass: Major Risk Alpine CD4 CD4-318 CD4-318A V5 350.24 350.00 101.83 7.38 94.44 Pass: Major Risk Alpine CD4 CD4-318 CD4-318P61 V3 351.28 350.00 101.85 7.41 94.45 Pass: Major Risk Alpine CD4 CD4-319 CD4-319 V5 300.65 300.00 121.72 6.06 115.66 Pass: Major Risk Alpine CD4 CD4-320 CD4-320 V7 299.45 300.00 138.78 5.48 133.30 Pass: Major Risk Alpine CD4 CD4-320 CD4-320PB1 V4 299.45 300.00 138.78 5.48 133.30 Pass: Major Risk Alpine CD4 CD4-321 CD4-321 V16 300.29 300.00 160.58 6.08 154.50 Pass: Major Risk Alpine CD4 Nanuq 3 Nanuq 3 V1 11117.79 7500.00 248.81 176.39 72.42 Pass: Major Risk Alpine CD4 Nanuq 5 Nanuq 5 V1 253.49 250.00 21.90 4.57 17.32 Pass: Major Risk Alpine CD4 Nanuq 5 Plan: CD4-212 VO Plan: 253.49 250.00 21.90 4.59 17.30 Pass: Major Risk Alpine CD4 Plan: CD4-16 Plan: CD4-16 V1 Plan: 375.39 375.00 60.35 7.91 52.44 Pass: Major Risk Alpine CD4 Plan: CD4-203 Plan: CD4-203 V1 Plan: 425.19 425.00 200.44 8.73 191.71 Pass: Major Risk Alpine CD4 Plan: CD4-204 Plan: CD4-204 V1 Plan: 351.09 350.00 180.79 7.34 173.45 Pass: Major Risk Alpine CD4 Plan: CD4-205 Plan: CD4-205 V1 Plan: 498.24 500.00 161.15 10.01 151.14 Pass: Major Risk Alpine CD4 Plan: CD4-206 Plan: CD4-206 V4 Plan: 126.07 125.00 141.12 2.59 138.53 Pass: Major Risk Alpine CD4 Plan: CD4-207 Plan: CD4-207 V3 Plan: 498.04 500.00 121.12 10.01 111.11 Pass: Major Risk Alpine CD4 Plan: CD4-215 Plan: CD4-215 V2 Plan: 350.10 350.00 40.23 7.30 32.93 Pass: Major Risk Alpine CD4 Plan: CD4-222 Plan: CD4-222 V2 Plan: 350.20 350.00 180.18 7.23 172.94 Pass: Major Risk Alpine CD4 Plan: CD4-223 Plan: CD4-223 VO Plan: 777.68 775.00 187.81 13.67 174.14 Pass: Major Risk Alpine CD4 Rig: CD4-211 Plan: CD4-211 VO Plan: 449.52 450.00 40.81 9.34 31.48 Pass: Major Risk Alpine CD4 Rig: CD4-211 Rig: CD4-211 V9 399.84 400.00 39.84 7.95 31.88 Pass: Major Risk Alpine CD4 Rig: CD4-214 Plan: CD4-214 V2 Plan: 450.28 450.00 19.93 9.11 10.82 Pass: Major Risk Alpine CD4 Rig: CD4-214 Rig: CD4-214 V11 300.07 300.00 21.36 6.10 15.26 Pass: Major Risk Alpine Satellites Nanuk 2 Nanuk 2 V1 8229.99 7025.00 924.50 116.55 807.96 Pass: Major Risk )GRAM OR161N^,'_ W'EI.L UETAII.I Name +N-5 -R-W Northing Eastine LarituJc Lanein~de llot PIan:CU4-213 -59.84 -232.69 595747D O4 3]794109 70`I]'32.3]]N I50`59'I]544W NA 75 n Calculation Mrlhud. Minimum Curvature Error l~~ciem IlCWSA lean Mulhod-. Trav C~lindcr North Ertor lurDce EIIiPlical ~ Casing l d i M h R l B Wa et : u es ase rn ng m From Colour To MD 36 250 250 500 500 750 750 1000 1000 1250 1250 1500 1500 1750 1750 2000 2000 8450 8450 8700 -- 3950 )200 11700 11950 12200 12450 ?5000 4-207) arc. CD4-2060 OS~an ~U41~_(A'g- (CD4-208pB1) Rh1~5~4-212) DrpN Fm DaPd'T~ 4~nq'.Plrn, x [t~tt f~Wl I ;..p05 ~ > 1000 W Iss.~.] el..m~N eve-zisxp05 l'S en~D IFk-Ak-~,v~s~ WFILPATH DET VL5 el.~~ cvann kig. IMa~on 19 Fe( Damm: Plan: CD4.21? 54.200 lhrgm Qigm R~nmg Mglc +N'.ti -E-W' From TAD X00.64 000 000 1630 Travelling Cylinder Azimuth (TFO+AZ[) [deg] vs Centre to Centre Separation [25fUin] • 75 AN'CI-(:OLLI~ION ~IiTTMC.~ roMPnNY Df:TnIL~ Intetinilutiun MelhodMD Llle~ml 21.00 Con«oPhilliPs Alaska lac. DcPth Range Fmm. 3h.30 'Co. 14537 i7 ~Bmemng Mn<imuni Rwge 1650.11 Relar9ncu Plan CD4-213Wrr05 LEGEND CD2-171CU2-37). Major Rick ~ NnnugS(Plan CD4-212)_Malor Risk CD2-60 (CD26UT Malur Risk ~ Ylw: CD4-16 (Plan. CU4-16), Maier Risk CD4-IJ(C D4-17)-Maior Risk ~ Plw CD4-103 (Plan CD4-203). Ma)nr Risk CD4-208 iCD4-20A), Major Ruk ~ Plen:CD4-204 (Plan-CD4-2041, MnJor ROCk CD4-208 (C W-208P[3 D_Ma,l^r Rick ~ Plan CD4-205 (PInnCD4-205)_Malor Risk CD4-2U91CU9-209), Major Risk ~ Plat. CIW-206 IYlan_ CD4-2061, Mnior Risk CD4-21111CD4-210). Ma3oe Risk ~ Plan CD4-20] (Plan CD4-20]). Malur Risk CIW-318 CD4-318), Major Risk ~ PIw.CU4-2151PInn .CD4-215 ), Major Risk CIN-318 (C D1-lIRA). Malnr Rick ~ Plai CD4-2221PIan.CU4-222)_Malor Rick C[W-318 tCIW-?IRPB II, Major R~.k ~ PIw:CD4-2231PIan: CIM-2231, Mnjor Risk CD4-?19 (CI W-i 1'J ). Motor Rick ~ Rrg:CD4-211 (RigCD4-211). Major Risk CDJ-320 fCU4-?20). Mnior Risk ~ Rig: CIYI-2141 Rig. CD4-214). Major Risk CD4-J2U fCD4-320PI31). Major Risk ~ Nnnuk 2 (Nwuk 2). Major Rick CD4-321 tC1Yl-121). Mv,lor RO.k ~ Plan. CDb-213 Nwnq 3 (Nwuq J). Major Rick ~ CD4-213x1r05 Nanuq 5 ~Nwuq 5). M jot Risk Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [75fUin] lECT10N DETAILl .l'ec MD Inc nzi TVU -N.-R *F-W Ul.eg TEace V,l'ec l'areet 1 JG J0 0,(1f1 000 3630 000 U.DO Of10 (100 0.00 2 400 00 1.00 0 00 400 00 0 OU 0.00 0 00 0 00 0 00 3 1000,00 1200 196.50 995.62 -6002 -17.78 200 19650 -1529 4 2059 09 4J ?0 210 G3 1922 87 -489.13 -239 Bi i DO I S 55 -42 94 5 6449.90 4130 210.63 511%.39 -3080.15 -177426 OOU 0,01 -43.22 6 8240 60 B4 UO 334 0] fi201 20 -2684 25 -2794 67 6 (10 119 55 1036 49 CD4-213cvp04 T I 7 8]]820 BG 93 ]340] 6208.92 -259fi ]7 -283721 300 0,01 1117 G] 8 903812 8693 3340] 6246 45 -19(+821 -314282 000 000 1]0095 9 914051 9000 334,17 624920 -I N7G.16 -318757 3.f10 0,00 17%63% CD4-213tep(14'r2 10 920.9.22 9J 26 3340] 6246.11 -177845 -323508 100 -001 187704 11 9931,60 9326 334,07 620].29 -1165]7 -353298 000 0311 2445 G1 12 1004030 901111 3341N 62M 20 -106806 -358048 3.00 I]9 K9 253627 CD4-213tvp04'f3 IJ 1014900 RG']4 33408 620729 -97035 -]621-9R 3nU IRU,00 2626.93 14 10RJ1.32 R6 ]4 33408 6246.11 -357 GS -392579 000 000 319541 IS 10940.0? 90,00 334,07 6219211 -259 Y7 -3973 28 3,00 -0,03 J2R6 f17 CD4-213.ep(Il Td I6 11022.12 92.46 334,07 6247.44 -IR6.15 -1009.16 3.00 0,(10 J3S456 17 1205704 92 J6 3340] 620296 ]43 "IS -1461.21 000 O.UO 4217.41 I% 72139.13 9000 }340] 620120 RI].56 -44'1709 300 -1]990 4285.'10 C'D4-213wpOd TS 19 1225631 86 J8 331 J] 620479 922%8 -154830 300 -18000 438363 20 1292190 N6 ~% 1340] 6245 G1 1520.34 -4838.]9 0,00 000 493805 21 1101908 9000 13107 62!920 1625 G6 -188999 300 000 501579 CUL213wp(IJ TG 22 131UISA 918] 334.07 624%.IR IGR I.RS -191712 300 0.00 508794 23 145 i~3] 9187 331117 620120 297241 -5511.80 000 0.00 628554 CDi-211wp04 T7 From Colour To MD 36 250 0 cn0 500 Closest in POOL ...~+.. ~k ~ ,,.~< ~Z . /~. c+G 1,.~,..~,~., Closest Approach: Reference Well: CD4-213wp05 Plan Offset Well: Nanuq 3 Coords. - Coords. - 3-D ctr- ASP ASP ctr Mln. Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Dist. Depth Angle Azi. TVD E(+)/W(_ (300.64°) Comments Depth Angle Azi. TVD E(+)/W(_ (300.64°) Comments POOL Min POOL Min Distance (246.57 ft Distance (246.57 ft in POOL (8153 - in POOL (8153 - 14537 MD) l0 14537 MD) to CD4 Nanuq 3 (6129 - 213wp05 Plan (61 246.5 11111 92.4 3 6187.09 595742 3738 3428.61 6264 TVDss) 749 23.42 271. 6108.8 595732 373677. 3558.7 - 6264 TVDss) Closest Approach: Reference Well: CD4-213wp05 Plan Offset Well: Rig: CD4-214 Coords. - Coords. - 3-D ctr- ASP ASP ctr Min. .-: , . Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Dist. ,.-. Depth Angle Azi. TVD E(+)/W(. (300.64°) Comments Depth Angle Azi. TVD E(+)/W(_ (300.64°) Comments POOL Min POOL Min Distance (507.59 ft Distance (507.59 ft in POOL (8153 - in POOL (8153 - 14537 MD) to Rig: 14537 MD) to CD4 CD4-214 (8361 - 213wp05 Plan (8 507.5 815 79. 330. 6132.40 595475 375143. 960.745 15072 MD) 8261 83.9 147. 6120.8 595424 37512 715.3 -15072 MD) Closest Approach: Reference Well: CD4-213wp05 Plan Offset Well: Nanu k 2 Coords. - Coords. - 3-D ctr- ASP ASP ctr Min. Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Dist. Depth Angle Azi. TVD E(+)/W(_ (300.64°) Comments Depth Angle Azi. TVD E(+)/W(. (300.64°) Comments POOL Min POOL Min Distance (924.2 ft) Distance (924.2 ft) in POOL (8153 - in POOL (8153 - 14537 MD) to 14537 MD) to CD4 Nanuk 2 (6129 - 213wp05 Plan (61 924. 823 83.7 333. 6144.2 595482 375106. 1030.60 6264 TVDss) 704 1.88 27 6129.3 595442 37427 1494.8 - 6264 TVDss) Closest Approach: Reference Well: CD4-213wp05 Plan Offse t Well: Rig: CD4-211 Coards.- Coords.- 3-D dr- ASP ASP ctr Min. Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Dlst. Depth Angle Azi. TVD E(+)/W(- (300.64°) Comments Depth Angle Azi. TVD E(+)AN(- (300.64°) Comments POOL Min POOL Min Distance (1233.02 Distance (1233.02 ft) in POOL (8153 - ft) in POOL (8153 - 14537 MD) to Rig: 14537 MD) to CD4 CD4-211 (7661 - 213wp05 Plan (76 1233.0 883 86.93 3 6179.09 595536 374852. 1530.86 13674 MD) 7561 82. 150.1 6142. 59558 375966. 858.5 -13674 MD) • • CD4-213wp05 POOLSummary.xls 11/30/2006 2:31 PM i i i i 6000 0 1G9 A y°~ ~~1 4000 q~z `c~ ~oR~ ti~4~~ ~ Bel ~9~ 3zo~ 0 2000 ~9p:L~$~`'9A o~~~~ .-. R Cpl ° G~~ 20$ ~G~ u ;_ ~o~y~g~l ~ ~ Da "'~ .~ ~`, lg d ~ ~.G~ A tip9l i ?' ~ G9A ~p9 lG~ -2000 V1 ~ ~9~`~ N . ~ - ~ ~~ Z 4,~ ~,9 -4000 -6000 ice, ~, fd' i _ -12000 -10000 -80 ~'J -6000 -4000 ~ -2000 0 2000 4000 n ~ West(-)/East(-+~ [2000ft/in] ConocoPhillips Alaska HALLIBURTQN ^~ V z 1 PLAN DETAILS CD4-213wp05 Version 6 11 / 14/2006 !'1 ~ T Quarter Mile (1320 feet) radius plot CD4-211 ~.q •' °o ~~ ~~ O O `9 ' c{' i CD4-213w OS Nanuk 2 anuk 2 ~~'~' ~ ~°~ ~ Nanu 3 Nanu 3 ~ r~s~ %`~ p~ --~ ~ ~~ ~~' _ ~ • • SHARON K. ALLSUP-DRAKE 1164 CONOCOPHILLIPS ATO 1530 7 700 G $T. DATE 1551/441 ANCHORAGE AKC995y"~01~j - ~ /~~//~ (,~yJ~ /' /~~ / ~' l ORDER OF%1~ /~/ ( I ~ D~ ~`~ri/ ~ l / / /T ~C~ ! ~ ~ (v`~ .. / V .. ~~ Fem.., ~' DOLLARS ' a~~~. J PMorganChase ~ j Valid Up To 5000 Dollars JPMorgan Chase Bank, N.A. ~~ " Columbus, OH /~ ~ ~~~Y~ ~ MEMO _.._-- ---- T--- -- ~:044LL55L~~:528747L90792711'LL64 / -- • • ®evelo went Ser~~ice p Espl®rat®ry Stratggraphgc Test ®n-C®nventi®nal W"ell Circle appr®priate Letter /Paragraphs t® be Included in Transmittal Letter CHECK VV'I-LAT APPLIES ADD-ONS (OPTIONS j TEXT FOR APPROVAL LETTER vtliLTI LATERAL The permit is for a new we[lbore segment of existing w-ell ,' (If last two digits in Permit'\lo. .:4PI No. ~0- AP[ number are - between 60-69) ,Production should continue to be reported as a function of the j original AP[ number stated above. PILOT HOLE In accordance with 20 .~~C 25.00~(f), al( records, data and logs ' acquired for the pilot hole must be clearly differentiated in both ~ well name ( PH) and API number (~0- - -~ from records, data and logs I j acquired for well 'SPACING 'The permit is approved subject to full compliance with 20 AAC ; EXCEPTION ' ?~.0>j. Approval to perforate and produce % inject is contingent 'upon issuance of a conservation order approving a spacing exception. assumes the liabi[it_y of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in ;SAMPLE ! no greater than 30' sample intervals from below the permafrost or !, from where samples are first caught and 10' sample intervals ~j through target zones. I Please note the following special condition of this permit: ; Non-Conventional production or production testing of coal bed methane is not allowed 'Well for (name of well) until after (Com~anv Name) has designed and i implemented a water well testing program to provide baseline data ~,' on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing ~ nro~ram. ~ Rev: i/Z~:'06 C 'jody`~rarsmittal checklist SELL PERMIT CHECKLIST Field & Pool COLVILLE RIVER, NANUO OIL -120175 _ _ .....Well Name: COLVILLE RIV NAN-N CD4-213 Program SER Well bore seg ^ PTD#:2061730 Company CONOCOPHILLIPS ALASKA INC Initial Classlfype SER / PEND GeoArea 890 Unit 50360 On/Off Shore On Annular Disposal ^ Administration 1 Permit_fee attached. _ _ , _ _ - _ Yes - _ - - - - - . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2 Lease number appropriate. _ - . - _ - - _ - _ Yes Surface location in ADL 380077; lop prod interval in ADL 384209; TD in_ADL_380075, 3 Unique well-nameandnumbe[---- ----- - -- - -- - Yes. -- - - - -- -- --- --------- -- --- -- ~------ -- -------- - 4 Well located in a_defnedpool_ - - - - - - - _ . Yes Colville-Rivet Field,Colville River Unit, Nanuq Oil Pool, oyerned-b Conse_rvation_Order No, 562. _ _ _ _ _ _ 9 ~' 5 Well located proper distance from drilling unitboundary- - - - Yes _ - - - -Conservation Order No. 562 contains no spacing restrictions with r_espect_to drilling unit boundaries. 6 Well located proper distance from other wells. Yes Conservation Order No. 562 has no interwell_spacing_restrictigns- - - - - - - - - - - - - - - - - - - - - - - - 7 Sufficient acreage ayail_able in_drilling unit- - - - - - - - - - - - - - - - - - - - - Yes _ - _ _ - - -Conservation Order No. 562 has_no interwell_spacing_restrictions, Wellbore_will be_ more than 500' from 8 If deviated, is_we_Ilbore plat.included .. - Yes external property line where.ownership orlandownership_changes._ 9 Operator only affected party- - - - - - - - Yes - - - 10 Operator has-appropria~ebond in farce---------- ----- ------- --- -- -- Yes- --- -- -- -- -- -- - - --....- --- --- -- -- -- -- -- -- - 11 Permit can be issued without conservation order Yes Appr Date 12 Permitcan be issued without administrativ_e_appr_oval _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ -- - SFD 12!13/2006 13 Can permit be approved before 15tlay wait Yes 14 Well located within area and strata authorized by_ Injection Order # (put_IO# in_comments)_(For_ Yes Colville_River Field, Colville River Unit, Nanuq Oil Po41,govemed-byArea-Injection Order 28 _ _ _ _ - _ - - - - - 15 All wells within 1/4_mile area of review jdentified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _Nanuq 3~suspended), Nanuk 2 ~P&A), CRU CD 4-211, and CRUCD4-214_ _ - _ _ _ - _ _ - _ _ _ _ _ _ _ _ - - _ _ : - 16 Pre-produced injector; duration of pre production less than 3 months. (For service well only) No_ Clean-up_ production for 2-3-days. - - - _ - - - _ . X 17 Nonconven. gas conforms to AS31,05,030Q.t.A),O.2.A-D) - . - , - - . - , - - - - - --- - - - - - NA_ - - Engineering 18 Conductor string_provided - Yes _ - - 19 Surface casing.protects aIl_known USDWs _ NA No aquifers, A1O18A conclusion_3. - - - - 20 CMT_v_ol.adeguate_to circulate-on conductor.& surf_csg Yes - . _ _ 21 CMT.vgl. adequate-to tie-in long string to surf csg_ N_o_ Qannik sand to be covered.. Annular disposal may be proposed. - - . - - . 22 CMT_will coverall known_productive horizons- - - - - - - - - - - - - - No- - _ - - _ - -Slotted liner completion planned, Qannik interval to be cemented.. 23 Casing designs adequate for C,T,B&_permafrost_________________ _______-Yes_ _.___________ 24 Adequate tankage_o_r reserve pit - - - - - - - - - - - - - - - - - - - - - -- - - Yes - _ - _ _ - -Rig is.equipped with steel_pits. No reserue_pitplanned, All waste to approved annulus or disposal well.- - . 25 If_a_re-dill, has.a-10-403 for abandonment been approved NA- _ - _ _ - - _ - - 26 Adequate wellbore separation_propp&ed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ . _ _ _ _ Proxim(ty analysis performed, Traveling cylinder plot_provjded._ Gyros possible.- - _ _ - _ _ _ _ _ _ _ _ _ _ _ - . _ - 27 If_diverter required, does jt meet regulations.. NA- Diverter waiver requested, No historyof problems on pad. Approval recommended. _20 AAC_2.5,035(h)~2)._ , - . - Appr Date 28 Drilling fluid_program schematic & equip listadequate_ Yes _ _ - - _ Maximum expected formation pressure 8,7_EMW, PI_anned mud weight_up to 9.3 ppg. TE 12118!2006 29 BOPEs,dotheymeet_regulation------------------------- --- Yes- -----------------------------------------.-----------------------. 7""W"v/~ 30 BOPE_ptess rating appropriate; test to.(put psig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ - - _ - - MASP calculated at 2186psi, 3500_psi_appropriate. CPAI usually_tests to 5000_ psi. _ _ _ - - . _ _ - _ _ _ - - - _ - _ 31 Choke_mamfold comp_hes wlAPl_RP-53 (May 84)- - - - - - - - - . -Yes - - - - - - - - - - - 32 Work will occur without operation shutdown____-________.__---_ ______ _Yes_ _____ 33 Is presence_of H2S gas. probable No_ H2S has not_been reported at Alpine. -Rig is equipped with sensors and alarms.. - 34 Mechanical condition of wells within AOR verified (Forservice well only) - - - - - - - - - - - - - -Yes No issues were identifed for any_of the wel_Is-identified on line 15, - - _ _ - - _ - - _ _ ... - _ _ _ _ . _ _ - - - . Geology 35 Permit can be issued wlo hydrogen-sulfide measures - - - - - - - - - - - - - - - - - - -. - - . -Yes _ . - _ _ - - H2S not encountered in offset well_s._ However, rig will be equipped with_operational_sensots. _ - _ _ _ .. - - i36 Data_presented on potential overpressure zones - Yes _ _ _ _ _ - -Expected resen!oirpressure is 8,7_ppg EMW; will be drilled with 9.0-9,3_ppg mud-- - - - - - - - - - - - - - - Appr Date X37 Seismic analysis ofshallow gas_zones . . .. . .. . .... . . . . .... . . . .. . .. . NA_ Multiple wells drilled from this pad.. Hydrates or shallow gas are-unlikely; mitigation measures discussed. SFD 1211312006 38 Seabed condition survey_(ifnff.-shore) - - - - - - - - - - -- - - - - - - - - - - - - - - - - - NA - - - - - - 39 Contact namelphone for weekly-progress reports [exploratory only] NA- - _ - Geologic Engineering .c Date Date: ' Date Nanu Oil Pool in ector. q ~ Commissioner: Commissioner: m oner Dr~ / l~~~L /~rJ ! ~D/~ • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding inforTnation, 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. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Apr 03 09:57:17 2007 Reel Header Service name .............LISTPE Date .....................07/04/03 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................07/04/03 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 Nanuq 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-0004802638 D. RICHARDSO L. HILL SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD CJ Scientific Technical Services Scientific Technical Services CD4-213 501032054000 ConocoPhillips Alaska, Inc. Sperry Drilling Services 03-APR-07 24 11 4 E 2337 303 56.65 19.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.750 9.625 2713.0 2ND STRING 3RD STRING PRODUCTION STRING ~~ - /~3 ~ /578" • • REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). 5. 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 THE DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 6. MWD RUNS 1,2 REPRESENT THE SURFACE AND INTERMEDIATE SECTIONS OF WELL CD4-213 WITH API#: 50-103-20540-00. THIS WELL SEGMENT HAS A TOTAL DEPTH (TD) OF 8305'MD/6201'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 (SEDP). SLIDE = ORIENTED DRILLING AT BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2678.5 8259.0 RPD 2700.0 8251.5 RPM 2700.0 8251.5 RPS 2700.0 8251.5 • • RPX 2700.0 8251.5 FET 2700.0 8251.5 ROP 2723.5 8305.0 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 2678.5 8305.0 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 Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2678.5 8305 5491.75 11254 2678.5 8305 RPD MWD OHMM 0.51 2000 9.14147 11104 2700 8251.5 RPM MWD OHMM 0.44 1743.45 7.89747 11104 2700 8251.5 RPS MWD OHMM 0.44 1629.72 6.35146 11104 2700 8251.5 RPX MWD OHMM 0.62 247.7 6.07643 11104 2700 8251.5 FET MWD HOUR 0.2 164.8 1.80448 11104 2700 8251.5 GR MWD API 50.87 173.93 105.818 11162 2678.5 8259 ROP MWD FT/H 0.19 371.1 156.613 11164 2723.5 8305 First Reading For Entire File..........2678.5 Last Reading For Entire File...........8305 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/03 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.......07/04/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2678.5 8259.0 RPD 2700.0 8251.5 RPM 2700.0 8251.5 RPS 2700.0 8251.5 RPX 2700.0 8251.5 FET 2700.0 8251.5 ROP 2723.5 8305.0 LOG HEADER DATA DATE LOGGED: 03-JAN-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8305.0 TOP LOG INTERVAL (FT) 2723.0 BOTTOM LOG INTERVAL (FT) 8305.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 41.7 MAXIMUM ANGLE: 85.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 97054 EWR4 ELECTROMAG. RESIS. 4 127479 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.750 2713.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Polymer 9.70 39.0 9.0 400 6.0 2.150 68.0 1.193 128.0 6.900 68.0 1.620 68.0 • 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 Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2678.5 8305 5491.75 11254 2678.5 8305 RPD MWD020 OHMM 0.51 2000 9.14147 11104 2700 8251.5 RPM MWD020 OHMM 0.44 17 43.45 7.89747 11104 2700 8251.5 RPS MWD020 OHMM 0.44 16 29.72 6.35146 11104 2700 8251.5 RPX MWD020 OHMM 0.62 247.7 6.07643 11104 2700 8251.5 FET MWD020 HOUR 0.2 164.8 1.80448 11104 2700 8251.5 GR MWD020 API 50.87 1 73.93 105.818 11162 2678.5 8259 ROP MWD020 FT/H 0.19 371.1 156.613 11164 2723.5 8305 First Reading For Entire File..........2678.5 Last Reading For Entire File...........8305 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/04/03 r~ ~_~ Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date .....................07/04/03 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF ~~ Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services End Of LIS File
