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210-189
New Plugback Esets 7/18/2024 Well Name API Number PTD Number ESet Number Date 1J-162 PB2 50-029-23360-71-00 207-080 T39224 5-21-2009 CD3-125 PB1 50-103-20632-70-00 210-189 T39225 4-15-2011 CD3-301A PB1 50-103-20543-71-00 210-017 T39226 4-13-2010 KIGUN 1 PB1 50-629-23239-70-00 205-025 T39227 9-26-2005 1J-105 PB1 50-029-23346-70-00 207-027 T39228 4-23-2009 2K-28A PB1 50-103-20385-70-00 211-133 T39229 2-6-2012 2L-306 PB1 50-103-20630-70-00 210-182 T39230 4-15-2011 3A-17AL1 PB1 50-029-22691-70-00 210-114 T39231 11-24-2010 3G-22AL2 PB1 50-103-20147-70-00 212-047 T39232 7-24-2012 3H-34L1 PB1 50-103-20643-70-00 211-162 T39233 2-28-2012 3N-16AL1 PB1 50-029-21593-73-00 210-107 T39234 11-24-2010 C-12A PB1 50-029-21373-70-00 199-091 T39235 1-17-2002 ODSN-01 PB1 50-703-20648-70-00 211-166 T39236 5-3-2012 ODST-39 PB1 50-703-20572-70-00 208-040 T39237 3-22-2012 OI06-05 PB1 50-029-23437-70-00 210-165 T39238 11-3-2011 OP17-02 PB1 50-029-23431-70-00 210-125 T39239 1-3-2011 CD3-125 PB1 50-103-20632-70-00 210-189 T39225 4-15-2011 TTT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – CRU DATE: 12/19/2023 Transmitted: North Slope, Colville River Unit data drophard driveVia CD2-45 50-103-20395-00 201212_CD2-45_Patch_15May2023 CD2-53 50-103-20494-00 204089_CD2-53_LDL_30Nov2022 204089_CD2-53_Patch_14Oct2022 CD3-107 50-103-20529-01 206189_CD3-107_Packer_16Apr2022 CD3-125 50-103-20632-00 210189_CD3-125_LDL_23Feb23 210189_CD3-125_POGLM_03Apr2023 CD3-127 50-103-20634-00 211005_CD3-127_Patch_23Apr2022 211005_CD3-127_PPROF_18Apr2022 CD3-303 50-103-20568-00 208013_CD3-303_CHC_21Feb2023 CD4-499 50-103-20810-00 219161_CD4-499_PPROF_28Sep2023 WD-02 50-103-20285-00 198258_WD-02_WFL_22May2022 WD-03 50-103-20835-00 221103_WD-03_IBC DSLT_12Feb2022 221103_WD-03_USIT_28Feb2022 2 of 2 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38298 T38299 T38300 T38301 T38302 T38303 T38304 T38305 T38306 2/29/2024 CD3-125 50-103-20632-00 210189_CD3-125_LDL_23Feb23 210189_CD3-125_POGLM_03Apr2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 10:46:16 -09'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-02-25_22077_CRU_CD3-125_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well #API # Log Description Log Date 22077 CRU CD3-125 50-103-20632-00 Caliper Survey w/ Log Data 25-Feb-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM 1 Regg, James B (OGC) From:AK Wells FEC <n1662@conocophillips.com> Sent:Monday, February 27, 2023 3:58 PM To:Regg, James B (OGC) Subject:RE: [EXTERNAL]RE: Alpine CD3 3-gal Crude Oil Spill Report Hi Jim, Apologize for the typo, the well the wireline unit was on was actually CD3 125.Ill have to check the Security reports closer in the future. Regards, Don Graika/Bert Bertolini ConocoPhillips Alaska Drilling & Wells Environmental Coordinator Alpine AEC Office: (907) 670 4943 Positional Mobile: (907) 231 9309 From:Regg, James B (OGC) <jim.regg@alaska.gov> Sent:Monday, February 27, 2023 2:59 PM To:AK Wells FEC <n1662@conocophillips.com> Subject:[EXTERNAL]RE: Alpine CD3 3 gal Crude Oil Spill Report CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Is there specific well the wireline unit was working on (CD3 25 does not exist in our database)? Jim Regg Supervisor, Inspections AOGCC 333 W. 7 th Ave, Suite 100 Anchorage, AK 99501 907 793 1236 From:AK Wells FEC <n1662@conocophillips.com> Sent:Friday, February 24, 2023 3:06 PM To:DEC SPAR NRegion <decsparnregion@alaska.gov>; dnr.nro.spill (DNR sponsored) <dnr.nro.spill@alaska.gov>; Leroy L. Oenga Jr. <leroy.oenga@north slope.org>; Chastity Olemaun <Chastity.Olemaun@north slope.org>; Robert.akpik@north slope.org; Lilly H. Kilapsuk <lilly.kilapsuk@north slope.org>; Ralph A. Kaleak <ralph.kaleak@north slope.org>;Herbert.Ipalookjr@north slope.org; 'Joe Nukapigak (jnukapigak@kuukpik.com)' <jnukapigak@kuukpik.com>; George Sielak <gsielak@kuukpik.com>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc:AK Wells FEC <n1662@conocophillips.com> Subject:Alpine CD3 3 gal Crude Oil Spill Report You don't often get email from n1662@conocophillips.com. Learn why this is important wireline unit was on was actually CD3 125. 2 Attached is the spill report for a 3 gallon crude oil spill to the CD3 pad well row area from a failed grease seal on a Wireline Unit. The misted area has been 100% cleaned up by ACS personnel. Thank you, Don Graika/Bert Bertolini ConocoPhillips Alaska Drilling & Wells Environmental Coordinator Alpine AEC Office: (907) 670 4943 Positional Mobile: (907) 231 9309 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Maximum Oil Storage Capacity of Kuparuk (Gallons): 6,930,000 (165,000 barrels) Maximum Oil Storage Capacity of Alpine (Gallons): 138,600 (3,300 barrels) Page 1 of 2 ConocoPhillips Alaska, Inc. First & Final Report Date:Friday, February 24, 2023 Submitted By:Don Graika LOCATION OF DISCHARGE:Alpine Drillsites SITE OF DISCHARGE:CD3-25 Well row area on pad ADDITIONAL LOCATION INFO:Latitude 70.41918 N; Longitude 150.91432 W TIME OBSERVED:Thursday, February 23, 2023 2:00:00 PM INITIAL NOTIFICATION BY:Rory Ober EXTERNAL AGENCY INFORMATION Agency name Initial Agency Notification Date External Reporting Comments ADEC Friday, February 24, 2023 12:00:00 PM ADNR Friday, February 24, 2023 12:00:00 PM AOGCC Friday, February 24, 2023 12:00:00 PM Kuukpik Friday, February 24, 2023 12:00:00 PM NSB Friday, February 24, 2023 12:00:00 PM RESPONSIBLE COMPANY:Schlumberger TYPE AND AMOUNT:Light Crude (between 15 - 40 API gravity) 3.00 gal 3.00 gal released to Gravel Pad/Road 100% Light Crude (between 15 - 40 API gravity) SQUARE FOOTAGE:18000 Lightly misted area TOTAL RELEASED: 3.00 gal CAUSE OF DISCHARGE:Failed grease seal on a Wireline Unit. ENVIRONMENTAL DAMAGE:None CLEANUP ACTIONS:Wiped down lightly misted well houses and equipment and scraped up misted snow. Thursday, February 23, 2023 2:00:00 PM Maximum Oil Storage Capacity of Kuparuk (Gallons): 6,930,000 (165,000 barrels) Maximum Oil Storage Capacity of Alpine (Gallons): 138,600 (3,300 barrels) Page 2 of 2 CLEANUP VERIFICATION:Visual AMOUNT OF SPILL RECOVERED: 100% (3.00 gal) CORRECTIVE ACTIONS: Replaced seal and conducted thorough PM inspection of Wireline Unit DISPOSAL/RECYCLE LOCATION: Scraped up lightly misted snow will be put in spot spill cleanup bin for melting and injection down Alpine's Class I Disposal Well. Oiled absorbs put in oily waste collection dumpster. COMMENTS: Large lightly misted area due to windy conditions during seal failure. Equipment wiped down and thin veneer of snow recovered from area. 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. c _10 - J O Well History File Identifier Organizing(done) Two-sided ill 111111 III Iliii ❑ Rescan Needed III 111111 ll 11111111 RESCAN DIGITAL DATA OVERSIZED (Scannable) olor Items: ❑ Diskettes, No. ❑ M s: Greyscale Items: er, No/Type: Cp No. i Other Items Scannable by a Large Scanner Loa S ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: S / I /s/ 01 f Project Proofing III 1111111111111111 BY: (aria) Date: 51 I Li..pti. isi al f Scanning Preparation 5 x 30 = /v 0 + ,2_8/= TOTAL PAGES (Count does not include cover sheet) BY: deb Date: /s/ Production Scanning III IIIIIIIIIII11111 Stage 1 Page Count from Scanned File: /7 (Count does include cover sheet) 9 Page Count Matches Number in Scanning Preparation: /ES NO BY: MOO Date: 5/ ILfl L/ /s/ imp Stage 1 If NO in stage 1, page(s)discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II II 1111111 11 III ReScanned III 11111111111 II III BY: Maria Date: /s/ Comments about this file: Quality Checked III 111111 III III III C C m Cl)a _=v 2 maNu_ Z CZ 0 Le O Z co �Zu'0c�oli M 00 co LI 0 W `' wa a¢ co 0 �I aG) rn Z �a0� (aa w ce �H E op 0 t 't in T ca E N a v7Z Xw 0w- 0< 0 0U � a 7 7 co m O Z LL n --- 6 = o U cZi) m =Ua(m= E 0i- >>o m5 mH m m m m a en c D a O(La(9aa(9 :EU F- ‹C EL al EL a s a s g -o a) 0 0 > a ,a) O 0 0 0 0 0 0 0 0 0 O 0 0 J N N (U N N N N N N N N N N N N N (7i O w <- co co co1713 co- co N N N N N N Z • E V' 4 a V V a a CO CO CO CO CO CO C j 2 c c c c c c c c c c c C C d NQm m m a) a) a) a) a) a) a) a) a) d E c =O V 0. a n a a a n n n n n a a I�— a Y 0 0 0 0 0 0 0 0 0 0 0 0 0 1 0 Li J 1co Lc, 0 Q O 13- U 'OO O 0 0 N-2 Lo co co co Or (D N O N d N Li J c N 7 w dZ Q d C N NI O O O O O h (D (D N- (D i. 0 (n N N N CO CO CO CO CO N CO CO N CO I'I W z J a) U0 O 0ii Z _ a) Q `o o IX MZ a) N a) 7 _I a m am N ° CO ZI 0)2 0 0 Ta 0 0 N C � o C N a) N a) o a) co m tO LO N (O (n O N E 0 N N N N co Co N cO J Q 0 I U r a' O _ 0 i{ • o N O CN CO CO N a' 4 c p J t' CO JJ 0 W Q ° � I I- :a I a ° < 6 1 Z w w E >, >. a 0 Cl 0 o I I c c .N .N .y .N .� Z z z z z 2 0 0 co CO CO CO CO 7 7 7 7 7 7 CO CD re m m Ce a) m cn cn (n cn cn V) Z a CO o - a' - CO (C CO CO (0 03 I.C. C C C C C C C C C C C y I y '� '� O O O O O O O O .0 O O • N C E U U U U V U U U U O U c I- a (o 7 7 7 7 7 2 2 2 N N 2 O or- i O Z J CO c c c c c 0 0 0 0 0 0 a CO a E o j 0 a rn o ar° I- E o c 0 < z ,so, w0z' N H N 2 ° ° '.°O d ° Q o CO w C. a) E co 6 N ? r a— J O Q Q Q co Z LO C TA O _ W LL d H a j l o 3 � 0 � a cc ww o 0 0 W W Cr w W w 0 0 0 0 N to 1 / M No Z el 0 5 6 1 ' N Z -J U Z_ d �/ a m L� J co u) O Q C N ON = C a U a J J W = ce a v W o J U U Q co a 1 Z :Q o Z` FO— o /� O co >, E 1 CIL N C 'ii o Gg U LL o N p_ r E S=-1 O J0:0 in N U 1 Q M U 1"' 0 l— O_ o C > N W Ce -4-et - N Q J V O , Q Z E v .Il. co z1 1 3 o 11 Z 1 0� CT) a �1 m 0 >-re 3 N y u.Z c•-• d co J 0 Q' N1.0 cam- a) O oZ `) o (s• C C Oo d N > 0) R € o U a .8 E EE 0 o a� c c m o 0 a 2 Q 0 <CC C.) 0 Halliburton Sperry Drilling 6900 Arctic Blvd Anchorage, AK 99518 August 23, 2011 AOGCC Christine Mahnken 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 Dear Sir or Madam: Subject: CD3-125/CD3-125PB1 (SURFACE)/CD3-125PB1 Definitive Survey Reports Enclosed are two hard copies(NAD83 and NAD27)of the definitive well path. Also enclosed is a disc containing an electronic export of the survey data. Please acknowledge receipt by sending an email to Avinash.Ramjit@Halliburton.com or by signing and returning a copy of this letter to the following address: Halliburton Sperry Drilling ATTN: Avinash Ramjit 6900 Arctic Blvd 4_ Anchorage, AK 18 Received by: v Date: A.6 n Please contact me at 907.263.4657 with questions or concerns. Regards, Avinash Ramjit STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil a Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test❑ 4._ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number / Faac /Sri ConocoPhillips Alaska, Inc. or Aband.: April 18,2011 210-189/311-115/311-034 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 February 2,2011 50-103-20632-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 4023'FNL, 1185'FEL,Sec.5,T12N, R5E, UM April 4,2011 CD3-125 Top of Productive Horizon: 8. KB(ft above MSL): 12.6'RKB 15.Field/Pool(s): 2503'FNL,2231'FEL,Sec.7,T12N, R5E,UM GL(ft above MSL): 40'AMSL Colville River Field li Total Depth: 9.Plug Back Depth(MD+TVD): 317'FNL,74'FWL,Sec. 17,T12N, R5E, UM 15442'MD/7050'TVD Fiord Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-387896 y- 6003766 Zone-4 16529'MD/7072'TVD ADL 372105,25538,025526 TPI: x-381488 y- 6000094 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-383755 y- 5996964 Zone-4 2171'MD/2012'TVD LAS2112 18.Directional Survey: Yes ❑✓ No❑ 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) 1300'MD/1282'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 GR/Res 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" 129# X-56 36' 114' 36' 114' 24" 4 cu yds Portland III 9.625" 40# L-80 36' 2961' 36' 2464' 12.25" 326 sx Class G,250 sx Class G 7" 26# L-80 34' 11487' 34' 6991' 8.75" 205 sx Class G,225 sx Class G 3.5" 9.3# L-80 11288' 15442" 6930' 7050' 6.125" slotted liner 24.Open to production or injection? Yes 0 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) 3.5" 11347' 11288'MD/6930'TVD slotted liner 11288'-15442'MD 6930'-7050'TVD 1e�'16i26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. f} c DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED �' "' cement retainer @ 10400'-10808' 202 sx Class G 6 .0". kick-off plug @ 7350'-7721' 234 sx Class G ...,.=..A.=«. 7 fracs-see schematic for summary 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting on facility hook-up 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 E 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. RECEIVED' NONE RBDMS MAY 10 2011. MAY tia Oil&Gs 0 :�t�t Caw Commission Form 10-407 Revised 12/2009 CONTINUED ON REV kakSubmit original only .."),; - 28. GEOLOGIC MARKERS(List all formations and markers 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 1300' 1282' needed,and submit detailed test information per 20 AAC 25.071. C-30 2991' 2480' C-20 3756' 2865' K-3 5779' 3855' K-2 6120' 4027' Nanuq 9597' 5967' K-1 11395' 6968' Kuparuk C 11676' 7009' Nechelik 12660' 7022' N/A CD3-125PB1 total depth 12754' 7007' Formation at total depth: Nechelik 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey IA 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Nina Anderson @ 265-6403 Printed Name /� nG..L.Alvord Title: Alaska Drilling Manager SASignature /Q _Lci. _ Phone 265-6120 Date Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 WNS CD3-125 CanomPhillipS Well Attributes - Max Angle Angle&MD TD �,,,n (- AJaska,Inc. ;." � Wellbore APW WI IF eW Name I Wall Status incl() MD(NKB) Act B1m(ftKB) (.onocat718kpy•- 5010320632 FIORD NECHELIK PROD 192-37 L 15,894.83 16,5290 ... Comment IH2S(ppm) IDate Annotation End Date KB•Cxd(ft) Rig Release Dab -.mit Cgmo 160 2 CAL.'..GQ3-125,,411912hU 1 5205 P9 SSV.TRDP _ Last W0. 41.89 . 4/9/2011 - Sd MMI/9_A�1._--„_ ___ AnnotationDepth(ftKB) End Date Annotation Last Mod. E d Date -- -- - Last Tag. I Rev Reason:FRAC _ZImosbor 14/19/2011 HANGER,31 --.--- :,;. __.__....._. - _.n - ' i Casing Strings Casing Description String 0... String ID..ITop(ftKB) Set Depth(f...Set Depth("ND)...String Wt...String.. String Top Thrd CONDUCTOR 16 15.250 36.6 1116 113.6 62.50 H-40 Casing-Description String 0... String ID...Top(ftiCB) Set Depth(i...Set Depth(TVD)...String W1...String...String Top Thal CONDUCTOR, SURFACE95/8 8.835 35.8 2,961.3 2,464.0 40.00 L-80 BTC-M 37-116 �. -�_- Casing Description String 0... String ID...Top(6KB) Sat Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd INTERMEDIATE 7 6.000 33.5 11,487.2 6,991.0 26.00 L-80 BTC-M Casing Description String 0... String ID..Top(ftKB) SN Depth(t...Set Depth(TVD) String Wt...String...String Top Thrd SAFETY VLV, ,-�+ 2,171\ LINER 3 1/2 2.992 11 288.4 15,442.0 7,048.9 9.30 L-80 SLHT ISO SLEEVE. \ ( Liner Details _::.- Top Depth ,171 ,i (TVD) Top Incl Rani... i Top(BKBI (8KB) (") rum Description Comment 10(in)SU F ACE,_ 11,288.4 6,930.1 66.86 PACKER Baker 5"x 7"HRD ZXP w/Hold downs (5.96"OD x 4.35"ID) 4.350 36.2.96 1 11,308.3 6,937.9 67.10 NIPPLE Baker 5"RS Nipple (5.26"OD x 4.260"ID) 4.260 casa 13 11,311.1 6,939.0 67.13 HANGER Baker 5"x 7"Flex lock hanger (5.92"OD x 4.36"ID) 4.360 ZFT. r 11,506.8 6,992..4 82.88 Swell Packer Swell Packer OD 5.75"WI 5'Sealing element 2.992 11 1 aft- �k 11,554.0 6,9925 84.49 Swell Packer Swell Packer OD 5.75"w/5'Sealing element 2.992 9 11,816.7 7,007 3 91 62 SLEEVE-C 3-1/2"SLHT Ball Actuated Sleeve(2.0"seat ID)(2.125"Ball)Closed 2.000 12,111.1 7008.2 90 76 Swell Packer Swell Packer(3-1/2"SLHT)OD 5.75"w/5'Sealing element 2.992 GAS LIFT, s.ozs 12,406.0 7,011.2 86.87 SLEEVE-C 3-1/2'SLHT Ball Actuated Sleeve(1.875"seat ID)(2.0"Ball)Closed 1.875 12,699.2 7,021.0 88.91 Swell Packer Swell Packer OD 5.75"w/5'Sealing element 2.992 12,993.2 7,026.8 87.99 SLEEVE-C 3-1/2"SLHT Ball Actuated Sleeve(1.75"seat ID)(1.875"Ball)Closed 1.750 GAS LIFT,__ {' 13,285.6 7,034.7 88.21 Swell Packer Swell Packer(3-1/2'SLHT)OD 5.75"w/5'Sealing element 2.992 11,220 I ----- _. _ _ 13,578.7 7,0411) 89.04 SLEEVE-C 3-1/2"SLHT Ball Actuated Sleeve(1.625"seat ID)(1.75"Ball)Closed 1.625 NIPPLE,11,268 13,870.7 7,0419 90.13 Swell Packer Swell Packer OD 5.75"wl S'Sealing element 2.992 -`. 14,165.8 7,0423 91.45 SLEEVE-C 3-1/2"SLHT Ball Actuated Sleeve(1.50"seat ID)(1.625"Ball)Closed 1.500 LOCAITO Jaime.,306 14,458.1 7,0425 88.82 Swell Packer Swell Packer OD 5.75"w/5'Sealing element 2.992 14,597.3 7,044.8 89 24 SLEEVE-C 3-1/2"SLHT Ball Actuated Sleeve(1.375'seat ID)(1.50"Ball)Closed 1.375 14,736.3 7,046 6 09.44 Swell Packer Swell Packer OD 535"w/5'Sealing element 2.992 SEAL ASSY, 3333 !-, 111 15,061.5 7,051.9 89.76 SLEEVE-C 3-1/2"SLHT Ball Actuated Sleeve(1.250"seat ID)(1.375"Ball)Closed 1.250 15,384.9 7,049.6 90.58 Swell Packer Swell Packer OD 5.75"w/5'Sealing element 2.992 SEAL ASSY, -__ : Tubing Strings _. _ 11,345 Description Istring 0... IString ID...Tubing _ - Top(ftKB) Set Depth(f...Set Depth(ND) String Wt...String...String Top Thrd TUBING 4.5x3.5" 31/2 2 992 I 310 I 11,347.3 I 6,952.4 9.30 I L-80 I EUE-Ord-mod Completion Details Top Depth LATER 1 (ND) Top Incl Nomi... 34-1441,4117,497 Top(fti(B) 18681 C) nem Description Comment ID(in) 31.0 31.0 -0.05 HANGER FMC 4-1/2"x 11"tubing hanger(10.85"OD) 3.958 142.9 142.9 0.38 X0-Reducing Crossover 4-1/2"12.6 ppf L-80 IBT-m box x 3-1/2"9.3 ppf L-80 EUE-m 2.992 pin WAN 2,171.1 2,012.3 45.72 SAFETY VLV 3-1/2"Camco TRMAXX-5E w/2.812""X"profile,1/4"single control line 2.812 11,268.4 6,922.2 66.61 NIPPLE HES"XN"nipple(2.813"profile 2.75"No-go) 2.750 FRAC.11,617 I 11,305.9 6,936.9 67.07 LOCATOR Baker 80-40 GBH locator 2.970 11,333.33 6,9466 68.32 SEAL ASSY 80-40 Bonded Seal assembly 3.000 11,345.2 6,951 6 6962 SEAL ASSY 180-40 Seal assembly w/1/2 mule shoe 3.000 ARM Other In Hole,(Wirelineretrievable plugs,valves pumps,fish etc.) Top Depth (TVD) Top feel FRAC,12,406 1 MI 1 Top(ftKB) (ftKB) CI Description Comment Run Date ID(in) 2,171.1 2,012.3 45.72 ISO SLEEVE 2.81"ISO SLEEVE SET IN SSSV 4/16/2011 2.290 ilittja Stimulations&Treatments Bottom ( ( Min Top Max Bbn Top Depth Depth Depth Depth (TVD) (TVD) FRAC,12,993 I ! (MB) (ftKBI (8KB) (1)0(B) Type Date Comment 11 817.0 11,8220 7,007.3 7,007.1 FRAC 4/18/2011 138,065#CARBOLITE 1620 12,406.0 12,411.0 7,011.2 7,011.5 FRAC 4/18/2011 123,327#CARBOLITE 16/20 12,993.0 12,998.0 /0268 7,027.0 FRAC 4/18/2011 123,385#CARBOILTE 16/20 13,579.0 13,584.0 /641 0 7,041.1 FRAC 4/18/2011 89,575#COLORADO WHITE SAND 16/30,33,298# CARBOLITE 16/20 FRAC,13,579 I I 14,166.0 14,171.0 /,042.8 7,042.6 FRAC 4/18/2011 122,682 COLORADO WHITE SAND 16/30 14,597.0 14,6020 7,044.8 7,044.9 FRAC 4/18/2011 15,061.0' 15,066.0 7,051.9 7,051.9 FRAC 4/18/2011 122,743 COLORADO WHITE SAND 16/30 Notes:General&Safety End Date Annotation 47152011 NCi'E'View schematic w/Alaska Schematic9.0 FRAC,14.166 / I -- Mandrel Details Top Depth Top Port (ND) Incl OD Valve Latch Size TRO Run Stn Top(ftKBly {ftKB) I') Make Model lin) Seen Type Type (in) (I#) Run Data Com..._ 11 1 4,842 6 3.4114 1 61.29 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 4/7/2011 FRAC,14,597 _ 2 9,025.2 5,598.0 50.60 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 4/7/2011 3 11,219.7 6,901.8 63.96 Camco KBMG 1 GAS LIFT Gauges 0.000 0.0 4/162011 FRAC,15.061 ' I LINER, 11288-15,442 TD(CO3.125), 16,529 +t ii i s r Yy0 h 'HI f ConocoPhill �i °u����s(Alaska) Inc. Western North Slope CD3 Fiord Pad ', -0 cc`D3-125PB1 (surface) 501032063270 ril g 0 til 4 , V FA ii 1!i, FO: Iy Sperry Drilling Definitive Survey Report 11 April, 2011 1 I I„,,„ `” a, i m A s 4, v ti r4 10 w , HALLIBURTON '5 j * Sperry t3r:HSing a +`Y ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-125 Project: Western North Slope TVD Reference: CD3-125 @ 40.13ft(D141) Site: CD3 Fiord Pad MD Reference: CD3-125 @ 40.13ft(D141) Well: CD3-125 North Reference: True Wellbore: CD3-125PB1(surface) Survey Calculation Method: Minimum Curvature Design: CD3-125PB1(surface) Database: CPAI EDM Production 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 Well CD3-125 Well Position +N1-S 0.00 ft Northing: 6,003,766.42 ft Latitude: 70°25'9.210 N +EI-W 0.00 ft Easting: 387,895.98 ft Longitude: 150°54'47.701 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.60ft Wellbore CD3-125PB1 (surface) Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2010 2/10/2010 21.25 80.81 57,603 ...._.._.......... Design CD3-125PB1 (surface) Audit Notes: 'Version: 1.0 Phase: ACTUAL Tie On Depth: 27.53 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 27.53 0.00 0.00 142.00 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 76.00 859.00 CD3-125PB1 Gyro(R100)(CD3-125PB1 CB-GYRO-SS Camera based gyro single shot 2/3/2011 12:0C 953.23 2,922.16 CD3-125PB1 MWD(R100)(CD3-125PB MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/3/2011 12:OC Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (1 (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 27.53 0.00 0.00 27.53 -12.60 0.00 0.00 6,003,766.42 387,895.98 0.00 0.00 UNDEFINED 76.00 0.44 122.77 76.00 35.87 -0.10 0.16 6,003,766.32 387,896.13 0.91 0.18 CB-GYRO-SS(1) 106.00 0.37 124.52 106.00 65.87 -0.22 0.33 6,003,766.20 387,896.31 0.24 0.38 CB-GYRO-SS(1) 136.00 0.39 128.85 136.00 95.87 -0.34 0.49 6,003,766.08 387,896.47 0.12 0.57 CB-GYRO-SS(1) 166.00 0.54 104.19 166.00 125.87 -0.44 0.71 6,003,765.98 387,896.68 0.82 0.78 CB-GYRO-SS(1) 193.00 0.14 143.66 193.00 152.87 -0.49 0.85 6,003,765.92 387,896.82 1.63 0.91 CB-GYRO-SS(1) 265.00 1.57 347.02 264.99 224.86 0.40 0.68 6,003,766.81 387,896.67 2.36 0.11 CB-GYRO-SS(1) 356.00 3.38 330.52 355.90 315.77 3.95 -0.92 6,003,770.38 387,895.12 2.12 -3.68 CB-GYRO-SS(1) 448.00 4.74 327.32 447.67 407.54 9.51 -4.31 6,003,775.99 387,891.82 1.50 -10.14 CB-GYRO-SS(1) 540.00 5.65 327.58 539.29 499.16 16.53 -8.79 6,003,783.08 387,887.44 0.99 -18.44 CB-GYRO-SS(1) 632.00 7.21 321.82 630.71 590.58 24.89 -14.78 6,003,791.53 387,881.57 1.83 -28.72 CB-GYRO-SS(1) 724.00 8.57 320.09 721.84 681.71 34.69 -22.75 6,003,801.45 387,873.75 1.50 -41.34 CB-GYRO-SS(1) 816.00 10.20 315.31 812.60 772.47 45.74 -32.88 6,003,812.65 387,863.79 1.96 -56.28 CB-GYRO-SS(1) 4111/2011 10:04:25AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. 1 ocal Co-ordinate Reference: Well CD3-125 Project: Western North Slope TVD Reference: CD3-125 @ 40.13ft(D141) Site: CD3 Fiord Pad I113D Reference: CD3-125 @ 40.13ft(D141) Well: CD3-125 North Reference: True Wellbore: CD3-125PB1 (surface) Survey Calculation Method: Minimum Curvature Design: CD3-125PB1 (surface) Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S ±EI-W Northing Easting DLS Section (ft) (0) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 859.00 11.02 31229 854.87 814.74 51.21 -38.60 6,003,818.20 387,858.16 2.30 -64.12 CB-GYRO-SS(1) 953.23 13.97 309.76 946.86 906.73 64.55 -54.00 6,003,831.77 387,842.95 3.18 -84.11 MWD+IFR-AK-CAZ-SC(2) 1,045.32 14.67 311.69 1,036.08 995.95 79.41 -71.26 6,003,846.89 387,825.93 0.92 -106.45 MWD+IFR-AK-CAZ-SC(2) 1,136.80 13.85 309.39 1,124.75 1,084.62 94.07 -88.37 6,003,861.80 387,809.04 1.09 -128.53 MWD+IFR-AK-CAZ-SC(2) 1,229.32 14.90 302.12 1,214.38 1,174.25 107.42 -107.01 6,003,875.43 387,790.61 2.25 -150.53 MWD+IFR-AK-CAZ-SC(2) 1,321.15 18.65 292.92 1,302.30 1,262.17 119.42 -130.54 6,003,887.78 387,767.26 4.99 -174.48 MWD+IFR-AK-CAZ-SC(2) 1,415.37 22.31 284.50 1,390.57 1,350.44 129.77 -161.75 6,003,898.60 387,736.21 4.98 -201.84 MWD+IFR-AK-CAZ-SC(2) 1,507.63 25.53 275.81 1,474.92 1,434.79 136.17 -198.50 6,003,905.55 387,699.56 5.17 -229.52 MWD+IFR-AK-CAZ-SC(2) 1,600.44 28.83 272.22 1,557.47 1,517.34 139.07 -240.77 6,003,909.08 387,657.34 3.97 -257.82 MWD+IFR-AK-CAZ-SC(2) 1,691.23 31.65 270.92 1,635.90 1,595.77 140.30 -286.47 6,003,910.99 387,611.67 3.19 -286.93 MWD+IFR-AK-CAZ-SC(2) 1,783.79 34.36 268.39 1,713.52 1,673.39 139.95 -336.88 6,003,911.41 387,561.27 3.28 -317.69 MWD+IFR-AK-CAZ-SC(2) 1,876.27 37.12 269.20 1,788.58 1,748.45 138.83 -390.88 6,003,911.10 387,507.26 3.03 -350.05 MWD+IFR-AK-CAZ-SC(2) 1,971.59 39.47 268.03 1,863.38 1,823.25 137.39 -449.92 6,003,910.54 387,448.21 2.58 -385.26 MWD+IFR-AK-CAZ-SC(2) 2,063.79 42.70 267.19 1,932.87 1,892.74 134.85 -510.45 6,003,908.91 387,387.65 3.55 -420.53 MWD+IFR-AK-CAZ-SC(2) 2,157.04 45.57 266.21 1,999.79 1,959.66 131.09 -575.27 6,003,906.13 387,322.79 3.16 -457.48 MWD+IFR-AK-CAZ-SC(2) 2,249.82 48.42 264.59 2,063.07 2,022.94 125.63 -642.89 6,003,901.68 387,255.10 3.33 -494.80 MWD+IFR-AK-CAZ-SC(2) 2,340.93 50.50 263.82 2,122.28 2,082.15 118.63 -711.77 6,003,895.72 387,186.13 2.37 -531.69 MWD+IFR-AK-CAZ-SC(2) 2,432.32 53.21 262.80 2,178.73 2,138.60 110.25 -783.14 6,003,888.41 387,114.65 3.09 -569.03 MWD+IFR-AK-CAZ-SC(2) 2,524.42 55.85 262.75 2,232.17 2,192.04 100.82 -857.55 6,003,880.10 387,040.11 2.87 -607.41 MWD+IFR-AK-CAZ-SC(2) 2,619.42 57.79 262.87 2,284.15 2,244.02 90.87 -936.43 6,003,871.33 386,961.10 2.04 -648.13 MWD+IFR-AK-CAZ-SC(2) 2,711.75 59.23 263.41 2,332.38 2,292.25 81.47 -1,014.60 6,003,863.11 386,882.80 1.64 -688.84 MWD+IFR-AK-CAZ-SC(2) 2,804.30 58.80 262.75 2,380.03 2,339.90 71.91 -1,093.36 6,003,854.73 386,803.91 0.77 -729.81 MWD+IFR-AK-CAZ-SC(2) 2,897.56 59.96 263.81 2,427.53 2,387.40 62.52 -1,173.07 6,003,846.55 386,724.08 1.58 -771.48 MWD+IFR-AK-CAZ-SC(2) 2,922.16 59.76 263.85 2,439.88 2,399.75 60.23 -1,194.22 6,003,844.58 386,702.90 0.83 -782.70 MWD+IFR-AK-CAZ-SC(2) 2,965.00 59.76 263.85 2,461.46 2,421.33 56.27 -1,231.01 6,003,841.17 386,666.05 0.00 -802.23 PROJECTED to TO 4/11/2011 10:04:25AM Page 3 COMPASS 2003.16 Build 69 g N. I ft fflI I ConocoPhilh pps(Alaska) Inc. Western North Slope g ..071.0a-Piorcl p CD3-125PB1 5 320-'3270 I perry Drilling k Definitive Su rvey Report y r rT M 11 April, 2011 11fsi IIHI pNy 4 HALLIBURTON Sperry Drilling ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-125 Project: Western North Slope TVD Reference: Rig:CD3-125 @ 49.19ft(D19) Site: CD3 Fiord Pad MD Reference: Rig:CD3-125 @ 49.19ft(D19) Well: CD3-125 North Reference: True Wellbore: CD3-125PB1 Survey Calculation Method: Minimum Curvature Design: CD3-125PB1 Database: CPAI EDM Production 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 Well CD3-125 Well Position +N/-S 0.00 ft Northing: 6,003,766.42 ft Latitude: 70°25'9.210 N +EI-W 0.00ft Easting: 387,895.98ft Longitude: 150°54'47.701 W Position Uncertainty 0.00ft Wellhead Elevation: ft Ground Level: 12.60ft Wellbore CD3-125PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) - BGGM2010 3/15/2011 20.69 80.83 57,604 Design CD3-125PB1 - Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 2,931.22 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) 'i (ft) (ft) (°) 36.59 0.00 0.00 142.00 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 85.06 868.06 CD3-125PB1 Gyro(R100)(CD3-125PB1 CB-GYRO-SS Camera based gyro single shot 2/3/2011 12:OC 962.29 2,931.22 CD3-125PB1 MWD(R100)(CD3-125PB MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/3/2011 12:0C 2,998.33 12,723.02 CD3-125PB1 MWD(R200)(CD3-125PB MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/10/2011 12:C 'Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 36.59 0.00 0.00 36.59 -12.60 0.00 0.00 6,003,766.42 387,895.98 0.00 0.00 UNDEFINED 85.06 0.44 122.77 85.06 35.87 -0.10 0.16 6,003,766.32 387,896.13 0.91 0.18 CB-GYRO-SS(1) 115.06 0.37 124.52 115.06 65.87 -0.22 0.33 6,003,766.20 387,896.31 0.24 0.38 CB-GYRO-SS(1) 145.06 0.39 128.85 145.06 95.87 -0.34 0.49 6,003,766.08 387,896.47 0.12 0.57 CB-GYRO-SS(1) ri 175.06 0.54 104.19 175.06 125.87 -0.44 0.71 6,003,765.98 387,896.68 0.82 0.78 CB-GYRO-SS(1) 202.06 0.14 143.66 202.06 152.87 -0.49 0.85 6,003,765.92 387,896.82 1.63 0.91 CB-GYRO-SS(1) 274.06 1.57 347.02 274.05 224.86 0.40 0.68 6,003,766.81 387,896.67 2.36 0.11 CB-GYRO-SS(1) 365.06 3.38 330.52 364.96 315.77 3.95 -0.92 6,003,770.38 387,895.12 2.12 -3.68 CB-GYRO-SS(1) 457.06 4.74 327.32 456.73 407.54 9.51 -4.31 6,003,775.99 387,891.82 1.50 -10.14 CB-GYRO-SS(1) 549.06 5.65 327.58 548.35 499.16 16.53 -8.79 6,003,783.08 387,887.44 0.99 -18.44 CB-GYRO-SS(1) 641.06 7.21 321.82 639.77 590.58 24.89 -14.78 6,003,791.53 387,881.57 1.83 -28.72 CB-GYRO-SS(1) 733.06 8.57 320.09 730.90 681.71 34.69 -22.75 6,003,801.45 387,873.75 1.50 -41.34 CB-GYRO-SS(1) 4111/2011 10:02:40AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-125 Project: Western North Slope TVD Reference: Rig:CD3-125 @ 49.19ft(D19) Site: CD3 Fiord Pad MD Reference: Rig:CD3-125 @ 49.19ft(D19) Well: CD3-125 North Reference: True Wellbore: CD3-125PB1 Survey Calculation Method: Minimum Curvature Design: CD3-125PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°f100') (ft) Survey Tool Name 825.06 10.20 315.31 821.66 772.47 45.74 -32.88 6,003,812.65 387,863.79 1.96 -56.28 CB-GYRO-SS(1) I 868.06 11.02 312.29 863.93 814.74 51.21 -38.60 6,003,818.20 387,858.16 2.30 -64.12 CB-GYRO-SS(1) 962.29 13.97 309.76 955.92 906.73 64.55 -54.00 6,003,831.77 387,842.95 3.18 -84.11 MWD+IFR-AK-CAZ-SC(2) 1,054.38 14.67 311.69 1,045.14 995.95 79.41 -71.26 6,003,846.89 387,825.93 0.92 -106.45 MWD+IFR-AK-CAZ-SC(2) 1,145.86 13.85 309.39 1,133.81 1,084.62 94.07 -88.37 6,003,861.80 387,809.04 1.09 -128.53 MWD+IFR-AK-CAZ-SC(2) 1,238.38 14.90 302.12 1,223.44 1,174.25 107.42 -107.01 6,003,875.43 387,790.61 2.25 -150.53 MWD+IFR-AK-CAZ-SC(2) 1,330.21 18.65 292.92 1,311.36 1,262.17 119.42 -130.54 6,003,887.78 387,767.26 4.99 -174.48 MWD+IFR-AK-CAZ-SC(2) 1,424.43 22.31 284.50 1,399.63 1,350.44 129.77 -161.75 6,003,898.60 387,736.21 4.98 -201.84 MWD+IFR-AK-CAZ-SC(2) 1,516.69 25.53 275.81 1,483.98 1,434.79 136.17 -198.50 6,003,905.55 387,699.56 5.17 -229.52 MWD+IFR-AK-CAZ-SC(2) 1,609.50 28.83 272.22 1,566.53 1,517.34 139.07 -240.77 6,003,909.08 387,657.34 3.97 -257.82 MWD+IFR-AK-CAZ-SC(2) 1,700.29 31.65 270.92 1,644.96 1,595.77 140.30 -286.47 6,003,910.99 387,611.67 3.19 -286.93 MWD+IFR-AK-CAZ-SC(2) 1,792.85 34.36 268.39 1,722.58 1,673.39 139.95 -336.88 6,003,911.41 387,561.27 3.28 -317.69 MWD+IFR-AK-CAZ-SC(2) 1,885.33 37.12 269.20 1,797.64 1,748.45 138.83 -390.88 6,003,911.10 387,507.26 3.03 -350.05 MWD+IFR-AK-CAZ-SC(2) 1,980.65 39.47 268.03 1,872.44 1,823.25 137.39 -449.92 6,003,910.54 387,448.21 2.58 -385.26 MWD+IFR-AK-CAZ-SC(2) 2,072.85 42.70 267.19 1,941.93 1,892.74 134.85 -510.45 6,003,908.91 387,387.65 3.55 -420.53 MWD+IFR-AK-CAZ-SC(2) 2,166.10 45.57 266.21 2,008.85 1,959.66 131.09 -575.27 6,003,906.13 387,322.79 3.16 -457.48 MWD+IFR-AK-CAZ-SC(2) 2,258.88 48.42 264.59 2,072.13 2,022.94 125.63 -642.89 6,003,901.68 387,255.10 3.33 -494.80 MWD+IFR-AK-CAZ-SC(2) 2,349.99 50.50 263.82 2,131.34 2,082.15 118.63 -711.77 6,003,895.72 387,186.13 2.37 -531.69 MWD+IFR-AK-CAZ-SC(2) 2,441.38 53.21 262.80 2,187.79 2,138.60 110.25 -783.14 6,003,888.41 387,114.65 3.09 -569.03 MWD+IFR-AK-CAZ-SC(2) 2,533.48 55.85 262.75 2,241.23 2,192.04 100.82 -857.55 6,003,880.10 387,040.11 2.87 -607.41 MWD+IFR-AK-CAZ-SC(2) 2,628.48 57.79 262.87 2,293.21 2,244.02 90.87 -936.43 6,003,871.33 386,961.10 2.04 -648.13 MWD+IFR-AK-CAZ-SC(2) 2,720.81 59.23 263.41 2,341.44 2,292.25 81.47 -1,014.60 6,003,863.11 386,882.80 1.64 -688.84 MWD+IFR-AK-CAZ-SC(2) 2,813.36 58.80 262.75 2,389.09 2,339.90 71.91 -1,093.36 6,003,854.73 386,803.91 0.77 -729.81 MWD+IFR-AK-CAZ-SC(2) 2,906.62 59.96 263.81 2,436.59 2,387.40 62.52 -1,173.07 6,003,846.55 386,724.08 1.58 -771.48 MWD+IFR-AK-CAZ-SC(2) 2,931.22 59.76 263.85 2,448.94 2,399.75 60.23 -1,194.22 6,003,844.58 386,702.90 0.83 -782.70 MWD+IFR-AK-CAZ-SC(2) 2,998.33 58.51 264.90 2,483.37 2,434.18 54.58 -1,251.54 6,003,839.79 386,645.50 2.30 -813.54 MWD+IFR-AK-CAZ-SC(3) 3,092.38 58.42 264.41 2,532.56 2,483.37 47.12 -1,331.35 6,003,833.52 386,565.60 0.45 -856.79 MWD+IFR-AK-CAZ-SC(3) 3,187.59 59.30 264.17 2,581.80 2,532.61 39.01 -1,412.44 6,003,826.63 386,484.41 0.95 -900.32 MWD+IFR-AK-CAZ-SC(3) 3,282.87 59.95 264.76 2,629.97 2,580.78 31.08 -1,494.26 6,003,819.94 386,402.49 0.87 -944.45 MWD+IFR-AK-CAZ-SC(3) 3,377.51 59.88 265.08 2,677.42 2,628.23 23.83 -1,575.83 6,003,813.91 386,320.82 0.30 -988.95 MWD+IFR-AK-CAZ-SC(3) 3,471.85 59.93 264.42 2,724.72 2,675.53 16.36 -1,657.10 6,003,807.67 386,239.45 0.61 -1,033.11 MWD+IFR-AK-CAZ-SC(3) 3,566.70 60.80 264.62 2,771.62 2,722.43 8.49 -1,739.17 6,003,801.03 386,157.28 0.94 -1,077.43 MWD+IFR-AK-CAZ-SC(3) 3,659.58 60.53 264.86 2,817.13 2,767.94 1.07 -1,819.80 6,003,794.82 386,076.56 0.37 -1,121.22 MWD+IFR-AK-CAZ-SC(3) 3,754.06 60.28 265.14 2,863.79 2,814.60 -6.09 -1,901.64 6,003,788.89 385,994.62 0.37 -1,165.96 MWD+IFR-AK-CAZ-SC(3) 3,848.42 60.59 263.67 2,910.35 2,861.16 -14.10 -1,983.32 6,003,782.11 385,912.84 1.39 -1,209.94 MWD+IFR-AK-CAZ-SC(3) 3,942.37 61.43 262.77 2,955.88 2,906.69 -23.80 -2,064.92 6,003,773.63 385,831.11 1.23 -1,252.54 MWD+IFR-AK-CAZ-SC(3) 4,037.19 60.93 262.10 3,001.59 2,952.40 -34.74 -2,147.27 6,003,763.94 385,748.61 0.81 -1,294.62 MWD+IFR-AK-CAZ-SC(3) 4,131.72 59.69 260.65 3,048.41 2,999.22 -47.05 -2,228.46 6,003,752.85 385,667.25 1.87 -1,334.90 MWD+IFR-AK-CAZ-SC(3) 4,225.88 59.61 261.10 3,095.99 3,046.80 -59.93 -2,308.69 6,003,741.17 385,586.85 0.42 -1,374.14 MWD+IFR-AK-CAZ-SC(3) 4,320.91 59.52 259.60 3,144.13 3,094.94 -73.67 -2,389.46 6,003,728.65 385,505.89 1.36 -1,413.05 MWD+IFR-AK-CAZ-SC(3) 4/11/2011 10:02:40AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-125 Project: Western North Slope TVD Reference: Rig:CD3-125 @ 49.19ft(D19) Site: CD3 Fiord Pad I iD Reference: Rig:CD3-125 @ 49.19ft(D19) Well: CD3-125 North Reference: True Wellbore: CD3-125PB1 Survey Calculation Method: Minimum Curvature Design: CD3-125PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S -+-E/-W Northing Easting DLS Section (ft) (0) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,414.21 59.82 260.48 3,191.24 3,142.05 -87.59 -2,468.77 6,003,715.92 385,426.38 0.88 -1,450.91 MW D+I F R-AK-CAZ-SC(3) 4,510.13 59.93 263.43 3,239.39 3,190.20 -99.20 -2,550.91 6,003,705.55 385,344.09 2.66 -1,492.33 MWD+IFR-AK-CAZ-SC(3) 4,604.94 59.85 262.95 3,286.96 3,237.77 -108.93 -2,632.35 6,003,697.05 385,262.52 0.45 -1,534.80 MWD+IFR-AK-CAZ-SC(3) 4,699.41 60.57 264.65 3,333.89 3,284.70 -117.78 -2,713.85 6,003,689.42 385,180.90 1.74 -1,578.00 MWD+IFR-AK-CAZ-SC(3) 4,794.72 60.49 265.26 3,380.78 3,331.59 -125.07 -2,796.50 6,003,683.37 385,098.15 0.56 -1,623.14 MWD+IFR-AK-CAZ-SC(3) 4,889.30 61.57 265.44 3,426.59 3,377.40 -131.78 -2,878.98 6,003,677.90 385,015.59 1.15 -1,668.63 MWD+IFR-AK-CAZ-SC(3) 4,983.78 62.13 264.96 3,471.17 3,421.98 -138.75 -2,961.99 6,003,672.18 384,932.49 0.74 -1,714.24 MWD+IFR-AK-CAZ-SC(3) 5,078.17 61.91 264.36 3,515.45 3,466.26 -146.51 -3,044.98 6,003,665.67 384,849.40 0.61 -1,759.23 MWD+IFR-AK-CAZ-SC(3) 5,172.68 61.99 263.56 3,559.89 3,510.70 -155.28 -3,127.93 6,003,658.14 384,766.34 0.75 -1,803.38 MWD+IFR-AK-CAZ-SC(3) 5,267.44 61.29 262.72 3,604.91 3,555.72 -165.24 -3,210.72 6,003,649.43 384,683.42 1.07 -1,846.50 MWD+IFR-AK-CAZ-SC(3) 5,360.04 61.35 263.27 3,649.35 3,600.16 -175.15 -3,291.35 6,003,640.73 384,602.65 0.53 -1,888.34 MWD+IFR-AK-CAZ-SC(3) 5,456.16 61.06 262.10 3,695.65 3,646.46 -185.87 -3,374.90 6,003,631.26 384,518.96 1.11 -1,931.32 MWD+IFR-AK-CAZ-SC(3) 5,550.46 60.30 262.14 3,741.82 3,692.63 -197.15 -3,456.34 6,003,621.22 384,437.37 0.81 -1,972.58 MWD+IFR-AK-CAZ-SC(3) 5,645.94 60.29 262.45 3,789.14 3,739.95 -208.27 -3,538.52 6,003,611.33 384,355.03 0.28 -2,014.42 MWD+IFR-AK-CAZ-SC(3) 5,740.18 60.36 262.52 3,835.79 3,786.60 -218.97 -3,619.70 6,003,601.85 384,273.71 0.10 -2,055.96 MWD+IFR-AK-CAZ-SC(3) 5,835.03 60.17 261.68 3,882.84 3,833.65 -230.29 -3,701.28 6,003,591.75 384,191.98 0.79 -2,097.26 MWD+IFR-AK-CAZ-SC(3) 5,929.00 60.05 260.34 3,929.67 3,880.48 -243.02 -3,781.74 6,003,580.24 384,111.34 1.24 -2,136.77 MWD+IFR-AK-CAZ-SC(3) 6,024.17 59.58 259.13 3,977.52 3,928.33 -257.68 -3,862.69 6,003,566.80 384,030.18 1.20 -2,175.06 MWD+IFR-AK-CAZ-SC(3) 6,119.27 58.77 259.98 4,026.25 3,977.06 -272.49 -3,943.00 6,003,553.20 383,949.67 1.15 -2,212.83 MWD+IFR-AK-CAZ-SC(3) 6,213.43 58.41 261.29 4,075.33 4,026.14 -285.57 -4,022.29 6,003,541.31 383,870.20 1.25 -2,251.34 MWD+IFR-AK-CAZ-SC(3) 6,307.67 58.07 262.04 4,124.93 4,075.74 -297.18 -4,101.57 6,003,530.89 383,790.76 0.77 -2,291.00 MWD+IFR-AK-CAZ-SC(3) 6,402.04 57.93 261.97 4,174.94 4,125.75 -308.31 -4,180.82 6,003,520.95 383,711.36 0.16 -2,331.02 MWD+IFR-AK-CAZ-SC(3) 6,496.71 59.16 262.98 4,224.34 4,175.15 -318.88 -4,260.88 6,003,511.58 383,631.15 1.59 -2,371.98 MWD+IFR-AK-CAZ-SC(3) 6,591.22 59.88 262.48 4,272.28 4,223.09 -329.19 -4,341.68 6,003,502.49 383,550.22 0.89 -2,413.60 MWD+IFR-AK-CAZ-SC(3) 6,685.69 58.92 263.33 4,320.37 4,271.18 -339.24 -4,422.37 6,003,493.66 383,469.40 1.28 -2,455.36 MWD+IFR-AK-CAZ-SC(3) 6,780.41 58.86 263.66 4,369.31 4,320.12 -348.43 -4,502.94 6,003,485.68 383,388.70 0.30 -2,497.72 MWD+IFR-AK-CAZ-SC(3) 6,874.99 59.65 264.80 4,417.66 4,368.47 -356.59 -4,583.81 6,003,478.73 383,307.72 1.33 -2,541.08 MWD+IFR-AK-CAZ-SC(3) 6,969.42 59.59 264.74 4,465.42 4,416.23 -364.02 -4,664.94 6,003,472.52 383,226.50 0.08 -2,585.17 MWD+IFR-AK-CAZ-SC(3) 7,063.64 59.72 263.98 4,513.02 4,463.83 -372.01 -4,745.85 6,003,465.75 383,145.48 0.71 -2,628.69 MWD+IFR-AK-CAZ-SC(3) 7,158.19 59.44 263.57 4,560.89 4,511.70 -380.85 -4,826.91 6,003,458.13 383,064.31 0.48 -2,671.63 MWD+IFR-AK-CAZ-SC(3) 7,253.22 60.16 264.45 4,608.70 4,559.51 -389.42 -4,908.59 6,003,450.79 382,982.52 1.10 -2,715.16 MWD+IFR-AK-CAZ-SC(3) 7,347.71 59.62 264.11 4,656.10 4,606.91 -397.57 -4,989.92 6,003,443.86 382,901.08 0.65 -2,758.82 MWD+IFR-AK-CAZ-SC(3) 7,442.38 60.78 263.66 4,703.15 4,653.96 -406.32 -5,071.60 6,003,436.34 382,819.28 1.29 -2,802.21 MWD+IFR-AK-CAZ-SC(3) 7,537.00 60.23 262.90 4,749.73 4,700.54 -415.96 -5,153.39 6,003,427.93 382,737.36 0.91 -2,844.97 MWD+IFR-AK-CAZ-SC(3) 7,631.28 59.06 263.69 4,797.38 4,748.19 -425.46 -5,234.19 6,003,419.65 382,656.44 1.44 -2,887.22 MWD+IFR-AK-CAZ-SC(3) 7,726.19 59.37 261.98 4,845.96 4,796.77 -435.63 -5,315.09 6,003,410.69 382,575.41 1.58 -2,929.01 MWD+IFR-AK-CAZ-SC(3) 7,820.72 60.44 262.86 4,893.36 4,844.17 -446.41 -5,396.16 6,003,401.13 382,494.19 1.39 -2,970.43 MWD+IFR-AK-CAZ-SC(3) 7,915.17 59.71 262.70 4,940.47 4,891.28 -456.70 -5,477.36 6,003,392.06 382,412.84 0.79 -3,012.32 MWD+IFR-AK-CAZ-SC(3) 8,010.18 60.22 263.77 4,988.03 4,938.84 -466.39 -5,559.04 6,003,383.60 382,331.04 1.11 -3,054.97 MWD+IFR-AK-CAZ-SC(3) 8,104.63 59.44 263.54 5,035.50 4,986.31 -475.41 -5,640.20 6,003,375.80 382,249.76 0.85 -3,097.82 MWD+IFR-AK-CAZ-SC(3) 4/11/2011 10:02:40AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-125 Project: Western North Slope TVD Reference: Rig:CD3-125 @ 49.19ft(D19) Site: CD3 Fiord Pad MD Reference: Rig:CD3-125 @ 49.19ft(D19) Well: CD3-125 North Reference: True Wellbore: CD3-125PB1 Survey Calculation Method: Minimum Curvature Design: CD3-125PB1 Database: CPA(EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S •,E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0/100') (ft) Survey Tool Name 8,198.42 60.85 262.19 5,082.19 5,033.00 -485.52 -5,720.90 6,003,366.90 382,168.92 1.95 -3,139.54 MWD+IFR-AK-CAZ-SC(3) 8,293.03 59.76 263.49 5,129.06 5,079.87 -495.77 -5,802.44 6,003,357.88 382,087.24 1.66 -3,181.67 MWD+IFR-AK-CAZ-SC(3) 8,388.23 60.20 261.70 5,176.69 5,127.50 -506.39 -5,884.18 6,003,348.49 382,005.36 1.69 -3,223.62 MWD+IFR-AK-CAZ-SC(3) 8,482.34 60.13 262.43 5,223.51 5,174.32 -517.66 -5,965.03 6,003,338.43 381,924.35 0.68 -3,264.52 MWD+IFR-AK-CAZ-SC(3) 8,576.54 59.95 262.06 5,270.55 5,221.36 -528.68 -6,045.90 6,003,328.64 381,843.34 0.39 -3,305.62 MWD+IFR-AK-CAZ-SC(3) 8,671.84 58.81 263.13 5,319.09 5,269.90 -539.25 -6,127.22 6,003,319.29 381,761.87 1.54 -3,347.36 MWD+IFR-AK-CAZ-SC(3) 8,765.85 58.51 260.03 5,368.00 5,318.81 -551.00 -6,206.64 6,003,308.73 381,682.30 2.83 -3,386.99 MWD+IFR-AK-CAZ-SC(3) 8,860.50 58.64 255.96 5,417.36 5,368.17 -567.80 -6,285.61 6,003,293.12 381,603.09 3.67 -3,422.38 MWD+IFR-AK-CAZ-SC(3) 8,955.10 56.65 252.17 5,468.00 5,418.81 -589.70 -6,362.44 6,003,272.38 381,525.95 3.98 -3,452.42 MWD+IFR-AK-CAZ-SC(3) 9,049.74 56.30 250.16 5,520.27 5,471.08 -615.17 -6,437.10 6,003,248.04 381,450.92 1.81 -3,478.32 MWD+IFR-AK-CAZ-SC(3) 9,144.20 55.19 244.46 5,573.47 5,524.28 -645.24 -6,509.10 6,003,219.05 381,378.49 5.12 -3,498.94 MWD+IFR-AK-CAZ-SC(3) 9,196.07 53.34 242.29 5,603.76 5,554.57 -664.10 -6,546.73 6,003,200.76 381,340.57 4.92 -3,507.25 MWD+IFR-AK-CAZ-SC(3) 9,238.79 51.34 240.43 5,629.87 5,580.68 -680.30 -6,576.41 6,003,185.01 381,310.65 5.81 -3,512.76 MWD+IFR-AK-CAZ-SC(3) 9,286.65 52.04 238.55 5,659.54 5,610.35 -699.37 -6,608.77 6,003,166.43 381,278.02 3.41 -3,517.65 MWD+IFR-AK-CAZ-SC(3) 9,333.30 53.15 236.55 5,687.87 5,638.68 -719.25 -6,640.03 6,003,147.02 381,246.47 4.15 -3,521.23 MWD+IFR-AK-CAZ-SC(3) 9,428.09 54.33 233.40 5,743.95 5,694.76 -763.12 -6,702.60 6,003,104.10 381,183.25 2.95 -3,525.18 MWD+IFR-AK-CAZ-SC(3) 9,522.62 53.98 228.90 5,799.32 5,750.13 -811.16 -6,762.25 6,003,056.96 381,122.89 3.88 -3,524.05 MWD+IFR-AK-CAZ-SC(3) 9,617.14 54.44 223.12 5,854.63 5,805.44 -864.38 -6,817.37 6,003,004.58 381,066.99 4.98 -3,516.05 MWD+IFR-AK-CAZ-SC(3) 9,711.80 55.13 217.26 5,909.25 5,860.06 -923.43 -6,867.22 6,002,946.29 381,016.25 5.11 -3,500.21 MWD+IFR-AK-CAZ-SC(3) 9,766.18 55.41 214.53 5,940.23 5,891.04 -959.63 -6,893.42 6,002,910.50 380,989.51 4.16 -3,487.82 MWD+IFR-AK-CAZ-SC(3) 9,806.19 55.85 213.00 5,962.82 5,913.63 -987.08 -6,911.77 6,002,883.32 380,970.75 3.34 -3,477.48 MWD+IFR-AK-CAZ-SC(3) 9,900.78 54.49 211.29 6,016.84 5,967.65 -1,052.81 -6,953.09 6,002,818.23 380,928.46 2.07 -3,451.12 MWD+IFR-AK-CAZ-SC(3) 9,995.42 53.50 211.46 6,072.48 6,023.29 -1,118.18 -6,992.95 6,002,753.47 380,887.63 1.06 -3,424.15 MWD+IFR-AK-CAZ-SC(3) 10,089.85 53.99 210.09 6,128.32 6,079.13 -1,183.60 -7,031.91 6,002,688.65 380,847.69 1.28 -3,396.58 MWD+IFR-AK-CAZ-SC(3) 10,184.74 56.30 205.67 6,182.57 6,133.38 -1,252.42 -7,068.27 6,002,620.39 380,810.31 4.53 -3,364.74 MWD+IFR-AK-CAZ-SC(3) 10,279.11 56.23 200.37 6,235.00 6,185.81 -1,324.61 -7,098.94 6,002,548.68 380,778.56 4.67 -3,326.74 MWD+IFR-AK-CAZ-SC(3) 10,371.95 58.86 195.81 6,284.84 6,235.65 -1,399.05 -7,123.21 6,002,474.61 380,753.18 5.02 -3,283.02 MWD+IFR-AK-CAZ-SC(3) 10,419.76 60.66 193.75 6,308.92 6,259.73 -1,438.98 -7,133.74 6,002,434.84 380,742.05 5.29 -3,258.03 MWD+IFR-AK-CAZ-SC(3) 10,467.72 61.42 192.13 6,332.14 6,282.95 -1,479.88 -7,143.13 6,002,394.10 380,732.04 3.35 -3,231.59 MWD+IFR-AK-CAZ-SC(3) 10,562.24 61.06 189.53 6,377.62 6,328.43 -1,561.25 -7,158.70 6,002,312.97 380,715.25 2.44 -3,177.05 MWD+IFR-AK-CAZ-SC(3) 10,657.01 60.44 185.95 6,423.94 6,374.75 -1,643.17 -7,169.84 6,002,231.25 380,702.88 3.36 -3,119.36 MWD+IFR-AK-CAZ-SC(3) 10,751.39 57.70 181.77 6,472.46 6,423.27 -1,723.90 -7,175.33 6,002,150.61 380,696.18 4.78 -3,059.12 MWD+IFR-AK-CAZ-SC(3) 10,846.07 60.23 180.46 6,521.27 6,472.08 -1,805.01 -7,176.90 6,002,069.54 380,693.40 2.92 -2,996.18 MWD+IFR-AK-CAZ-SC(3) 10,940.37 61.94 180.06 6,566.87 6,517.68 -1,887.55 -7,177.27 6,001,987.03 380,691.79 1.85 -2,931.36 MWD+IFR-AK-CAZ-SC(3) 11,034.96 64.61 182.56 6,609.41 6,560.22 -1,971.99 -7,179.22 6,001,902.63 380,688.57 3.68 -2,866.02 MWD+IFR-AK-CAZ-SC(3) 11,129.74 68.07 181.75 6,647.44 6,598.25 -2,058.73 -7,182.48 6,001,815.95 380,684.01 3.73 -2,799.68 MWD+IFR-AK-CAZ-SC(3) 11,224.49 70.96 180.02 6,680.60 6,631.41 -2,147.46 -7,183.84 6,001,727.26 380,681.32 3.50 -2,730.59 MWD+IFR-AK-CAZ-SC(3) 11,318.83 72.90 177.24 6,709.86 6,660.67 -2,237.11 -7,181.68 6,001,637.60 380,682.13 3.48 -2,658.62 MWD+IFR-AK-CAZ-SC(3) 11,413.22 73.02 173.66 6,737.53 6,688.34 -2,327.05 -7,174.52 6,001,547.56 380,687.94 3.63 -2,583.33 MWD+IFR-AK-CAZ-SC(3) 11,507.67 73.73 169.87 6,764.56 6,715.37 -2,416.60 -7,161.56 6,001,457.84 380,699.55 3.92 -2,504.79 MWD+IFR-AK-CAZ-SC(3) 4/11/2011 10:02:40AM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-125 Project: Western North Slope TVD Reference: Rig:CD3-125 @ 49.19ft(D19) Site: CD3 Fiord Pad MD Reference: Rig:CD3-125 @ 49.19ft(D19) Well: CD3-125 North Reference: True Wellbore: CD3-125PB1 Survey Calculation Method: Minimum Curvature Design: CD3-125PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/1004) (ft) Survey Tool Name 11,602.24 73.40 165.07 6,791.33 6,742.14 -2,505.12 -7,141.89 6,001,369.04 380,717.89 4.88 -2,422.93 MWD+IFR-AK-CAZ-SC(3) 11,696.92 73.34 161.09 6,818.44 6,769.25 -2,591.89 -7,115.49 6,001,281.89 380,742.98 4.03 -2,338.30 MWD+IFR-AK-CAZ-SC(3) 11,790.35 74.12 160.27 6,844.61 6,795.42 -2,676.53 -7,085.82 6,001,196.83 380,771.37 1.19 -2,253.33 MWD+IFR-AK-CAZ-SC(3) 11,885.96 77.62 157.69 6,867.96 6,818.77 -2,763.05 -7,052.56 6,001,109.83 380,803.33 4.50 -2,164.68 MWD+IFR-AK-CAZ-SC(3) 11,980.47 78.87 157.17 6,887.21 6,838.02 -2,848.49 -7,017.04 6,001,023.87 380,837.56 1.43 -2,075.49 MWD+IFR-AK-CAZ-SC(3) 12,074.93 80.13 155.75 6,904.42 6,855.23 -2,933.63 -6,979.95 6,000,938.19 380,873.36 1.99 -1,985.55 MWD+IFR-AK-CAZ-SC(3) 12,169.58 79.18 153.02 6,921.42 6,872.23 -3,017.58 -6,939.70 6,000,853.65 380,912.34 3.01 -1,894.62 MWD+IFR-AK-CAZ-SC(3) 12,264.16 78.81 148.34 6,939.49 6,890.30 -3,098.51 -6,894.25 6,000,772.06 380,956.57 4.87 -1,802.87 MWD+IFR-AK-CAZ-SC(3) 12,358.16 81.33 146.24 6,955.70 6,906.51 -3,176.40 -6,844.22 6,000,693.43 381,005.42 3.47 -1,710.68 MWD+IFR-AK-CAZ-SC(3) 12,452.13 81.87 142.43 6,969.43 6,920.24 -3,251.91 -6,790.03 6,000,617.12 381,058.47 4.05 -1,617.82 MWD+IFR-AK-CAZ-SC(3) 12,546.75 81.76 139.11 6,982.91 6,933.72 -3,324.45 -6,730.81 6,000,543.71 381,116.59 3.47 -1,524.20 MWD+IFR-AK-CAZ-SC(3) 12,641.48 82.94 138.91 6,995.52 6,946.33 -3,395.31 -6,669.22 6,000,471.93 381,177.09 1.26 -1,430.44 MWD+IFR-AK-CAZ-SC(3) 12,673.01 84.07 139.08 6,999.08 6,949.89 -3,418.96 -6,648.67 6,000,447.98 381,197.29 3.62 -1,399.16 MWD+IFR-AK-CAZ-SC(3) 12,723.02 84.61 139.43 7,004.01 6,954.82 -3,456.66 -6,616.19 6,000,409.80 381,229.20 1.28 -1,349.45 MWD+IFR-AK-CAZ-SC(3) 12,754.00 84.61 139.43 7,006.92 6,957.73 -3,480.09 -6,596.13 6,000,386.07 381,248.90 0.00 -1,318.63 PROJECTED to TD 4/11/2011 10:02:40AM Page 6 COMPASS 2003.16 Build 69 A 0 10 • r Ai M0 0 w A I• t AI • a 1111! ConocoPhillii p��s(Alaska) Inc. 0 Western North Slope at0 • , CD3 Fiord Pad 0 ivI g CD3-125 moa*. 501032063200 0 ili 014 4• l' : Sperry Drilling Definitive Survey Report op a 11 April, 2011 1 - 11 1 N 0 girt 4 HALLIBURTON It , Sperry Drilfingri ..yaw ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-125 Project: Western North Slope TVD Reference: Rig:CD3-125 @ 49.19ft(D19) Site: CD3 Fiord Pad MD Reference: Rig:CD3-125 @ 49.19ft(D19) Well: CD3-125 North Reference: True Wellbore: CD3-125 Survey Calculation Method: Minimum Curvature Design: CD3-125 Database: CPAI EDM Production 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 Well CD3-125 Well Position +N/-S 0.00 ft Northing: 6,003,766.42 ft Latitude: 70°25'9.210 N +EI-W 0.00 ft Easting: 387,895.98 ft Longitude: 150°54'47.701 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.60ft Wellbore CD3-125 Magnetics Model Name Sample Date Declination Dip Angle Field Strength I (0) (0) (nT) BGGM2010 3/26/2011 20.68 80.83 57,604 Design CD3-125 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,442.38 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 36.59 0.00 0.00 142.00 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 85.06 868.06 CD3-125PB1 Gyro(R100)(CD3-125PB1 CB-GYRO-SS Camera based gyro single shot 2/3/2011 12:OC 962.29 2,931.22 CD3-125PB1 MWD(R100)(CD3-125PB MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/3/2011 12:0C 2,998.33 7,442.38 CD3-125PB1 MWD(R200)(CD3-125PB MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/10/2011 12:C 7,500.00 11,499.77 CD3-125 MWD(R400)(CD3-125) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/23/2011 12:C 11,600.29 16,467.05 CD3-125 MWD(R600)(CD3-125) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/1/2011 12:0C Survey , Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 36.59 0.00 0.00 36.59 -12.60 0.00 0.00 6,003,766.42 387,895.98 0.00 0.00 UNDEFINED 85.06 0.44 122.77 85.06 35.87 -0.10 0.16 6,003,766.32 387,896.13 0.91 0.18 CB-GYRO-SS(1) 115.06 0.37 124.52 115.06 65.87 -0.22 0.33 6,003,766.20 387,896.31 0.24 0.38 CB-GYRO-SS(1) 145.06 0.39 128.85 145.06 95.87 -0.34 0.49 6,003,766.08 387,896.47 0.12 0.57 CB-GYRO-SS(1) E 175.06 0.54 104.19 175.06 125.87 -0.44 0.71 6,003,765.98 387,896.68 0.82 0.78 CB-GYRO-SS(1) 202.06 0.14 143.66 202.06 152.87 -0.49 0.85 6,003,765.92 387,896.82 1.63 0.91 CB-GYRO-SS(1) 274.06 1.57 347.02 274.05 224.86 0.40 0.68 6,003,766.81 387,896.67 2.36 0.11 CB-GYRO-SS(1) 365.06 3.38 330.52 364.96 315.77 3.95 -0.92 6,003,770.38 387,895.12 2.12 -3.68 CB-GYRO-SS(1) 457.06 4.74 327.32 456.73 407.54 9.51 -4.31 6,003,775.99 387,891.82 1.50 -10.14 CB-GYRO-SS(1) 549.06 5.65 327.58 548.35 499.16 16.53 -8.79 6,003,783.08 387,887.44 0.99 -18.44 CB-GYRO-SS(1) 4111/2011 9:56:15AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-125 Project: Western North Slope TVD Reference: Rig:CD3-125 @ 49.19ft(D19) Site: CD3 Fiord Pad MD Reference: Rig:CD3-125 @ 49.19ft(D19) Well: CD3-125 North Reference: True Wellbore: CD3-125 Survey Calculation Method: Minimum Curvature Design: CD3-125 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section 1 (ft) (°) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 641.06 7.21 321.82 639.77 590.58 24.89 -14.78 6,003,791.53 387,881 57 1.83 -28.72 CB-GYRO-SS(1) 733.06 8.57 320.09 730.90 681.71 34.69 -22.75 6,003,801.45 387,873.75 1.50 -41.34 CB-GYRO-SS(1) 825.06 10.20 315.31 821.66 772.47 45.74 -32.88 6,003,812.65 387,863.79 1.96 -56.28 CB-GYRO-SS(1) 868.06 11.02 312.29 863.93 814.74 51.21 -38.60 6,003,818.20 387,858.16 2.30 -64.12 CB-GYRO-SS(1) 962.29 13.97 309.76 955.92 906.73 64.55 -54.00 6,003,831.77 387,842.95 3.18 -84.11 MWD+IFR-AK-CAZ-SC(2) 1,054.38 14.67 311.69 1,045.14 995.95 79.41 -71.26 6,003,846.89 387,825.93 0.92 -106.45 MWD+IFR-AK-CAZ-SC(2) 1,145.86 13.85 309.39 1,133.81 1,084.62 94.07 -88.37 6,003,861.80 387,809.04 1.09 -128.53 MWD+IFR-AK-CAZ-SC(2) 1,238.38 14.90 302.12 1,223.44 1,174.25 107.42 -107.01 6,003,875.43 387,790.61 2.25 -150.53 MWD+IFR-AK-CAZ-SC(2) 1,330.21 18.65 292.92 1,311.36 1,262.17 119.42 -130.54 6,003,887.78 387,767.26 4.99 -174.48 MWD+IFR-AK-CAZ-SC(2) F 1,424.43 22.31 284.50 1,399.63 1,350.44 129.77 -161.75 6,003,898.60 387,736.21 4.98 -201.84 MWD+IFR-AK-CAZ-SC(2) 1,516.69 25.53 275.81 1,483.98 1,434.79 136.17 -198.50 6,003,905.55 387,699.56 5.17 -229.52 MWD+IFR-AK-CAZ-SC(2) 1,609.50 28.83 272.22 1,566.53 1,517.34 139.07 -240.77 6,003,909.08 387,657.34 3.97 -257.82 MWD+IFR-AK-CAZ-SC(2) 1,700.29 31.65 270.92 1,644.96 1,595.77 140.30 -286.47 6,003,910.99 387,611.67 3.19 -286.93 MWD+IFR-AK-CAZ-SC(2) 1,792.85 34.36 268.39 1,722.58 1,673.39 139.95 -336.88 6,003,911.41 387,561.27 3.28 -317.69 MWD+IFR-AK-CAZ-SC(2) 1,885.33 37.12 269.20 1,797.64 1,748.45 138.83 -390.88 6,003,911.10 387,507.26 3.03 -350.05 MWD+IFR-AK-CAZ-SC(2) 1,980.65 39.47 268.03 1,872.44 1,823.25 137.39 -449.92 6,003,910.54 387,448.21 2.58 -385.26 MWD+IFR-AK-CAZ-SC(2) 2,072.85 42.70 267.19 1,941.93 1,892.74 134.85 -510.45 6,003,908.91 387,387.65 3.55 -420.53 MWD+IFR-AK-CAZ-SC(2) 2,166.10 45.57 266.21 2,008.85 1,959.66 131.09 -575.27 6,003,906.13 387,322.79 3.16 -457.48 MWD+IFR-AK-CAZ-SC(2) 2,258.88 48.42 264.59 2,072.13 2,022.94 125.63 -642.89 6,003,901.68 387,255.10 3.33 -494.80 MWD+IFR-AK-CAZ-SC(2) 2,349.99 50.50 263.82 2,131.34 2,082.15 118.63 -711.77 6,003,895.72 387,186.13 2.37 -531.69 MWD+IFR-AK-CAZ-SC(2) 2,441.38 53.21 262.80 2,187.79 2,138.60 110.25 -783.14 6,003,888.41 387,114.65 3.09 -569.03 MWD+IFR-AK-CAZ-SC(2) 2,533.48 55.85 262.75 2,241.23 2,192.04 100.82 -857.55 6,003,880.10 387,040.11 2.87 -607.41 MWD+IFR-AK-CAZ-SC(2) 2,628.48 57.79 262.87 2,293.21 2,244.02 90.87 -936.43 6,003,871.33 386,961.10 2.04 -648.13 MWD+IFR-AK-CAZ-SC(2) 2,720.81 59.23 263.41 2,341.44 2,292.25 81.47 -1,014.60 6,003,863.11 386,882.80 1.64 -688.84 MWD+IFR-AK-CAZ-SC(2) 2,813.36 58.80 262.75 2,389.09 2,339.90 71.91 -1,093.36 6,003,854.73 386,803.91 0.77 -729.81 MWD+IFR-AK-CAZ-SC(2) 2,906.62 59.96 263.81 2,436.59 2,387.40 62.52 -1,173.07 6,003,846.55 386,724.08 1.58 -771.48 MWD+IFR-AK-CAZ-SC(2) 2,931.22 59.76 263.85 2,448.94 2,399.75 60.23 -1,194.22 6,003,844.58 386,702.90 0.83 -782.70 MWD+IFR-AK-CAZ-SC(2) 2,998.33 58.51 264.90 2,483.37 2,434.18 54.58 -1,251.54 6,003,839.79 386,645.50 2.30 -813.54 MWD+IFR-AK-CAZ-SC(3) 3,092.38 58.42 264.41 2,532.56 2,483.37 47.12 -1,331.35 6,003,833.52 386,565.60 0.45 -856.79 MWD+IFR-AK-CAZ-SC(3) 3,187.59 59.30 264.17 2,581.80 2,532.61 39.01 -1,412.44 6,003,826.63 386,484.41 0.95 -900.32 MWD+IFR-AK-CAZ-SC(3) 3,282.87 59.95 264.76 2,629.97 2,580.78 31.08 -1,494.26 6,003,819.94 386,402.49 0.87 -944.45 MWD+IFR-AK-CAZ-SC(3) 3,377.51 59.88 265.08 2,677.42 2,628.23 23.83 -1,575.83 6,003,813.91 386,320.82 0.30 -988.95 MWD+IFR-AK-CAZ-SC(3) 3,471.85 59.93 264.42 2,724.72 2,675.53 16.36 -1,657.10 6,003,807.67 386,239.45 0.61 -1,033.11 MWD+IFR-AK-CAZ-SC(3) 3,566.70 60.80 264.62 2,771.62 2,722.43 8.49 -1,739.17 6,003,801.03 386,157.28 0.94 -1,077.43 MWD+IFR-AK-CAZ-SC(3) 3,659.58 60.53 264.86 2,817.13 2,767.94 1.07 -1,819.80 6,003,794.82 386,076.56 0.37 -1,121.22 MWD+IFR-AK-CAZ-SC(3) 3,754.06 60.28 265.14 2,863.79 2,814.60 -6.09 -1,901.64 6,003,788.89 385,994.62 0.37 -1,165.96 MWD+IFR-AK-CAZ-SC(3) 3,848.42 60.59 263.67 2,910.35 2,861.16 -14.10 -1,983.32 6,003,782.11 385,912.84 1.39 -1,209.94 MWD+IFR-AK-CAZ-SC(3) 3,942.37 61.43 262.77 2,955.88 2,906.69 -23.80 -2,064.92 6,003,773.63 385,831.11 1.23 -1,252.54 MWD+IFR-AK-CAZ-SC(3) 4,037.19 60.93 262.10 3,001.59 2,952.40 -34.74 -2,147.27 6,003,763.94 385,748.61 0.81 -1,294.62 MWD+IFR-AK-CAZ-SC(3) 4,131.72 59.69 260.65 3,048.41 2,999.22 -47.05 -2,228.46 6,003,752.85 385,667.25 1.87 -1,334.90 MWD+IFR-AK-CAZ-SC(3) 4/11/2011 9:56:15AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-125 Project: Western North Slope TVD Reference: Rig:CD3-125 @ 49.19ft(D19) Site: CD3 Fiord Pad MD Reference: Rig:CD3-125 @ 49.19ft(D19) Well: CD3-125 North Reference: True Wellbore: CD3-125 Survey Calculation Method: Minimum Curvature Design: CD3-125 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) 0100') (ft) Survey Tool Name 4,225.88 59.61 261.10 3,095.99 3,046.80 -59.93 -2,308.69 6,003,741.17 385,586.85 0.42 -1,374.14 MWD+IFR-AK-CAZ-SC(3) 4,320.91 59.52 259.60 3,144.13 3,094.94 -73.67 -2,389.46 6,003,728.65 385,505.89 1.36 -1,413.05 MWD+IFR-AK-CAZ-SC(3) 4,414.21 59.82 260.48 3,191.24 3,142.05 -87.59 -2,468.77 6,003,715.92 385,426.38 0.88 -1,450.91 MWD+IFR-AK-CAZ-SC(3) 4,510.13 59.93 263.43 3,239.39 3,190.20 -99.20 -2,550.91 6,003,705.55 385,344.09 2.66 -1,492.33 MWD+IFR-AK-CAZ-SC(3) 4,604.94 59.85 262.95 3,286.96 3,237.77 -108.93 -2,632.35 6,003,697.05 385,262.52 0.45 -1,534.80 MWD+IFR-AK-CAZ-SC(3) 4,699.41 60.57 264.65 3,333.89 3,284.70 -117.78 -2,713.85 6,003,689.42 385,180.90 1.74 -1,578.00 MW D+I FR-AK-CAZ-SC(3) 4,794.72 60.49 265.26 3,380.78 3,331.59 -125.07 -2,796.50 6,003,683.37 385,098.15 0.56 -1,623.14 MWD+IFR-AK-CAZ-SC(3) 4,889.30 61.57 265.44 3,426.59 3,377.40 -131.78 -2,878.98 6,003,677.90 385,015.59 1.15 -1,668.63 MWD+IFR-AK-CAZ-SC(3) 4,983.78 62.13 264.96 3,471.17 3,421.98 -138.75 -2,961.99 6,003,672.18 384,932.49 0.74 -1,714.24 MWD+IFR-AK-CAZ-SC(3) 5,078.17 61.91 264.36 3,515.45 3,466.26 -146.51 -3,044.98 6,003,665.67 384,849.40 0.61 -1,759.23 MWD+IFR-AK-CAZ-SC(3) 5,172.68 61.99 263.56 3,559.89 3,510.70 -15528 -3,127.93 6,003,658.14 384,766.34 0.75 -1,803.38 MWD+IFR-AK-CAZ-SC(3) 5,267.44 61.29 262.72 3,604.91 3,555.72 -16524 -3,210.72 6,003,649.43 384,683.42 1.07 -1,846.50 MWD+IFR-AK-CAZ-SC(3) 5,360.04 61.35 263.27 3,649.35 3,600.16 -175.15 -3,291.35 6,003,640.73 384,602.65 0.53 -1,888.34 MWD+IFR-AK-CAZ-SC(3) 5,456.16 61.06 262.10 3,695.65 3,646.46 -185.87 -3,374.90 6,003,631.26 384,518.96 1.11 -1,931.32 MWD+IFR-AK-CAZ-SC(3) 5,550.46 60.30 262.14 3,741.82 3,692.63 -197.15 -3,456.34 6,003,621.22 384,437.37 0.81 -1,972.58 MWD+IFR AK-CAZ-SC(3) 5,645.94 60.29 262.45 3,789.14 3,739.95 -208.27 -3,538.52 6,003,611.33 384,355.03 0.28 -2,014.42 MWD+IFR-AK-CAZ-SC(3) 5,740.18 60.36 262.52 3,835.79 3,786.60 -218.97 -3,619.70 6,003,601.85 384,273.71 0.10 -2,055.96 MWD+IFR-AK-CAZ-SC(3) 5,835.03 60.17 261.68 3,882.84 3,833.65 -230.29 -3,701.28 6,003,591.75 384,191.98 0.79 -2,097.26 MWD+IFR-AK-CAZ-SC(3) 5,929.00 60.05 260.34 3,929.67 3,880.48 -243.02 -3,781.74 6,003,580.24 384,111.34 1.24 -2,136.77 MWD+IFR-AK-CAZ-SC(3) 6,024.17 59.58 259.13 3,977.52 3,928.33 -257.68 -3,862.69 6,003,566.80 384,030.18 1.20 -2,175.06 MWD+IFR-AK-CAZ-SC(3) 6,119.27 58.77 259.98 4,026.25 3,977.06 -272.49 -3,943.00 6,003,553.20 383,949.67 1.15 -2,212.83 MWD+IFR-AK-CAZ-SC(3) 6,213.43 58.41 261.29 4,075.33 4,026.14 -285.57 -4,022.29 6,003,541.31 383,870.20 1.25 -2,251.34 MWD+IFR-AK-CAZ-SC(3) 6,307.67 58.07 262.04 4,124.93 4,075.74 -297.18 -4,101.57 6,003,530.89 383,790.76 0.77 -2,291.00 MWD+IFR-AK-CAZ-SC(3) 6,402.04 57.93 261.97 4,174.94 4,125.75 -308.31 -4,180.82 6,003,520.95 383,711.36 0.16 -2,331.02 MWD+IFR-AK-CAZ-SC(3) 6,496.71 59.16 262.98 4,224.34 4,175.15 -318.88 -4,260.88 6,003,511.58 383,631.15 1.59 -2,371.98 MWD+IFR-AK-CAZ-SC(3) 6,591.22 59.88 262.48 4,272.28 4,223.09 -329.19 -4,341.68 6,003,502.49 383,550.22 0.89 -2,413.60 MWD+IFR-AK-CAZ-SC(3) 6,685.69 58.92 263.33 4,320.37 4,271.18 -339.24 -4,422.37 6,003,493.66 383,469.40 1.28 -2,455.36 MWD+IFR-AK-CAZ-SC(3) 6,780.41 58.86 263.66 4,369.31 4,320.12 -348.43 -4,502.94 6,003,485.68 383,388.70 0.30 -2,497.72 MWD+IFR-AK-CAZ-SC(3) 6,874.99 59.65 264.80 4,417.66 4,368.47 -356.59 -4,583.81 6,003,478.73 383,307.72 1.33 -2,541.08 MWD+IFR-AK-CAZ-SC(3) 6,969.42 59.59 264.74 4,465.42 4,416.23 -364.02 -4,664.94 6,003,472.52 383,226.50 0.08 -2,585.17 MWD+IFR-AK-CAZ-SC(3) 7,063.64 59.72 263.98 4,513.02 4,463.83 -372.01 -4,745.85 6,003,465.75 383,145.48 0.71 -2,628.69 MWD+IFR-AK-CAZ-SC(3) 7,158.19 59.44 263.57 4,560.89 4,511.70 -380.85 -4,826.91 6,003,458.13 383,064.31 0.48 -2,671.63 MWD+IFR-AK-CAZ-SC(3) 7,253.22 60.16 264.45 4,608.70 4,559.51 -389.42 -4,908.59 6,003,450.79 382,982.52 1.10 -2,715.16 MWD+IFR-AK-CAZ-SC(3) 7,347.71 59.62 264.11 4,656.10 4,606.91 -397.57 -4,989.92 6,003,443.86 382,901.08 0.65 -2,758.82 MWD+IFR AK-CAZ-SC(3) 7,442.38 60.78 263.66 4,703.15 4,653.96 -406.32 -5,071.60 6,003,436.34 382,819.28 1.29 -2,802.21 MWD+IFR-AK-CAZ-SC(3) 7,500.00 60.44 263.20 4,731.42 4,682.23 -412.06 -5,121.48 6,003,431.35 382,769.33 0.91 -2,828.39 MWD+IFR-AK-CAZ-SC(4) 7,523.85 59.52 262.67 4,743.35 4,694.16 -414.60 -5,141.97 6,003,429.11 382,748.80 4.31 -2,839.00 MWD+IFR-AK-CAZ-SC(4) 7,587.27 57.36 261.05 4,776.55 4,727.36 -422.24 -5,195.46 6,003,422.28 382,695.21 4.04 -2,865.91 MWD+IFR-AK-CAZ-SC(4) 7,682.24 56.42 260.15 4,828.43 4,779.24 -435.23 -5,273.94 6,003,410.47 382,616.55 1.27 -2,903.99 MWD+IFR-AK-CAZ-SC(4) 7,775.71 56.52 258.81 4,880,06 4,830.87 -449.46 -5,350.55 6,003,397.40 382,539.75 1.20 -2,939.95 MWD+IFR-AK-CAZ-SC(4) 4/11/2011 9:56:15AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-125 Project: Western North Slope TVD Reference: Rig:CD3-125 @ 49.19ft(D19) Site: CD3 Fiord Pad PLOD Reference: Rig:CD3-125 @ 49.19ft(D19) Well: CD3-125 North Reference: True Wellbore: CD3-125 Survey Calculation Method: Minimum Curvature Design: CD3-125 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S -±±E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,869.44 55.72 258.09 4,932.31 4,883.12 -465.04 -5,426.78 6,003,382.97 382,463.29 1.07 -2,974.61 MWD+IFR-AK-CAZ-SC(4) 7,965.92 55.07 257.47 4,987.10 4,937.91 -481.84 -5,504.40 6,003,367.33 382,385.44 0.86 -3,009.15 MWD+IFR-AK-CAZ-SC(4) 8,060.45 55.78 255.44 5,040.75 4,991.56 -500.08 -5,580.06 6,003,350.23 382,309.52 1.92 -3,041.36 MWD+IFR-AK-CAZ-SC(4) 8,153.28 56.07 254.77 5,092.76 5,043.57 -519.84 -5,654.36 6,003,331.59 382,234.93 0.67 -3,071.53 MWD+IFR-AK-CAZ-SC(4) 8,247.07 56.12 254.42 5,145.08 5,095.89 -540.52 -5,729.41 6,003,312.04 382,159.59 0.31 -3,101.44 MWD+IFR-AK-CAZ-SC(4) 8,342.28 55.51 253.66 5,198.57 5,149.38 -562.18 -5,805.13 6,003,291.53 382,083.56 0.92 -3,131.00 MWD+IFR-AK-CAZ-SC(4) 8,436.66 56.25 251.89 5,251.52 5,202.33 -585.32 -5,879.76 6,003,269.51 382,008.60 1.74 -3,158.70 MWD+IFR-AK-CAZ-SC(4) 8,529.19 55.59 250.74 5,303.37 5,254.18 -609.86 -5,952.35 6,003,246.06 381,935.65 1.25 -3,184.05 MWD+IFR-AK-CAZ-SC(4) 8,626.19 54.89 246.82 5,358.68 5,309.49 -638.69 -6,026.62 6,003,218.36 381,860.96 3.40 -3,207.06 MWD+IFR-AK-CAZ-SC(4) 8,718.01 53.69 242.82 5,412.29 5,363.10 -670.38 -6,094.08 6,003,187.68 381,793.05 3.77 -3,223.62 MWD+IFR-AK-CAZ-SC(4) 8,815.38 53.07 240.09 5,470.38 5,421.19 -707.71 -6,162.72 6,003,151.39 381,723.86 2.34 -3,236.46 MWD+IFR-AK-CAZ-SC(4) 8,909.99 52.87 237.82 5,527.36 5,478.17 -746.66 -6,227.42 6,003,113.43 381,658.58 1.93 -3,245.61 MWD+IFR-AK-CAZ-SC(4) 9,003.93 51.72 235.94 5,584.82 5,535.63 -787.25 -6,289.67 6,003,073.77 381,595.74 2.00 -3,251.94 MWD+IFR-AK-CAZ-SC(4) 9,098.97 50.00 232.98 5,644.81 5,595.62 -830.07 -6,349.65 6,003,031.86 381,535.12 3.02 -3,255.13 MWD+IFR-AK-CAZ-SC(4) 9,193.22 49.23 225.88 5,705.92 5,656.73 -876.69 -6,404.13 6,002,986.07 381,479.95 5.79 -3,251.94 MWD+IFR-AK-CAZ-SC(4) 9,239.66 49.50 222.47 5,736.17 5,686.98 -901.96 -6,428.69 6,002,961.18 381,455.03 5.60 -3,247.14 MWD+IFR-AK-CAZ-SC(4) 9,288.56 49.32 221.75 5,767.99 5,718.80 -929.51 -6,453.59 6,002,934.01 381,429.72 1.18 -3,240.76 MWD+IFR-AK-CAZ-SC(4) 9,383.10 48.84 219.59 5,829.92 5,780.73 -983.68 -6,500.14 6,002,880.54 381,382.36 1.80 -3,226.73 MWD+IFR-AK-CAZ-SC(4) 9,477.65 50.64 217.07 5,891.02 5,841.83 -1,040.28 -6,544.86 6,002,824.62 381,336.79 2.79 -3,209.66 MWD+IFR-AK-CAZ-SC(4) 9,571.87 50.55 212-29 5,950.86 5,901.67 -1,100.12 -6,586.27 6,002,765.42 381,294.50 3.92 -3,188.00 MWD+IFR-AK-CAZ-SC(4) 9,666.53 51.14 208.55 6,010.64 5,961.45 -1,163.40 -6,623.41 6,002,702.71 381,256.41 3.13 -3,161.01 MWD+IFR-AK-CAZ-SC(4) 9,760.86 52.54 204.72 6,068.93 6,019.74 -1,229.69 -6,656.63 6,002,636.93 381,222.20 3.52 -3,129.22 MWD+IFR-AK-CAZ-SC(4) 9,855.72 52.77 199.07 6,126.51 6,077.32 -1,299.62 -6,684.73 6,002,567.44 381,193.06 4.74 -3,091.42 MWD+IFR-AK-CAZ-SC(4) 9,950.44 51.94 195.36 6,184.37 6,135.18 -1,371.23 -6,706.93 6,002,496.18 381,169.79 3.22 -3,048.65 MWD+IFR-AK-CAZ-SC(4) 10,044.95 51.91 191.29 6,242.67 6,193.48 -1,443.60 -6,724.07 6,002,424.08 381,151.56 3.39 -3,002.18 MWD+IFR-AK-CAZ-SC(4) 10,138.10 53.29 187.39 6,299.26 6,250.07 -1,516.59 -6,736.05 6,002,351.28 381,138.49 3.64 -2,952.04 MWD+IFR-AK-CAZ-SC(4) 10,234.08 54.14 183.43 6,356.07 6,306.88 -1,593.59 -6,743.33 6,002,274.40 381,130.06 3.44 -2,895.84 MWD+IFR-AK-CAZ-SC(4) 10,328.16 56.15 180.09 6,409.85 6,360.66 -1,670.74 -6,745.67 6,002,197.31 381,126.56 3.61 -2,836.49 MWD+IFR-AK-CAZ-SC(4) 10,422.91 56.23 179.56 6,462.57 6,413.38 -1,749.46 -6,745.43 6,002,118.60 381,125.61 0.47 -2,774.31 MWD+IFR-AK-CAZ-SC(4) 10,518.17 54.92 178.80 6,516.42 6,467.23 -1,828.03 -6,744.31 6,002,040.03 381,125.55 1.52 -2,711.71 MWD+IFR-AK-CAZ-SC(4) 10,612.53 55.61 178.22 6,570.19 6,521.00 -1,905.55 -6,742.30 6,001,962.50 381,126.41 0.89 -2,649.38 MWD+IFR-AK-CAZ-SC(4) 10,705.63 55.46 177.09 6,622.87 6,573.68 -1,982.24 -6,739.16 6,001,885.77 381,128.40 1.01 -2,587.01 MWD+IFR-AK-CAZ-SC(4) 10,801.54 55.43 177.52 6,677.27 6,628.08 -2,061.14 -6,735.44 6,001,806.83 381,130.92 0.37 -2,522.55 MWD+IFR-AK-CAZ-SC(4) 10,894.50 55.75 178.74 6,729.81 6,680.62 -2,137.79 -6,732.94 6,001,730.16 381,132.27 1.14 -2,460.61 MWD+IFR-AK-CAZ-SC(4) 10,988.88 56.48 179.17 6,782.43 6,733.24 -2,216.13 -6,731.51 6,001,651.82 381,132.52 0.86 -2,398.00 MWD+IFR-AK-CAZ-SC(4) 11,084.90 56.91 179.29 6,835.15 6,785.96 -2,296.37 -6,730.43 6,001,571.57 381,132.40 0.46 -2,334.11 MWD+IFR-AK-CAZ-SC(4) 11,131.96 59.38 178.84 6,859.99 6,810.80 -2,336.33 -6,729.78 6,001,531.61 381,132.45 5.31 -2,302.21 MWD+IFR-AK-CAZ-SC(4) 11,179.42 61.58 177.61 6,883.37 6,834.18 -2,377.61 -6,728.50 6,001,490.32 381,133.12 5.15 -2,268.89 MWD+IFR-AK-CAZ-SC(4) 11,225.72 64.32 176.35 6,904.43 6,855.24 -2,418.78 -6,726.32 6,001,449.13 381,134.67 6.39 -2,235.11 MWD+IFR-AK-CAZ-SC(4) 11,272.30 66.66 175.93 6,923.75 6,874.56 -2,461.06 -6,723.46 6,001,406.81 381,136.89 5.09 -2,200.03 MWD+IFR-AK-CAZ-SC(4) 4/11/2011 9:56:15AM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-125 Project: Western North Slope TVD Reference: Rig:CD3-125 @ 49.19ft(D19) Site: CD3 Fiord Pad MD Reference: Rig:CD3-125 @ 49.19ft(D19) Well: CD3-125 North Reference: True Wellbore: CD3-125 Survey Calculation Method: Minimum Curvature Design: CD3-125 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 11,319.04 67.23 175.57 6,942.05 6,892.86 -2,503.95 -6,720.28 6,001,363.88 381,139.44 1.41 -2,164.27 MWD+IFR-AK-CAZ-SC(4) 11,368.86 70.41 175.83 6,960.05 6,910.86 -2,550.27 -6,716.79 6,001,317.52 381,142.22 6.40 -2,125.63 MWD+IFR-AK-CAZ-SC(4) 11,414.17 73.07 173.37 6,974.25 6,925.06 -2,593.10 -6,712.74 6,001,274.64 381,145.63 7.81 -2,089.38 MWD+IFR-AK-CAZ-SC(4) 11,461.90 77.62 172.17 6,986.32 6,937.13 -2,638.90 -6,706.92 6,001,228.76 381,150.76 9.84 -2,049.72 MWD+IFR-AK-CAZ-SC(4) 11,600.29 86.06 170.91 7,005.95 6,956.76 -2,774.27 -6,686.77 6,001,093.12 381,168.87 6.16 -1,930.64 MWD+IFR-AK-CAZ-SC(5) 11,691.40 89.16 171.58 7,009.75 6,960.56 -2,864.23 -6,672.92 6,001,002.97 381,181.37 3.48 -1,851.22 MWD+IFR-AK-CAZ-SC(5) 11,788.19 91.50 171.30 7,009.19 6,960.00 -2,959.93 -6,658.51 6,000,907.07 381,194.34 2.43 -1,766.94 MWD+IFR-AK-CAZ-SC(5) 11,884.30 90.64 168.74 7,007.39 6,958.20 -3,054.56 -6,641.86 6,000,812.20 381209.57 2.81 -1,682.11 MWD+IFR-AK-CAZ-SC(5) 11,978.19 89.28 166.46 7,007.46 6,958.27 -3,146.25 -6,621.70 6,000,720.23 381,228.35 2.83 -1,597.45 MWD+IFR-AK-CAZ-SC(5) 12,077.27 89.15 165.02 7,008.82 6,959.63 -3,242.27 -6,597.30 6,000,623.87 381,251.30 1.46 -1,506.76 MWD+IFR-AK-CAZ-SC(5) 12,163.38 90.02 160.70 7,009.44 6,960.25 -3,324.53 -6,571.93 6,000,541.24 381,275.43 5.12 -1,426.32 MWD+IFR-AK-CAZ-SC(5) 12,268.21 88.54 157.64 7,010.76 6,961.57 -3,422.49 -6,534.66 6,000,442.74 381,311.22 3.24 -1,326.18 MWD+IFR-AK-CAZ-SC(5) 12,363.96 88.79 155.63 7,012.99 6,963.80 -3,510.36 -6,496.70 6,000,354.32 381,347.86 2.11 -1,233.57 MWD+IFR-AK-CAZ-SC(5) 12,459.21 87.49 152.31 7,016.08 6,966.89 -3,595.89 -6,454.93 6,000,268.18 381,388.33 3.74 -1,140.46 MWD+IFR-AK-CAZ-SC(5) 12,554.61 88.60 149.49 7,019.34 6,970.15 -3,679.18 -6,408.57 6,000,184.20 381,433.44 3.18 -1,046.27 MWD+IFR-AK-CAZ-SC(5) 12,649.93 88.54 147.34 7,021.71 6,972.52 -3,760.35 -6,358.66 6,000,102.30 381,482.12 2.26 -951.58 MWD+IFR-AK-CAZ-SC(5) 12,745.55 88.97 144.15 7,023.79 6,974.60 -3,839.36 -6,304.86 6,000,022.50 381,534.72 3.37 -856.20 MWD+IFR-AK-CAZ-SC(5) 12,840.92 89.09 137.78 7,025.41 6,976.22 -3,913.39 -6,244.83 5,999,947.58 381,593.62 6.68 -760.91 MWD+IFR-AK-CAZ-SC(5) 12,937.00 88.60 137.59 7,027.35 6,978.16 -3,984.42 -6,180.16 5,999,875.59 381,657.21 0.55 -665.12 MWD+IFR-AK-CAZ-SC(5) 13,031.26 88.04 138.69 7,030.11 6,980.92 -4,054.59 -6,117.29 5,999,804.49 381,719.02 1.31 -571.12 MWD+IFR AK-CAZ-SC(5) 13,126.37 88.17 141.06 7,033.25 6,984.06 -4,127.27 -6,056.04 5,999,730.91 381,779.17 2.49 -476.13 MWD+IFR-AK-CAZ-SC(5) 13,221.45 89.03 144.79 7,035.58 6,986.39 -4,203.10 -5,998.74 5,999,654.24 381,835.31 4.02 -381.11 MWD+IFR-AK-CAZ-SC(5) 13,317.74 88.48 144.26 7,037.67 6,988.48 -4,281.49 -5,942.88 5,999,575.02 381,889.99 0.79 -284.94 MWD+IFR-AK-CAZ-SC(5) 13,413.40 89.28 144.94 7,039.54 6,990.35 -4,359.45 -5,887.47 5,999,496.24 381,944.21 1.10 -189.40 MWD+IFR-AK-CAZ-SC(5) 13,508.68 88.47 144.80 7,041.41 6,992.22 -4,437.36 -5,832.66 5,999,417.53 381,997.85 0.86 -94.25 MWD+IFR-AK-CAZ-SC(5) 13,604.31 89.16 145.43 7,043.39 6,994.20 -4,515.79 -5,777.98 5,999,338.29 382,051.34 0.98 1.21 MWD+IFR-AK-CAZ-SC(5) 13,699.72 89.59 144.69 7,044.43 6,995.24 -4,594.00 -5,723.34 5,999,259.28 382,104.80 0.90 96.48 MWD+IFR-AK-CAZ-SC(5) 13,795.38 89.28 143.11 7,045.37 6,996.18 -4,671.28 -5,666.98 5,999,181.16 382,159.98 1.68 192.08 MWD+IFR-AK-CAZ-SC(5) 13,890.67 90.14 142.72 7,045.86 6,996.67 -4,747.30 -5,609.52 5,999,104.30 382,216.29 0.99 287.36 MWD+IFR-AK-CAZ-SC(5) 13,986.11 90.20 142.44 7,045.57 6,996.38 -4,823.09 -5,551.53 5,999,027.65 382,273.13 0.30 382.79 MWD+IFR-AK-CAZ-SC(5) 14,080.35 89.90 141.43 7,045.49 6,996.30 -4,897.29 -5,493.42 5,998,952.59 382,330.11 1.12 477.03 MWD+IFR-AK-CAZ-SC(5) 14,176.60 91.32 143.13 7,044.47 6,995.28 -4,973.42 -5,434.54 5,998,875.60 382,387.83 2.30 573.27 MWD+IFR-AK-CAZ-SC(5) 14,272.74 90.14 142.67 7,043.24 6,994.05 -5,050.09 -5,376.56 5,998,798.07 382,444.66 1.32 669.38 MWD+IFR-AK-CAZ-SC(5) 14,367.95 89.71 142.56 7,043.37 6,994.18 -5,125.74 -5,318.75 5,998,721.57 382,501.32 0.47 764.59 MWD+IFR-AK-CAZ-SC(5) 14,463.58 88.84 140.65 7,044.58 6,995.39 -5,200.68 -5,259.36 5,998,645.75 382,559.57 2.19 860.20 MWD+IFR-AK-CAZ-SC(5) 14,559.43 89.16 142.24 7,046.25 6,997.06 -5,275.62 -5,199.63 5,998,569.93 382,618.16 1.69 956.03 MWD+IFR-AK-CAZ-SC(5) 14,654.92 89.28 142.19 7,047.55 6,998.36 -5,351.08 -5,141.13 5,998,493.60 382,675.51 0.14 1,051.51 MWD+IFR-AK-CAZ-SC(5) 14,749.73 89.34 140.82 7,048.69 6,999.50 -5,425.28 -5,082.12 5,998,418.54 382,733.40 1.45 1,146.31 MWD+IFR-AK-CAZ-SC(5) 14,845.17 88.66 140.45 7,050.36 7,001.17 -5,499.05 -5,021.60 5,998,343.87 382,792.80 0.81 1,241.71 MWD+IFR-AK-CAZ-SC(5) 14,940.69 88.91 143.77 7,052.38 7,003.19 -5,574.41 -4,962.96 5,998,267.65 382,850.30 3.48 1,337.19 MWD+IFR-AK-CAZ-SC(5) 4/11/2011 9:56:15AM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-125 Project: Western North Slope TVD Reference: Rig:CD3-125 @ 49.19ft(D19) Site: CD3 Fiord Pad MD Reference: Rig:CD3-125 @ 49.19ft(D19) Well: CD3-125 North Reference: True Wellbore: CD3-125 Survey Calculation Method: Minimum Curvature Design: CD3-125 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 15,035.92 89.40 145.94 7,053.79 7,004.60 -5,652.2€ -4,908.15 5,998,188.98 382,903.93 2.34 1,432.29 MWD+IFR-AK-CAZ-SC(5) 15,131.46 90.76 146.68 7,053.65 7,004.46 -5,731.76 -4,855.15 5,998,108.71 382,955.72 1.62 1,527.55 MWD+IFR-AK-CAZ-SC(5) 15,226.77 90.20 145.79 7,052.85 7,003.66 -5,810.99 -4,802.18 5,998,028.70 383,007.49 1.10 1,622.60 MWD+IFR-AK-CAZ-SC(5) 15,321.90 90.58 144.94 7,052.21 7,003.02 -5,889.25 -4,748.12 5,997,949.64 383,060.37 0.98 1,717.56 MWD+IFR-AK-CAZ-SC(5) 15,417.40 90.64 142.93 7,051.19 7,002.00 -5,966.44 -4,691.90 5,997,871.62 383,115.41 2.11 1,813.00 MWD+IFR-AK-CAZ-SC(5) 15,512.92 90.82 143.01 7,049.97 7,000.78 -6,042.69 -4,634.38 5,997,794.52 383,171.78 0.21 1,908.50 MWD+I FR-AK-CAZ-SC(5) 15,608.45 91.44 142.29 7,048.09 6,998.90 -6,118.62 -4,576.44 5,997,717.74 383,228.57 0.99 2,004.00 MWD+IFR-AK-CAZ-SC(5) 15,704.82 90.20 142.19 7,046.71 6,997.52 -6,194.80 -4,517.43 5,997,640.69 383,286.42 1.29 2,100.36 MWD+IFR-AK-CAZ-SC(5) 15,799.25 90.08 14433 7,046.48 6,997.29 -6,270.47 -4,460.95 5,997,564.19 383,341.76 2.27 2,194.76 MWD+IFR-AK-CAZ-SC(5) 15,894.83 92.37 147.20 7,044.44 6,995.25 -6,349.45 -4,407.20 5,997,484.41 383,394.31 3.84 2,290.09 MWD+IFR-AK-CAZ-SC(5) 15,990.08 90.82 145.28 7,041.78 6,992.59 -6,428.60 -4,354.29 5,997,404.48 383,446.02 2.59 2,385.04 MWD+IFR-AK-CAZ-SC(5) 16,085.92 87.42 142.57 7,043.26 6,994.07 -6,506.04 -4,297.88 5,997,326.21 383,501.26 4.54 2,480.79 MWD+IFR-AK-CAZ-SC(5) 16,181.46 85.88 144.20 7,048.84 6,999.65 -6,582.59 -4,240.99 5,997,248.82 383,556.98 2.34 2,576.13 MWD+IFR-AK-CAZ-SC(5) 16,277.00 86.50 144.44 7,055.19 7,006.00 -6,660.02 -4,185.39 5,997,170.57 383,611.41 0.70 2,671.38 MWD+IFR-AK-CAZ-SC(5) 16,372.43 86.31 144.65 7,061.17 7,011.98 -6,737.60 -4,130.15 5,997,092.17 383,665.48 0.30 2,766.53 MWD+IFR-AK-CAZ-SC(5) 16,467.05 86.13 143.75 7,067.41 7,018.22 -6,814.18 -4,074.92 5,997,014.79 383,719.55 0.97 2,860.88 MWD+IFR-AK-CAZ-SC(5) 16,529.00 86.13 143.75 7,071.59 7,022.40 -6,864.02 -4,038.37 5,996,964.40 383,755.34 0.00 2,922.66 PROJECTED to TD 4/11/2011 9:56:15AM Page 7 COMPASS 2003.16 Build 69 ConocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: CD3-125 Rig Name: DOYON 19 Job Type: DRILLING ORIGINAL Rig Accept: 3/8/2011 4:30:00 PM Rig Release: 4/9/2011 5:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/30/2011 24 hr Summary Completed 1 E-08A. Rig released @ 12:00 12:00 00:00 12.00 0 0 MIRU MOVE DMOB P Rig down and prep for move from 1E-08A to Alpine CD3-125.Camp off 1E Pad @ 12:00 hrs.Continue rig down Doyon 141 and prep for rig move. Disconnect outside choke line, prep cellar, Disconnect mud lines, Blow down water lines, Drain centrifigal pumps,Clean pits in rockwasher, Rig down geronimo line, Check air pressure on all tires. Sim-ops--Change pump liners to 6", Unload drillpipe from shed. 01/31/2011 Camp moved to CD3. Initiated rig move, Pits,motor complex and boiler house.5 Impassable loads. 00:00 05:00 5.00 0 0 MIRU MOVE MOB P Continue prep for rig move. Disconnect tioga, Rockwasher,jack up pipe sheds, Blow down all steam lines, Disconnect steam lines between modules, Disconnect service lines between modules.Sim -ops Slip and cut drill line. 05:00 16:00 11.00 0 0 MIRU MOVE MOB P Hook up Trucks to complexes and rockwasher,Move complexes and rockwasher from 1 E-08A to Alpine CD3 pad and stage.Sim-Ops-- Clean well area and pad on 1 E location, Stack rig mails. (5 complexes moved-Pits, Boiler house,Motor complex and rockwasher) 16:00 19:30 3.50 0 0 MIRU MOVE MOB P Send trucks back to 1E-pad for sub and pipe shed complexes. Fuel cold starts, Install tow bar,riding shacks. 19:30 00:00 4.50 0 0 MIRU MOVE MOB P Load pipe sheds and stage at pad entrance. Hook up weighted SOW and D8 Cats(2)to sub and pull sub off well. Position grater behind sub. Pull sub and pipesheds off 1 E Pad and start move to CD3 Pad 02/01/2011 Completed rig move,Spotted rig over well, Rigged up,Took on Spud mud. Nippled up surface riser. Loaded pipeshed with drillpipe and BHA tools Page 1 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 0 0 MIRU MOVE MOB P Move substructure and pit complexes onto CD3 pad. Sim-ops- Place portable heater with truck on conductor, Put Diverter adapter in shop to warm.Stage wellhead equipment in cellar area. Fuel rig complexes. 12:00 15:30 3.50 0 0 MIRU MOVE MOB P Spot substructure over well CD3-125, Spot complexes, Rockwasher and pipeshed. 15:30 18:00 2.50 0 0 MIRU DRILL RURD P Rig up shot glasses for rockwasher, Fuel rig and camp, Unload rig equipment from camp. Complete rig acceptance checklist. Rig accepted at 18:00 Hrs. 18:00 00:00 6.00 0 0 SURFA( DRILL NUND P Nipple up surface stack, Load pipeshed with Drillpipe and BHA tools.Took on 290 bbl's spud mud to pit 6. 02/02/2011 Nippled up surface stack, Picked up clean out BHA, Filled conductor, Pressure tested surface lines to 3,500 psi.Cleaned out conductor to 114'MD continued drilling to make sufficient hole depth for picking up remaining BHA.Tripped out picked up remaining BHA. Drilled to 698'at 24:00 hrs 00:00 03:30 3.50 0 0 SURFA(WHDBO NUND P Complete nipple up of surface stack. -Sim ops complete loading pipeshed with drillpipe and BHA components, Orient gyro on rig floor for North heading and establish azimuth direction. 03:30 08:00 4.50 0 0 SURFA( DRILL PULD P PJSM, Pick up 69 joints 5"drillpipe (23 stands)Pick up 24 joints 5" HWDP(8 Stands)Racked back in derrick. 08:00 09:30 1.50 0 0 SURFA( DRILL PULD P Make up Clean out assembly. 09:30 10:00 0.50 0 0 SURFA( DRILL PRTS P Fill conductor check for leaks. Pressure test surface lines to 3,500 psi. (No leaks found) 10:00 10:30 0.50 0 0 SURFA( DRILL REAM P Wash and Ream to clean out conductor to 114'.Tagged ice @ 80' 10:30 13:30 3.00 0 228 SURFA( DRILL DDRL P Drill F/114'MD-T/228'MD 228' ND. ADT 2.44 ART 2.44 AST 0.0 P/U 45K,S/0 45K, Rot 45K WOB 10, RPM 50 Torque On/Off 2K-1K 480 GPM, Psi on,970 Off 900 psi 13:30 14:00 0.50 228 228 SURFA( DRILL SRVY P Gyro Survey's 76'MD.44° INC, 121.65°AZ/166' MD.54° INC 104.19°AZ 14:00 18:00 4.00 228 228 SURFA( DRILL PULD P Trip out to Top of Mudmotor, Pick up MWD components and remaining_/ BHA.Orient Motor,MWD obtain offset. Load MWD data, Pulse test. Page 2 of 39 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 18:00 00:00 6.00 228 698 SURFA( DRILL DDRL P Drill F/228'MD-T/698'MD 695' ND.ADT 3.09 ART 1.15 AST 1.94. Total bit and Jar hrs 5.53 P/U 75K,S/O 75K, Rot 75K WOB 20, RPM 50 Torq On/Off 3K-1K 500 GPM, Psi on, 1050 Off 980 psi. Gyro surveys taken at each connection. 02/03/2011 Drilled surface interval F/698'-T/2,689'. Loaded pipeshed with casing, Drifted and strapped same. 00:00 12:00 12.00 698 1,737 SURFA( DRILL DDRL P Drill F/698'MD-T/1,737'MD 1,674' ND.ADT 7.92 Hrs. ART 3.55 Hrs. AST 4.37'Hrs.Total bit and Jar hrs 13.45. P/U 96K,S/O 90K, Rot 92K WOB 20, RPM 60 Torq On/Off 4-5K-2-3K 500 GPM, Psi on, 1350 Off 1160 psi. Gyro Released @ 816'MD. 12:00 00:00 12.00 1,737 2,689 SURFA( DRILL DDRL P Drill F/1,737'MD-T/2,689"MD 2,320'ND.ADT 8.80 Hrs. ART 6.30 Hrs. AST 2.50'Hrs.Total bit and Jar hrs 22.25. P/U 105K,5/0 88K, Rot 96K WOB 20, RPM 60 Torq On/Off 5K-3K 500 GPM, Psi on, 1650 psi.Slide percentage to 2,889-37%.Sim-Ops load pipeshed with 9-5/8"casing, Drift and strap. 02/04/2011 TD surface section @ 2,966'MD.Circulate, Backream to HWDP,Trip to bottom w/no problems,Trip out lay D down BHA.Clean and Clear floor r� 00:00 05:15 5.25 2,689 2,966 SURFA( DRILL DDRL P Drill F/2,689'MD-T/2,966"MD (Surface TD)2,462'ND.ADT 4.14 Hrs. ART 3.6 Hrs. AST.54'Hrs. Total bit and Jar hrs 26.39. P/U 107K,S/0 89K, Rot 96K WOB 30, RPM 60 Torq On/Off 6K-4K 500 GPM, Psi on, 1,725 psi.off 1,550. (Picked up Single to TD section) 05:15 06:30 1.25 2,966 2,966 SURFA( DRILL CIRC P Circulate 2 X bottoms up,550 gpm, 65 rpm, 1,800 psi. layed down single, Racked back 2 stands while circulating. 06:30 07:00 0.50 2,966 2,966 SURFA( DRILL OWFF P Monitor well 20 minutes. (Well Static) 07:00 11:30 4.50 2,966 906 SURFA( DRILL REAM P Back ream F/2,745'MD-T/906' MD.(At HWDP)550 gpm, 1,700 psi, 65 rpm,Torq-5k. Hole fill for trip calculated 13.2 bbl's actual hole fill 13.0 bbl's.(Heavy cuttings load visible at shakers) 11:30 12:00 0.50 906 906 SURFA( DRILL OWFF P Observe well for flow(Well Static) 12:00 13:00 1.00 906 2,966 SURFA( DRILL TRIP P Trip in hole F/906'MD-T/2,966'MD. No hole problems evident.Good displacement Page 3 of 39 Time Logs Date From To Dur S. Depth E.Death Phase Code Subcode T Comment 13:00 16:00 3.00 2,966 2,966 SURFA( DRILL 'CIRC P Circulate and weight up system to 10.0 ppg,550 gpm, 1,800 psi,Vis 220 in,Vis 300 out. up wt 105k dn wt 87k 16:00 19:00 3.00 2,966 906 SURFA( DRILL TRIP P Blow down top drive, Monitor well 20 minutes,Trip out on elevators w/no problems evident. 19:00 21:00 2.00 906 74 SURFA( DRILL PULD P Lay down 24 joints 5"HWDP,Jars,2 Non Mag Flex Collars 21:00 23:00 2.00 74 0 SURFA( DRILL PULD P Down load MWD,lay down MWD, Drain and Break bit, Lay down motor. 23:00 23:30 0.50 0 0 SURFA( DRILL PULD P Clear small BHA components from floor,Clean floor 23:30 00:00 0.50 0 0 SURFA( CASING SFTY P Pre Job Safety Meeting on rigging up for 9-5/8"casing run 02/05/2011 Rig up&run 9-5/8"Surface casing. Circulate and condition,Cement per Program. Nipple down Surface stack, 00:00 01:00 1.00 0 0 SURFA( CASING RURD P Riq up to run 9-5/8"Surface casing 01:00 01:30 0.50 0 0 SURFA( CASING SFTY P Pre Job Safety Meeting for running 9-5/8"Casing. Review running order, Discuss hazards associated with task. Hand pinch points, Positions of people,Watch out for casing stabber. 01:30 02:00 0.50 0 160 SURFA(CASING RNCS P Pick up casing float equipment, Fill pipe check floats. (Joints baker locked.) 02:00 04:00 2.00 160 1,493 SURFA( CASING RNCS P Run casing F/160'-T/1,485'.Good returns with no tight spots. 04:00 05:00 1.00 1,493 1,493 SURFA( CASING CIRC P Circulate Bottoms up,Stage pumps up to 5 bbl per min with no losses. Reciprocate full joint.Mud wt in and out 10.0 ppg Vis out 300+Vis in 259. Pumped 140 bbls while circulating.Annular capacity at 1,485'MD 83 bbl's. 05:00 07:00 2.00 1,493 2,953 SURFA( CASING RNCS P Run Casing to 2,925',Make up lamding joint, Land casing at 2,953' , MD. Up wt 142k dn wt 85k. Calculated displacement 42.45 bbl's Actual displacement 36.5 bbl's 07:00 09:00 2.00 2,953 2,953 SURFA( CEMEN"CIRC P Circulate and condition through Franks fill up tool.Stage pumps up to 5 bpm with 400 psi.404 bbl's circulated. Up wt 125k dn wt 100k. Sim ops rig down csg equip. 09:00 09:30 0.50 2,953 2,953 SURFA( CEMEN"RURD P PJSM, Rig down franks tool, Make up X-O and cement head to landing joint. (Spill drill held during operation with 2 min response time) 09:30 12:30 3.00 2,953 2,953 SURFA(CEMEN"CIRC P Circulate and condition for correct mud properties prior to cement job.6 bpm flow rate with 400 psi. 125k up wt 100k down wt Page 4 of 39 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 12:30 16:00 3.50 2,953 2,953 SURFA( CEMEN"CMNT P PJSM with cementer, Pump 80 bbl spacer viscosified nut plug, 50 bbl Desco pill, Swap over to Schlumberger, Pump 5 bbl's water, Pressure test lines to 3,500 psi. Bleed off pressure. Drop bottom plug. Pump 50 bbl mudpush @ 10.5 ppg, 4LA tor Pump 337 bbl's 10.5 ppg Lead 01^' cement, Pump 49 bbl's 15.8 ppg Tail cement. Drop top plug.Chase with 20 bbl's water with DS. Displace cement with rig pumps 197.5 bbl's 05 • mud. Bump plug @ 1,968 strokes. CIP at 15:23 hrs. Pressure up 500 ✓ psi over final circulating pressure. Bleed off pressure check floats. Floats Good) 16:00 16:30 0.50 0 0 SURFA(CEMEN"PRTS P Test casing to 3,500 psi for 30 min. Test Charted.) 16:30 19:30 3.00 0 0 SURFA(CEMEN"RURD P Rig down cement lines,Cement& Casing equipment, Lay down landing joint, Function diverter hydril and flush. Flush and wash surface stack. 19:30 22:00 2.50 0 0 SURFA(WHDBO NUND P PJSM, Nipple down surface stack, Clean and prep for casing head per FMC rep. 22:00 00:00 2.00 0 0 SURFA(WHDBO NUND P Nipple up casing head with FMC Rep 02/06/2011 N/U BOPE,Shell test,Set Tubing Wear Bushing, Rig Up and Run 3-1/2"Tubing kill string, Land tubing with 2 way check installed, Nipple down BOPE, Nipple up tree,Test tree, Displace and freeze protect well,Secure tree, Release Doyon 141 @ 24:00 00:00 02:30 2.50 0 0 SURFA(WHDBO NUND P PJSM, Nipple Up BOPE and related equipment 02:30 03:30 1.00 0 0 SURFA(WHDBO BOPE P make up test joint, Rig up to shell test BOPE,Close annular pressure test BOP shell 250 psi low test 5 min,2,000 psi high test 10 min.Test charted. Rig down from test 03:30 04:00 0.50 0 0 SURFA( RPCOM NUND P Set wear bushing for tubing run. 04:00 08:30 4.50 0 2,800 SURFA( RPCOM PUTB P Rig uo and run 3-1/2"EUE Tubing 9.3 ppf L-80. Run order-WLEG,89 joints tubing,4.5"X 3.5"crossover 5.10 c' pup joint, Pup on tubing hanger, Hanger.Calculated displacement 8.9 bbl's,Actual Displacement 9.75 bbl's 08:30 09:30 1.00 2,800 2,800 SURFA( RPCOM NUND P Rig up FMC wear bushing removal tool and pull wear bushing 09:30 10:30 1.00 2,800 2,833 SURFA( RPCOM HOSO P Make up hanger and landing joint, land tubing. Install 2 way check. Tubing landed @ 2,833'MD. Run in lock downs, Pull landing joint. 10:30 11:00 0.50 2,833 0 SURFA( DRILL PULD P Clear and clean rig floor 11:00 13:30 2.50 0 0 SURFA(WHDBO NUND P PJSM, Nipple down BOPE, Nipple up Tree.(Fire drill held with 1.5 min response time) Page 5 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 14:30 1.00 0 0 SURFA(WHDBO PRTS P Test tubing adapter void to 5,000 psi for 10 min.Test tree with diesel 250 psi low, 5,000 psi high. Each test held for 5 min.Witnessed by Conoco rig Supervisor. 14:30 15:30 1.00 0 0 SURFA(WHDBO NUND P Pull 2 way check valve, Rig up to lines to displace. 15:30 17:00 1.50 0 0 SURFA( DRILL CIRC P pump 25 bbl sweep and displace mud from well with fresh water. Pump water until returns clean. 17:00 18:30 1.50 0 0 SURFA( DRILL FRZP P Freeze protect well. Pump 132 bbl's diesel down annulus take returns 4 18:30 19:30 through tubing to pits. 1.00 0 0 SURFA( DRILL FRZP P Rig up hose and U-tube diesel. `✓ \� 19:30 20:00 0.50 0 0 SURFA(WHDBO NUND P Set BPV,Secure well. 20:00 00:00 4.00 0 0 SURFA( DRILL DMOB P Prep for rig move, Unhook Glycol lines, Blow down water and steam .l�O� �4 lines on sub.Off load all fluids, Blow PP \\ down Power pack. Release rig @ I`�o 24.00 hr,. 13/08/2011 Move rig frorge CD3-127 to CD3-125.Spot complexes. Hook up service lines and high line power.Accept rig at 16:30 hrs. Hook up hard line.Test casing and BPV to 2500 psi for 30 min-OK. Pull BPV.Circ out freeze protect diesel from well. 06:00 12:00 6.00 0 0 MIRU MOVE MOB P Prepare rig for move over to CD3-125 06:00 09:00 3.00 0 0 MIRU MOVE PSIT P Spot sub,pits, motors and pipeshed 09:00 10:30 1.50 0 0 MIRU MOVE RURD P Hook up air,steam,water and electrical lines. Rig on high line power at 16:30 hrs.Accept rig at 16:30 hrs. 10:30 14:00 3.50 0 0 SURFA( MOVE RURD P Take on mud. Hook up hard line to well to test casing and circ out freeze protect. Install landings on tree. 14:00 15:00 1.00 0 0 SURFA(WHDBO PRTS P Test lines to 3000 psi. Pump down annulus and test 9 5/8"casing and BPV from below to 2500 psi for 30 min. Lost 75 psi in 30 min. 15:00 16:00 1.00 0 0 SURFA(WHDBO RURD P RU lubricator and pull BPV. RU hard line to tiger tank. 16:00 17:30 1.50 0 0 SURFA( DRILL CIRC P Circ out diesel from well thru 3.5"kill string taking returns to tiger tank at 5 bpm/700 psi. Displace until 9.6 ppg LSND mud all the way around. Blow down lines. 17:30 18:00 0.50 0 0 SURFA( DRILL OWFF P Monitor well for flow-no flow. Blow down lines to tiger tank. .3/09/2011 ND tree. NU BOPE.Test to 250/3500 psi. Unseat tbg hgr. Pull&LD 3.5"killstring. Finish BOP test.MU drilling BHA. 00:00 00:45 0.75 0 0 SURFA(WHDBO PRTS P Set BPV with lubricator and test from below to 2500 psi-10 min.Good test. 00:45 01:15 0.50 0 0 SURFA(WHDBO NUND P ND Xmas tree and install blanking plug in tubing hanger. Page 6 of 39 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 01:15 03:45 2.50 0 0 SURFA(WHDBO NUND P NU BOPE. Install flowline,riser and drain lines.Adjust turnbuckles. 03:45 05:00 1.25 0 0 SURFA(WHDBO BOPE P PJSM. RU to test BOPE. Wait on arrival of AOGCC Rep John Crisp to witness test. 05:00 12:00 7.00 0 0 SURFA(WHDBO BOPE P Test BOPE to 250/3500 psi-5 min ea test.Annular to 250/2500 psi. P Test blind rams, UPR, LPR,valves 1, 5, 14, 15, 16 on choke manifold. Test 5"floor valve and kill line HCR valve. All tests done with 3.5"test joint. Blow down lines and RD test jt. 12:00 12:45 0.75 0 0 SURFA( DRILL RURD P RU tubing tongs. Install landing jt. BOLDS. 12:45 13:15 0.50 0 0 SURFA( DRILL PULL P Unseat hanger and pull to rig floor. Break&LD crossovers and hanger. 13:15 15:45 2.50 0 0 SURFA( DRILL PULL P POH and LD 3.5"tubing kill string from—2800'. 15:45 16:30 0.75 0 0 SURFA( DRILL RURD P RD tubing tongs etc. Fill stack with water. 16:30 18:30 2.00 0 0 SURFA(WHDBO BOPE P Install test plug and 5"test jt.Test BOPE to 250/3500 psi for 5 min ea test. UPR's failed test. Choke valves 16&11 failed test. Annular tested to 250/2500 psi. 18:30 19:45 1.25 0 0 SURFA( RIGMNT RGRP T Replace VBR's in upper cavity with 5"solid body rams. Re-build choke manifold valves 11 & 16. 19:45 20:30 0.75 0 0 SURFA( RIGMNT RGRP T Re-test UPR's and choke&kill line HCR+manual valves.250/3500 psi for 5 min ea test. 20:30 22:00 1.50 0 0 SURFA(WHDBO BOPE P RD test jt. Blow down lines and set drilling wear ring. RU&test choke manifold valves 11 and 16 while bringing up Geopilot skid to rig floor. Good tests to 250/3500 psi. 22:00 00:00 2.00 0 200 SURFA( DRILL TRIP P MU Geo Pilot RSS BHA with bit#2- 8.75"HTC HCM503ZX PDC.Start RIH. Seeing resistance starting at about 55'BRT.Appears to be ice/slush on BHA when pulled up to inspect. Continue to work BHA components in hole until able to PU stands of DP and circ/rotate down. 03/10/2011 MU BHA#2(RSS).Work circ and rotate in hole to clear ice from inside casing down to 800'.Single in to shoe. Drill out shoe track to 2995'MD. Perform LOT to 16.5 ppg EMW. Drill ahead to 3689'MD. 00:00 01:00 1.00 0 100 SURFA( DRILL PULD P MU BHA#2. RIH Encountered ice in casing starting at—100'. Wash down with stands from derrick to 380'. POH&rack back DP stands. Page 7 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 04:15 3.25 100 197 SURFA( DRILL PULD P Cont PU BHA. Upload MWD. Shallow test/Troubleshoot MWD detection issue. Break in Geo Pilot bearings. Pressure test Geo span skid to 3000 psi. PJSM. Load sources. Cont MU BHA components. 04:15 06:15 2.00 197 790 SURFA( DRILL PULD P Cont MU BHA and run in to 411'. Encounter more ice in casing. Wash down stands from derrick to 790'to allow room to MU remaining BHA components&HWDP. POH racking back DP. 06:15 09:00 2.75 790 2,837 SURFA( DRILL PULD P RIH PUDP from pipe shed to 2837'. 09:00 09:45 0.75 2,837 2,837 SURFA( DRILL PRTS P RU&test casing to 3500 psi for 10 min to prove integrity of lower annulus valve on wellhead-OK. 09:45 11:00 1.25 2,837 2,876 SURFA( DRILL COCF P Wash and ream from 2837'to 2876' DPM at 550 gpm @ 910 psi. Tag cement at 2865'MD.Test Geo Span skid to 4000 psi. 11:00 14:15 3.25 2,876 2,975 SURFA( CEMEN-DRLG P Drill out shoe track from 2876'to shoe at 2961'MD/2459'TVD and clean out rat hole to 2975'MD. 14:15 15:00 0.75 2,975 2,995 SURFA( DRILL DDRL P Drill 20'new hole to 2995'MD. 15:00 15:30 0.50 2,995 2,995 SURFA( DRILL CIRC P Circ btms up for FIT.MW in/out= 15:30 16:00 0.50 2,995 2,995 SURFA( DRILL FIT ' Perform FIT to 900 psi over 9.5 ppg ' MW. FIT=16.5 ppg EMW. 16:00 00:00 8.00 2,995 3,689 INTRM1 DRILL DDRL rill -lead in 8 -"hole • •- MD/2831'TVD. ADT=4.79 hrs. ECD=10.44 ppg. WOB=10/20 klbs. RPM=130. 650 gpm @ 1350 psi. String Wts: 155 klbs up. 130 klbs dn. 141 klbs rot. TQ on/off=9000/8500 ft lbs. Sweeps pumped at 3300'and 3600' brought back significant amount of clay. 03/11/2011 Drill 8 3/4"hole from 3689'MD to 5800'MD. Page 8 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 3,689 4,729 INTRMI DRILL DDRL P Drill ahead in 8 3/4"hole from 3689' to 4729'MD/3349'TVD. Limit ROP below 225 fph. RSS having issues staying hooked up at higher flowrates. ADT=7.95 hr. Footage= 1040'. Avg ROP=131 fph. ECD=10.7 ppg. WOB=10/20 klbs. RPM=120/160. 650 gpm @ 1680 psi. String Wts: UP= 180 klbs. DN=140 klbs. ROT=150 klbs. TQ ON/OFF=14000/9000 ft lbs. Running 30-40 bph water w/Resinex and Soltex. 12:00 00:00 12.00 4,729 5,800 INTRM1 DRILL DDRL P Continue drilling 8 3/4"hole from 4729'to 5800'MD/3349'TVD. ADT=7.4 hrs. Footage=1071'. Avg ROP=145 fph. ECD=10.85 ppg. WOB=15/25 klbs. RPM=150/160. 650 gpm @ 1930 psi. String Wts: UP=170 klbs. DN=152 klbs. ROP=160 klbs. Additions of Lo-Torq and Lube 776. 03/12/2011 Drill 8 3/4"hole from 5800'to 8700'MD. 00:00 12:00 12.00 5,800 7,093 INTRMI DRILL DDRL P Drill ahead in 8 3/4"hole from 5800' to 7093'MD/4528'ND. Footage drilled=1293'. ADT=6.28 hrs Avg ROP=206 fph. ECD=10.73 ppg. WOB=20/25 klbs. RPM=150. Flowrate=650 gpm @ 1900 psi. String Wts: UP= 188 klbs. DN=165 klbs. ROT=175 klbs. TQ ON/OFF=12000/9500 ft lbs. Housing roll on RSS much reduced once in Qannik formation. Page 9 of 39 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 12:00 00:00 12.00 7,093 8,700 INTRMI DRILL DDRL P Drill ahead in 8 3/4"hole from 7093' to 8700'MD/5333'TVD. Footage drilled=1607'. ADT=7.3 hrs. Avg ROP=220 fph. ECD=10.95 ppg. WOB=30 klbs. RPM= 160. Flowrate=650 gpm @ 2200 psi. String Wts: PU=215 klbs. SO= 172 klbs. ROT=192 klbs. TQ ON/OFF BTM: 13500/12000 ft lbs. ROP improvement when increased WOB to 30 klbs from 25 klbs. 03/13/2011 Drill 8 3/4"hole from 10015'to 10497'MD/6346'TVD.Circ hole clean. POH for short trip to shoe to wipe hole and check hole condition. 00:00 12:00 12.00 8,700 10,015 INTRM1 DRILL DDRL P Drill 8 3/4"hole from 8700'MD to 10015'MD/6084'ND. Footage=1315' ADT=6.33 hrs. Avg ROP=208 fph. ECD=10.76 ppg. WOB=25/30 klbs. RPM=150. 650 gpm @ 2030 psi. String Wts: PUW=245 klbs SOW= 180 klbs. ROT=210 klbs. TQ ON/OFF BTM=17000/16000 ft lbs. 12:00 15:30 3.50 10,015 10,497 INTRM1 DRILL DDRL P Drill from 10015'MD to 10497' MD/6346'ND. Footage=482'. ADT=2.55 hrs. Avg ROP= 189 fph. ECD=10.86 ppg. WOB=30 klbs. RPM= 150 650 gpm @ 2130 psi. String Wts: PUW=250 klbs. SOW=180 klbs. ROT=210 klbs. TQ ON/OFF BTM=18000/17000 klbs. 15:30 17:30 2.00 10,497 10,497 INTRM1 DRILL CIRC P Circ hole clean 650 gpm @ 2150 psi. Rotate 150 rpm.Circ sweep around- brought back moderate increase in cuttings. 17:30 17:45 0.25 10,497 10,497 INTRMI DRILL OWFF P Monitor well for flow-OK.Slight drop in fluid level at flowline. Blow down top drive. Page 10 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:45 21:45 4.00 10,497 6,242 INTRM1 DRILL TRIP P POH on elevators from 10308'to 6242'MD.Tight spot(25-50 klbs over from 10110'-10100'. Drop back down and wipe clean- OK. POH to 9450'-trying to swab. Pull up to 9370'. Drop back down and work stand-OK.Add defoamer to trip tank-mud aired up. Continue POH to 6148'MD(top std #47). 21:45 23:15 1.50 6,242 5,864 INTRM1 DRILL REAM P Backream from 6242'to 5864'across Qannik interval. 650 gpm @ 1600 psi. 150 rpm @ 12000 ft lbs TQ. Circulated out a fair amount of soft, mushy cuttings then shakers cleaned up. 23:15 23:30 0.25 5,864 5,864 INTRM1 DRILL OWFF P Monitor well for flow-slight drop in fluid level below flowline. Blow down top drive. 23:30 00:00 0.50 5,864 5,391 INTRMI DRILL TRIP P Continue POH on elevators from 5864'to 5391'MD. 03/14/2011 POH from 5391'to 3122'. Backream to shoe and pump sweep around. Cut drilling line and replace air swivel on top drive. RIH and drill ahead to 11253'MD/6689'ND. THRZ came in at 10880'MD. BHRZ at 11228'MD. 00:00 02:00 2.00 5,391 3,122 INTRM1 DRILL TRIP P POH on elevators from 5391'to 3122' MD.At middle of std#32(-4775') pulled tight. Drop back down and worked through tight spot on 3rd attempt-50-60 klbs overpull. Run back in and wipe entire stand again- OK. 02:00 03:00 1.00 3,122 2,932 INTRM1 DRILL CIRC P Circ viscosified nutplug sweep surf to surf while backreaming slowly from 3122'to clean up casing.650 gpm flowrate and 150 rpm.Sweep brought back a minor amount of clay and mushy cuttings but did not appear to unload hole.Circ additional bottoms up for cleanup. 03:00 04:30 1.50 2,932 2,932 INTRMI RIGMNT SLPC P PJSM-Slip and cut drilling line- Service top drive and drawworks 04:30 06:30 2.00 2,932 2,932 INTRMI RIGMNT RGRP T PJSM-Replace lower air swivel on top drive-function tested auto IBOP -valve working well 06:30 12:45 6.25 2,932 10,403 INTRM1 DRILL TRIP P RIH from 2,932'to 10,403'-filled pipe every 20 stands-obtained survey @ 9,156' Wiped tight spots when loss of 15K SOW occured at 9855', 10,000', 10,085'and 10,220' Page 11 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:45 14:30 1.75 10,403 10,497 INTRM1 DRILL CIRC P Staged pumps up to 650 gpm/2100 psi/11.1 ppg ECD-Precautionary wash and ream from 10,403'to 10,497'-Circulate and condition mud -performed 700 bbl Glydril whole mud dilution with 5%GLYDRIL,6 ppb Soltex,4 ppb Resinex,6 ppb Sack Black-increased mud wt.to 10.0 ppg 14:30 00:00 9.50 10,497 11,253 INTRMI DRILL DDRL P Drill ahead in 8 3/4"hole from 10497' to 11253'MD/6689'TVD. Footage drilled=756',ADT=5.84 hrs,Avg ROP=129 fph, ECD= 11.25 ppg,WOB=25/30 klbs, RPM =150 rpm,650/600 gpm @ 2330/2250 psi,String Wts: PUW= 265000 lbs,SOW=185000 lbs, ROT=218000 lbs,TQ ON/OFF BTM =17500/14000 ft lbs,Add 275 bbls Glydril mud slowly to system, Maintain MW at 10.0 ppg,THRZ= 10880'MD. BHRZ=11228'MD. 03/15/2011 Drill 8 3/4"hole and land well at int csg point-12754'MD/7007'TVD.CBU x2. Pump 11.8 ppg visc sweep surf-surf. Backream out to 10875'MD. 00:00 12:00 12.00 11,253 12,327 INTRMI DRILL DDRL P Continue drilling 8 3/4"hole from 11253'to 12327'MD/6951'TVD. Saw K-1 marker at 11395'MD/6732' ND. Tentative picks: Kup C sand at 11678'MD. LCU at 11707'MD. Started seeing drop trend in hole angle at 11520'. Footage= 1074' ADT=8.02 hrs Avg ROP=134 fph ECD=11.1 ppg WOB=30000 lbs RPM= 150 rpm 650 gpm @ 2610 psi String Wts: POW=290 klbs SOW=177 klbs ROT=225 klbs TQ ON/OFF=20000/16000 ft lbs Page 12 of 39 Time Logs Date From To Dur S.Death E. Death Phase Code Subcode T Comment 12:00 16:15 4.25 12,327 12,754 INTRM1 DRILL DDRL P Drill 8 3/4"hole from 12327'to TD at 12754'MD/7007'TVD. Hole angle at TD=85.2 deg ABI. Footage=427' ADT=3.29 hrs AVG ROP= 130 fph. ECD=11.14 ppg WOB=30000 lbs RPM= 150 rpm 650 gpm @ 2600 psi String Wts: PUW=292 klbs SOW= 176 klbs. ROT=225 klbs. TQ ON/OFF BTM=20000/16000 ft lbs. 16:15 16:30 0.25 12,754 12,754 INTRMI DRILL CIRC P Get SPR's&flow check well-static. 16:30 18:30 2.00 12,754 12,576 INTRMI DRILL CIRC P CBU X2.650 gpm @ 2550 psi. Rack back 1 stand every 45 min to 12576'. 18:30 22:00 3.50 12,754 12,754 INTRMI DRILL CIRC P Circ 11.8 ppg hi-vis sweep around surf>>surf-650 gpm @ 2550 psi once in annulus. Sweep did not bring back a significant increase in cuttings from well. 22:00 00:00 2.00 12,754 10,875 INTRM1 DRILL REAM P Flow check well-static.Start backreaming out of hole-600 gpm @ 2100 psi to 10875'MD. No problems. No indication of packing off,excessive torque(18 kft lbs)or excessive cuttings coming back. Hole appears to be in good condition. 03/16/2011 Continue backreaming OOH to 10590'MD w/o problems.CBU. RIH to btm w/o problems.Circ and weight up mud to 10.5 ppg. Pull/backream out of hole from 12754'to surface to run 7"casing. Download MWD data. 00:00 00:15 0.25 10,875 10,686 INTRM1 DRILL REAM P Finish backreaming out of hole to 10686'MD(-200'above THRZ). 00:15 01:00 0.75 10,686 10,686 INTRM1 DRILL CIRC P CBU at 650 gpm and 150 rpm while working one additional stand. 01:00 01:15 0.25 10,686 10,686 INTRMI DRILL OWFF P Blow down top drive and flow check well-static. 01:15 02:30 1.25 10,686 12,754 INTRMI DRILL TRIP P RIH from 10686'to TD at 45-60 fpm. No tight spots or obstructions. Max set down weight no more than 10 klbs. No circulating or reaming required. SOW=175 klbs. PUW=270 klbs. Hole in good condition. 02:30 05:00 2.50 12,754 12,754 INTRMI DRILL CIRC P Circ at 600-650 gpm and raise MW from 10.0 to 10.5 ppg. 05:00 08:30 3.50 12,754 10,591 INTRM1 DRILL TRIP P Spot casing running pill in drill pipe- POOH spotting pill f/12,754'to 10,591'-pumping @ 3 bbls/min- pulling 1800 ft/hr. 08:30 08:45 0.25 10,591 10,591 INTRM1 DRILL OWFF P Blow down TD-Monitor well-Well static Page 13 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:45 10:00 1.25 10,591 9,173 INTRM1 DRILL TRIP P POOH on elevators f/10,591'to 9173'-good hole fill-no tight spots 10:00 10:30 0.50 9,173 9,173 INTRM1 DRILL CIRC P Flow ck.(static)-Blow down TD 10:30 12:00 1.50 9,173 8,606 INTRMI DRILL TRIP P Cont. POOH on elevators f/9173'to 8606'-Good hole fill&no tight spots -attempt to pull f/8606'-tight spots @ 8580'-8550'&8517'-pulling 60 over @ 8517'-RIH to 8606' 12:00 12:30 0.50 8,606 8,417 INTRM1 DRILL REAM T Backream f/8606'to 8511'@ 600 gpm @2100 psi w/120 rpm-RIH to 8606'-Pulled back to 8511'-w/no pump-no rotary-Pulled f/8511'to 8417'-no pump-no rotary OK 12:30 14:15 1.75 8,417 5,769 INTRMI DRILL TRIP P Cont. POOH on elevators f/8417'to 5732' -tight hole @ 5732'-RIH to 5769' 14:15 15:00 0.75 5,769 5,675 INTRM1 DRILL REAM T Backream f/5769'to 5675'@ 600 gpm 1720 psi w/120 rpm-Circ btms up while backreaming-Observed excessive amount of cuttings @ shakers. 15:00 15:30 0.50 5,675 5,391 INTRM1 DRILL TRIP P Cont. POOH on elevators f/5675'to 5327'-Tight hole @ 5327'-RIH to 5391' 15:30 17:30 2.00 5,391 4,918 INTRM1 DRILL REAM T Backream f/5391'to 4823'MD. 600 gpm @ 1750 psi. 120 rpm at 10 kftlbs torque. 17:30 17:45 0.25 4,918 4,918 INTRMI DRILL OWFF P Flow check well-static. 17:45 19:30 1.75 4,918 2,838 INTRMI DRILL TRIP P pOH on elevators from 4823'to 9 l 5/8"casing shoe. Work thru and clean up tight spots at 4210'(std#26)and 3790'(std#22). Minor tight spot at—3745'(std#21)- pulled thru on first attempt with 30 klbs overpull. Pull in to csg shoe. 19:30 20:15 0.75 2,838 2,838 INTRM1 DRILL CIRC P CBU 600 gpm @ 1650 psi and 100 III rpm rotary inside casing shoe.Circ out a moderate amount of clay from btms up. 20:15 21:30 1.25 2,838 104 INTRM1 DRILL TRIP P POH to MWD/LWD tools. 21:30 00:00 2.50 104 104 INTRMI DRILL PULD P PJSM for removing nuclear source. Remove sources. Download MWD tools. LD BHA. 03/17/2011 LD BHA#2. Install&test 7"casing rams. RU casing equp't. PJSM. Run 7"casing per running detail.Circ at shoe and continue CBU every 2000'while running casing in open hole to 9488'MD. 00:00 02:00 2.00 104 0 INTRM1 CASING PULD P Continue downloading MWD data. LD BHA#2. Dull bit grade: 1-1-CT-N-X-I-ER-TD. 02:00 02:30 0.50 0 0 INTRM1 CASING PULD P Clear&clean rig floor. 02:30 03:45 1.25 0 0 INTRM1 CASING NUND P Pull wear bushing. Install 7"casing rams in top cavity. Page 14 of 39 Time Logs Date From To Dur S.Death E.Depth Phase Code Subcode T Comment 03:45 04:15 0.50 0 0 INTRM1 CASING BOPE P Test casing rams to 250/3500 psi-5 min ea test. 04:15 04:45 0.50 0 0 INTRMI CASING NUND P Install thin walled wear bushing for running casing 04:45 06:15 1.50 0 0 INTRM1 CASING RURD P Rig up to run 7"casing 06:15 06:30 0.25 0 0 INTRMI CASING SFTY P Pre job meeting on running 7"casing -Discussed casing tong incident with crew(tong used in incident not the type used here). 06:30 11:00 4.50 0 2,930 INTRMI CASING RNCS P Ran 7"26#L-80 BTC-Mod casing as follows: Ray Oil Tools(silver bullet) float shoe-2 jts casing-Halliburton float collar(Super seal II w/baffle adapoter installed) 1 jt.casing- Halliburton baffle collar-1 jt.casing to 168'(4 jts total)shoe track made up w/BakerLoc-stabbed into jt#4 w/fill up tool-fill pipe&circ to checks floats(OK)-Continue to RIH w/7"26#L-80 BTC-Mod.casing to 2930'(71 jts total in hole)Installed 1 Hydroform centralizer on jt#1 &1 Ray Oil Tools 7"x 8 3/8"straight blade centralizer on jts.#2 thru#30 (as per well plan) 11:00 11:30 0.50 2,930 2,930 INTRM1 CASING CIRC P Establish circulation&circulate casing volume staging pump up to 6 bbls/min @ 240 psi 11:30 13:45 2.25 2,930 4,948 INTRM1 CASING RNCS P Continue to RIH w/7"casing f/2930' to 4948'(120 jts.total in hole) 13:45 14:45 1.00 4,948 4,948 INTRM1 CASING CIRC P Establish circulation&circulate btms up while staging pump up to 6 bbls/min @ 270 psi. 14:45 18:00 3.25 4,948 7,011 INTRM1 CASING RNCS P Continue to RIH w/7"casing f/4948' to 7011'(170 jts total in hole). Installed Halliburton ES cementer on top of jt#144(BakerLoc connections). Installed Ray Oil Tools 7"x 8 3/8" straight blade centralizers one per jt f/jt#145 to#170-free floating. 18:00 19:00 1.00 7,011 7,011 INTRMI CASING CIRC P Break circ&stage pumps up to 6 bpm @ 400 psi.CBU x1.5. MW In= 10.5 ppg. MW Out=10.5+ppg. 19:00 21:30 2.50 7,011 9,077 INTRM1 CASING RNCS P Continue running 7"casing to 9077' MD(220 jts). Install straight blade centralizers on jts 171-173 free floating. 21:30 23:00 1.50 9,077 9,077 INTRM1 CASING CIRC P Break circ&stage pumps up to 6 bpm @ 475 psi. CBU x1.75. MW in=10.5 ppg.MW out= 10.6 ppg. 23:00 00:00 1.00 9,077 9,488 INTRMI CASING RNCS P Continue running 7"casing to 9488' MD(230 jts). Page 15 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/18/2011 24 hr Summary Continue running 7"casing to 11394. No further progress. LR 1 jt and attempt to circ-packed off. Work pipe down to 11475.Work pipe free. Prepare to pull casing. LD 26 jts casing from 11475 to 10398' MD(Jt#252). Break circ and CBU. 00:00 01:45 1.75 9,488 10,731 INTRM1 CASING RNCS P Continue to RIH w/7"casing f/9488' to 10,731'MD(260 jts total in hole) 146'above top of HRZ 01:45 03:30 1.75 10,731 10,731 INTRM1 CASING CIRC P Break circ and stage pump up to 6 bpm @ 540 psi.-Circ btms up+ mud wt. in 10.5 ppg-Mud wt. out 10.6 ppg- PU wt.305 k SO wt 165- after circ-PU wt.260 SO wt 165 03:30 05:00 1.50 10,731 11,394 INTRM1 CASING RNCS P Continue to RIH w/7"casing f/ 10,731'to 11,394'(276 jts total in hole) String started taking weight @ 11,368'-slack off wt.went f/150 k to 125 k @ 11,394' 05:00 07:00 2.00 11,394 11,475 INTRM1 CASING RNCS T Attempt to circ-Packed-off-Pulled back to 11,353'(laid down jt#276) Working stuck pipe pulling up to 405 k&attempting to circ-hole kept packing off-Worked pipe free 300 k up 170 k down-Attempted to circ- regained circ for very short time @ 2.2 bbls/min @ 420 psi-hole continuing to pack-off-working tight hole pulling up to 450 k-Attempted to RIH&work pipe down-work pipe down to 11,475'(278 jts total in hole) unable to work past 11,475'- Attempt to work pipe back out of hole-pulling up to 485 k unable to work up past 11,455' 07:00 08:30 1.50 11,475 11,353 INTRM1 CASING RNCS T Work pipe free and come up hole to 11353'MD. Continue working pipe attempting to POH up to 450 klbs. 08:30 12:00 3.50 11,353 11,475 INTRM1 CASING RNCS T Work pipe back down to 11475'. Pipe became stuck at 11475'. 12:00 18:30 6.50 11,475 11,475 INTRM1 CASING PULL T Work stuck pipe at 11475'MD. , Finally able to work pipe free and get pipe movement. 18:30 23:15 4.75 11,475 11,435 INTRM1 CASING PULL T Pull&LD jt#278 from 11475'to 11435'. Pipe started pulling with normal up wt(-325 klbs). Continue pulling and LD casing jts #277-253 up to shoe depth—10390' MD. No excessive overpulls noted and hole taking fluid when pulling. 23:15 00:00 0.75 11,435 11,435 INTRM1 CASING CIRC T Establish circulation at 1 bpm. Stage pumps up to 3 bpm at 530 psi. PUW=275 klbs.SOW= 165 klbs with pumps on. Page 16 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/19/2011 24 hr Summary Circ&cond mud-MW in= 10.5 ppg.MW out=10.6 ppg.Continue POH laying down 7"casing to 9 5/8" shoe.Circ and pump dry job. 00:00 03:00 3.00 10,398 10,398 INTRMI CASING CIRC T Circ and cond mud. Stage pump up to 4.5 bpm @ 550 psi.Circ to get MW out down to 10.6 ppg. MW out varying from 10.7 to 10.9 ppg when circulating. 03:00 12:00 9.00 10,398 7,340 INTRMI CASING PULL T Continue pulling and laying down 7" casing. LD 101 jts at 12:00 hrs of 279 jts run. 178 jts still in hole. 12:00 22:15 10.25 7,340 2,887 INTRMI CASING PULL T Continue pulling and laying down 7" casing until up above 9 5/8"casing shoe. 209 jts laid down so far. 22:15 00:00 1.75 2,887 2,887 INTRM1 CASING CIRC T Break circ.Stage pumps up to 4.5 bpm. Clean rig floor. Pump dry job. Blow down top drive. 03/20/2011 Finish LD 7"casing.Clear floor. Install 3.5 x 6"VBR's in top cavity and test to 250/3500 psi.MU 3.5" cementing stinger and RIH on 5"DP.CBU at 9 5/8"shoe.Cut drlg line. RIH to 8856'.Circ and even out mud weight in pipe and annulus. RIH to 9500'. 00:00 02:00 2.00 2,887 2,887 INTRM1 CASING RURD T Change bails,elevators,slips and casing tongs. RD Franks fill-up tool. Held prejob meeting on change of scope for laying down remaining 7" casing 02:00 08:15 6.25 2,887 0 INTRM1 CASING PULL T Continue to pull&LD 7"casing f/ 2887'(278 jts total laid down)(Used torch to heat BakerLoc'ed connections of shoe track) 08:15 08:45 0.50 0 0 INTRM1 CASING RURD T RD casing equipment-Clear rig floor -Observed well(static) 08:45 09:15 0.50 0 0 INTRMI WHDBO OTHR T Drain stack-pull thin wall wear bushing 09:15 09:30 0.25 0 0 INTRMI WHDBO SFTY T Held PJSM on changing rams 09:30 10:15 0.75 0 0 INTRM1 WHDBO NUND T Change top rams f/7"solid body to 3 1/2"x 6"VBR 10:15 12:00 1.75 0 0 INTRM1 WHDBO BOPE T Set test plug w/5"test jt.-Test top rams to 250&3500 psi-Change test joints f/5"to 3 1/2" &test to 250&3500 psi-Pull test plug-set wear bushing 12:00 12:15 0.25 0 0 INTRM1 CEMEN"SFTY T PJSM on rigging up&running 3 1/2" tbg for cement job 12:15 13:30 1.25 0 918 INTRM1 CEMEN"PUTB T MU 3 1/2"mule shoe&29 jts(3 1/2" 9.3#EUE tbg)&XO's-Total BHA 918.90' 13:30 13:45 0.25 918 918 INTRMI CEMEN"RURD T RD tbg tongs&elevators 13:45 15:15 1.50 918 2,899 INTRMI CEMEN"TRIP T RIH w/3 1/2"cementing stringer on 5"DP f/918'to 2899' 15:15 15:45 0.50 2,899 2,899 INTRMI CEMEN"CIRC T CBU at 9 5/8"casing shoe. Page 17 of 39 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 15:45 17:15 1.50 2,899 2,899 INTRMI RIGMNISLPC T Slip&cut drilling line. Service top drive. 17:15 22:00 4.75 2,899 8,900 INTRM1 CEMEN-TRIP T Run in to open hole with cement stinger to 8900'. Fluid out of balance and flowing over top of DP when RIH. 22:00 23:00 1.00 8,900 8,900 INTRMI CEMEN"CIRC T Circ 6 bpm @ 400 psi to balance mud columns. Blow down top drive. 23:00 00:00 1.00 8,900 9,500 INTRMI CEMEN-TRIPT Continue RIH with stinger to—9500'. 03/21/2011 Pump 15.8 ppg cement isolation plug from 10808'to—10400'MD followed by 17.0 ppg kick-off plug from 7721' to 7350'MD. POH. LD cementing stinger. RU&test BOPE to 250/3500 psi. 00:00 00:30 0.50 9,500 10,808 INTRMI CEMEN'TRIP T RIH to 10808'with mule shoe and cement stinger on 5"DP. 00:30 03:15 2.75 10,808 10,808 INTRM1 CEMEN"CIRC T Break circ&stage pumps up to 9.5 bpm @ 700 psi. Circ and cond mud until MW in= MW out=10.5 ppg. 03:15 03:30 0.25 10,808 10,808 INTRMI CEMEN"RURD T Blow down top drive. RU cement hose and head pin on 5"DP. 03:30 04:15 0.75 10,808 10,808 INTRMI CEMEN"CMNT T Hold PJSM for pumping cement. W/3 1/2"tbg stringer set @ 10,808'- Set P&A plug f/10,808'to 10,400' as follows: Pump 2 bbls water and test lines to 3000 psi. Pump 26 bbls Mudpush at 11.5 ppg. Mix&pump 42 bbls(202 sx) 15.8 Class G w/0.2%BWOC DO46, 0.3%BWOC DO65,0.4%BWOC D167,0.110%BWOC B155- Intermediate tail Follow with 3.8 bbls 11.5 ppg Mudpush to balance. 04:15 04:45 0.50 10,808 10,808 INTRMI CEMEN'DISP T Displace cement w/10.5 ppg mud at 8 bpm/600 psi at 100 bbls away. Slow displacement to 5 bpm to 150 bbls away-390 psi. Slow to 3.5 bpm to finish displacement at 165 bbls away for balanced plug. Full circ throughout the job w/good pressure build-up as cmt was exiting the tbg tail 04:45 05:45 1.00 10,808 9,991 INTRM1 CEMEN-TRIPT POOH on TT f/10,808'to 9991'(9 stds)@ 1200 ft/hr.-PU wt 215 SO wt165 05:45 07:15 1.50 9,991 9,991 INTRM1 CEMEN"CIRC T Insert wiper ball into top of DP-Circ ball thru pipe @ 12 bbls/min @ 1040 psi&then circ btms up. Did not observe wiper ball back to surface. 07:15 09:15 2.00 9,991 8,100 INTRMI CEMEN'TRIP T Observed well(static)-POOH on TT f/9991'to 8100'(20 stds)PU wt. 190 SO wt 152 Page 18 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:15 10:15 1.00 8,100 7,721 INTRMI CEMEN-CIRCT Break circ&pump 30 bbls hi-vis gell pill-POOH spotting pill f/8100'to 7721'@ 3 bbls/min @ 320 psi 10:15 10:30 0.25 7,721 7,721 INTRM1 CEMEN"SFTY T PJSM on setting cement plug#2 10:30 11:30 1.00 7,721 7,721 INTRM1 CEMEN"PUCM T W/OE tbg stinger @ 7721'set kick off plug as follows: Pumped 2 bbls/ fresh water&tested lines to 3000 psi -Mixed&pumped 35 bbls Mudpush @ 11.5 ppg-Mixed&pumped 42 bbls(234 sxs)17.0 ppg Class G w/ 0.2%BWOC DO46, 1%BWOC DO46,0.2%BWOC D167-followed �/ by 5 bbls 11.5 ppg MudPush&1 bbl fresh water-Switched over to rig pumps&displaced cmt.w/111 bbls 10.5 ppg LSND mud @ 7 bbls/min @ 250 to 650 psi(final pressure-Full circulation throughout job w/good pressure build up as cmt was exiting tbg tail-CIP @ 11:30 hrs. 11:30 12:30 1.00 7,721 6,965 INTRMI CEMEN'TRIP T POOH on TT f/7721'to 6965'(8 stds) 12:30 13:30 1.00 6,965 6,965 INTRM1 CEMEN"CIRC T Insert wiper ball into top of DP- Pumped ball through pipe @ 12 bbls/min @ 890 psi&then circ btms up-Blow down TD-Monitor well (static) Didn't observe ball back to surface 13:30 17:30 4.00 6,965 918 INTRM1 CEMEN"TRIP T POH to cementing stinger at 918'. 17:30 19:00 1.50 918 0 INTRMI CEMEN-PULD T RU handling equipment and LD 3 1/2"tubing stinger and mule shoe. 19:00 21:15 2.25 0 0 INTRMI WHDBO RURD T Clear&clean rig floor. Pull wear bushing. Clear annulus valves plugged with cuttings. 21:15 00:00 2.75 0 0 INTRM1 WHDBO BOPE T Install test plug. RU and test BOPE. Test to 250/3500 psi for 5 min ea test. Annular tested to 250/2500 psi. 03/22/2011 Continue to Test BOPE;Test Waived by AOGCC Inspector Chuck Scheeve-M/U BHA#4 and RIH t/2,899' MD-De-energize, Disconnect and Reposition High Line Power Cable-Continue to RIH t/6,965'MD-Wash I7 Down and Tag Cement @ 7,470'MD-Dress Cement U 7,500'MD-Time Drill t/7,515'MD Page 19 of 39 Time Logs Date From To Dur S.Depth E. Death Phase Code Subcode T Comment 00:00 06:45 6.75 0 0 INTRM1 WHDBO BOPE T Cont. BOP testing-Tested pipe rams,choke manifold valves,choke &kill line valves,4"Demco kill line valve,TD IBOP valves,floor safety& dart valves to 250&3500 psi w/5" test jt.-Performed accumulator recovery test-LD 5"test jt.Tested blind rams to 250&3500 psi-MU 4" test jt.Tested Hydril to 250&2500 psi-tested pipe rams to 250&3500 psi-LD 4"test jt.-Tested hydralic& manual chokes. Test gas alarms 06:45 07:30 0.75 0 0 INTRMI WHDBO BOPE T Blow down lines-Pull test plug- Install wear bushing 07:30 08:30 1.00 0 0 INTRM1 RIGMNT SVRG T Install EZ torque-Service&inspect TD 08:30 10:00 1.50 0 85 INTRMI DRILL PULD T MU BHA#4-Motor w/MWD 10:00 10:30 0.50 85 85 INTRM1 DRILL PULD T Upload MWD Data 10:30 11:15 0.75 85 269 INTRMI DRILL TRIP T RIH w/1 Stand of NMFDC's, 1 Stand HWDP and Shallow Test MWD 11:15 13:30 2.25 269 2,899 INTRM1 DRILL TRIP T P/U Jars and RIH w/BHA#3 on 5" DP t/2,899'MD *Note:Retested choke manifold valves#13 after being repaired OK 13:30 15:00 1.50 2,899 2,899 INTRM1 DRILL RURD T Monitor Well on TT While High Line Power Disconnected f/the Rig and the Spool was Relocated on the Pad 15:00 18:15 3.25 2,899 6,965 INTRM1 DRILL TRIP T RIH f/2,899'to 6,965'MD 18:15 20:15 2.00 6,965 7,500 INTRMI DRILL WASH T Wash Down f/6,965'to 7,470'MD C)�j (TOC)@ 500 GPM w/1740 Psi and 30 RPM-Polish Cement Plug t/ 7,500'MD 20:15 20:45 0.50 7,500 7,500 INTRM1 DRILL CIRC T CBU @ 550 GPM w/1900 Psi 20:45 00:00 3.25 7,500 7,515 INTRM1 DRILL DDRL T Time Drill f/7,500 to 7,515'MD(1/10 FPM) ADT 3.36 P/U 190,S/0 140, Rot 153 51 1 Torque On/Off 10/8 WOB 0-10; RPM 60 550 GPM @ 1940 Psi 03/23/2011 Drill 8%"hole w/motor f/7515'to 9,329'MD Page 20 of 39 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 00:00 12:00 12.00 7,515 8,383 INTRMI DRILL DDRL T Drilled 8 3/4"hole w/motor f/7515' to 8383'MD 5221'TVD ADT 7.12 hrs=ART-5.64 hrs AST-1.48 hrs ECD-11.07 ppg Footage-868' WOB 18/20 k RPM 90 GPM 650 @ 2440 psi String wt. PU 224 SO 160 Rot 184 Torque on/off btm.-16/14 k 12:00 00:00 12.00 8,383 9,329 INTRM1 DRILL DDRL T Drilled 8'/:'Hole w/1.5° Bent Motor f/8,383'to 9,329'MD ADT 6.3,ART 3.74,AST 2.56 P/U 260,S/O 165, Rot 204 Torque On/Off 18/17 WOB 10-20; RPM 90 650 GPM @ 2560 Psi; ECD 10.76 SPR's @ 8,950'MD MPI:30-350, 40-420/MP2 30-350,40-410 03/24/2011 Drilled 8 9/e"Hole w/Motor f/9,329'to 9,991'MD-CBU-OWFF(Static)-Perform Wiper Trip f/9,991'to 7,059' MD;Worked Through Tight Spots f/9,328'to 9,234'MD-OWFF(Static)-RIH f/7,059'to 9,139'MD- Precautionary Ream f/9,139'to 9,328'MD-RIH 1/9,900'MD-Circulate While Swapping Mud System f/9.6 PPG LSND to 10.5 PPG LSND w/Glydrill-Take SPR's and Continue to Drill f/9,991'to 10,325'MD 00:00 10:15 10.25 9,329 9,991 INTRM1 DRILL DDRL T Drilled 8 3/4"hole w/motor f/9329' to 9991'MD 6210'TVD ADT-5.71 hrs.=ART-2.09 hrs. AST-3.62 hrs. ECD-11.54 ppg Footage-662' WOB 18/20 k RPM 90 GPM 635 @ 2550 psi String wt. PU 275 SO 173 Rot 210 Torque on/off btm.-19.5/19 K ft/lbs. 10:15 12:00 1.75 9,991 9,991 INTRM1 DRILL CIRC T Circ&cond. hole for short trip @ 650 gpm @ 2300 psi w/90 rpm's-19 k torque 12:00 14:30 2.50 9,991 7,059 INTRMI DRILL WPRT T Blow down TD-Flow ck-well static -Wiper trip f/9991/to 7059'(pulled on elevators)hole took proper fill- worked through some tight spots f/ 9328'to 9234' 14:30 14:45 0.25 7,059 7,059 INTRM1 DRILL OWFF T OWFF(Static) 14:45 16:15 1.50 7,059 9,139 INTRM1 DRILL TRIP T RIH f/7,059'to 9,139'MD on Elevators 16:15 17:15 1.00 9,139 9,328 INTRM1 DRILL REAM T Ream Tight Spot f/9,139 to 9,328' MD-650 GPM w/2250 Psi and 50 RPM 17:15 17:45 0.50 9,328 9,900 INTRM1 DRILL TRIP T RIH f/9,328'to 9,900'MD on Elevators 17:45 21:00 3.25 9,900 9,991 INTRMI DRILL CIRC T Circulate While Changing Mud System f/9.6 PPG LSND to 10.5 PPG LSND w/Glydrill-625 GPM w/ 2400 Psi-RIH U 9,991'MD Page 21 of 39 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 00:00 3.00 9,991 10,325 INTRMI DRILL DDRL T Drill 8%"Hole f/9,991'to 10,325' MD ADT 2.95,ART 1.14,AST 1.81 P/U 255,S/O 178, Rot 215 Torque On/Off 16/14 WOB 25; RPM 90 615 GPM @ 2800 Psi SPR's @ 9,960'MD(w/New Mud); MP1 30-250,40-350/MP2 30-260, 40-350 03/25/2011 Drilled 8%:"Hole w/Motor f/10,325'to 11,504'MD(6,994'TVD);TD-CBU X2;Shakers Cleaned Up After First B/U-Pumped Weighted,Viscosified Nut Plug Sweep Around w/Modest Increase in Cuttings(Appeared to be Mostly Silt w/Shale Pieces)-After Sweep Cuttings Increased Significantly;Still Mostly Sand Sized Particles w/Pencil Lead Sized Pieces of Shale 00:00 12:00 12.00 10,325 11,077 INTRM1 DRILL DDRL T Drilled 8 3/4"hole w/motor f/10,325' to 11077'MD 6831'TVD ECD-11.58 ppg Footage-752' ADT-7.60 hrs. =ART-6.81 hrs AST-.79 hrs. WOB 15/20 k RPM 90 GPM 605 @ 2680 psi String wt. PU 272 SO 178 ROT 220 Torque on/off btm.-18/14.5 k 12:00 21:15 9.25 11,077 11,504 INTRM1 DRILL DDRL T Drill 8'/a"w/Motor f/11,077'to 11.504'MD(TD):6.994'TVD-Note. Final 2 Survey Points Show Dog Legs of 7.8 and 9.8 ADT 4.78,AST 4.21,ART.57 V/ P/U 290,S/O 180, Rot 224 Torque On/Off 18/17.5 RPM 30 WOB 15/25 615 GPM w/2880 Psi 21:15 00:00 2.75 11,504 11,504 INTRMI CASING CIRC T CBU X2;Shakers Cleaned Up After First B/U-Pumped 11.8 PPG Viscosified Nut Plug Sweep Around w/Modest Increase(30%)in Cuttings(Appeared to be Mostly Silt w/Shale Pieces)-After Sweep Cuttings Increased Significantly (50%),Still Mostly Sand Sized Particles w/Pencil Lead Sized Pieces of Shale-NOTE:Sweep Came Back 100 Bbls Late 615 GPM @ 2780 Psi and 50-90 RPM 03/26/2011 Continue to CBU-OWFF(Static)-POOH t/10,671'MD(Pulled 30 Over)-RIH t/11,409'MD-CBU-POOH V 10,463'MD-OWFF(Static)-CBU X2-RIH V 11,409';Wash V 11,503'MD-Circulate While Increasing MW f/10.5 to 11.5 PPG-OWFF(Static)-Spot Well Bore Strengthening and Casing Running Pills f/11,503' to 10,463'MD-OWFF(Static)-POOH U 2,899'MD-OWFF(Static)-CBU X2-POOH V 739'MD-OWFF (Static)-S/B HWDP and NMFDC's V 176'MD Page 22 of 39 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 00:00 01:00 1.00 11,504 11,314 INTRMI DRILL CIRC T Continue to CBU @ 625 gpm @ 2770 psi w/50 rpm's-16 k torque- Standing Back 1 Stand Every 1/2 Hour t/11,314'MD 01:00 01:15 0.25 11,314 11,314 INTRMI DRILL OWFF T OWFF(Static)-POOH to Check Swab(Not Swabbing) 01:15 02:00 0.75 11,314 10,671 INTRM1 DRILL TRIP T Attempt to POOH to Top of HRZ- Pulled Into Tight Spot @ 10,671'MD; Pulled 30K Over 02:00 02:30 0.50 10,671 11,409 INTRM1 DRILL TRIP T RIH t/11,409'MD 02:30 03:45 1.25 11,409 11,409 INTRMI DRILL CIRC T CBU;625 GPM @ 2820 Psi w/50 RPM 03:45 05:00 1.25 11,409 10,463 INTRM1 DRILL TRIP T POOH on Elevators f/11,409'to 10,463'MD; No Tight Spots Observed 05:00 06:30 1.50 10,463 10,463 INTRM1 DRILL CIRC T CBU X2;@ 625 gpm @ 2700 psi w/ 50 rpm's-14.5 k torque-stood back 1 std DP to 10,369' 06:30 07:15 0.75 10,463 11,503 INTRM1 DRILL TRIP T RIH f/10,369'to 11,409'-Wash down f/11,409'to 11,503'@ 600 gpm @ 2630 psi w/50 rpm's-15 k torque-hole in good condition- observed no tight hole running in 07:15 11:00 3.75 11,503 11,503 INTRMI DRILL CIRC T Circ&wt up f/10.5 ppg to 11.5 ppg @ 600 gpm @ 2980 psi(No rotation) 11:00 11:15 0.25 11,503 11,503 INTRM1 DRILL OWFF T Monitor well(static) 11:15 12:00 0.75 11,503 11,503 INTRM1 DRILL CIRC T Spot WBS&CR pills to bit @ 336 gpm @ 1260 psi 12:00 13:00 1.00 11,503 10,463 INTRM1 DRILL TRIP T POOOH spotting WBS&CR pills @ 3 bbls/min @ 300 psi f/11,503'to 10,463'(No rotation 13:00 21:00 8.00 10,463 2,899 INTRM1 DRILL TRIP T Flow ck well(static)-Blow down TD -Pull up 30'fluid level dropping- POOH on elevators f/10,463'to 2,899'MD 21:00 21:30 0.50 2,899 2,899 INTRM1 DRILL CIRC T OWFF(Fluid Falling)-CBU X2 @ 600 GPM w/1600 Psi and 30 RPM 21:30 23:00 1.50 2,899 729 INTRMI DRILL TRIP T Continue to POOH on TT t/729'MD 23:00 00:00 1.00 729 176 INTRM1 DRILL PULD T Stand Back HWDP and NMFDC's- UD Jars t/176 03/27/2011 Continue to UD BHA#3-Change Upper Rams t/7"and Test t/250/3500 Psi-R/U and Run 7"Casing U 9,081'MD(220 of 278 Jts in Hole);Circulate as Planned @ 2,884',4,945'and 7,011'MD 00:00 00:30 0.50 176 176 INTRM1 DRILL PULD T Download MWD Data 00:30 01:45 1.25 176 0 INTRM1 DRILL PULD T UD Remaining BHA#3 Items 01:45 02:15 0.50 0 0 INTRM1 DRILL RURD T OWFF(Static)-Clean&Clear the Rig Floor 02:15 02:30 0.25 0 0 INTRM1 WHDBO SFTY T PJSM on Changing Upper Rams 02:30 03:45 1.25 0 0 INTRM1 WHDBO NUND T Change Upper Rams f/5"to 7"Solid Body Rams 03:45 04:15 0.50 0 0 INTRM1 WHDBO NUND T Pull Wear Ring&Install Test Plug 04:15 04:30 0.25 0 0 INTRMI WHDBO BOPE T Test Upper Rams w/7"Test Joint U 250/3500 Psi Page 23 of 39 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 04:30 04:45 0.25 0 0 INTRM1 WHDBO NUND T Remove Test Plug&Install Wear Ring 04:45 06:45 2.00 0 0 INTRM1 CASING RURD T R/U to Run 7"Casing; P/U Casing Slips, Bales, and Elevators,M/U Franks Fill-Up Tool 06:45 07:00 0.25 0 0 INTRMI CASING SFTY T PJSM on Running 7"Casing 07:00 11:45 4.75 0 2,884 INTRMI CASING RNCS T Ran 7"26#L-80 BTC Mod.casing as follows: Float shoe(Ray Oil Tools Sliver bullet)2 jts casing-float collar (Halliburton Super Seal II-w/baffle adaptor installed))-1 jt casing- Baffle collar(Halliburton)1 jt.casing (shoe track made up w/BakerLoc- Stabbed into jt#4 w/fill up tool- filled pipe&circ to check floats) Cont.to RIH w/7"26#L-80 BTC casing f/165'to 2884'(70 jts in hole) Installed 1 Hydroform centralizer on shoe jt&then 80'f/shoe on jt#3- Installed 1 Hydroform per jt f/#4 to# 70 11:45 12:15 0.50 2,884 2,884 INTRMI CASING CIRC T Establish circ&circ casing volume- staging pump up to 6 bbls/min @ 280 psi 12:15 15:30 3.25 2,884 4,945 INTRMI CASING RNCS T Cont. RIH w/7"26#L-80 BTC-Mod casing f/2884'to 4945'(120 jts) Installed Halliburton ES cementer at jt#113- Ran 1 Hydroform centralizer per jt.f/ #71 to#120 15:30 16:15 0.75 4,945 4,945 INTRM1 CASING CIRC T Establish circ-Circ&condition mud -staging pump up to 5 bbls/min @ 380 psi 16:15 19:30 3.25 4,945 7,011 INTRM1 CASING RNCS T Cont. RIH w/7"26#L-80 BTC-Mod casing f/4945'to 7,011'MD(170 JTs in Hole) P/U 210,S/0 145 19:30 20:45 1.25 7,011 7,011 INTRMI CASING CIRC T CBU Staging Pumps Up to 5 BPM w/520 Psi 20:45 00:00 3.25 7,011 9,087 INTRMI CASING RNCS T Continue to Run 7"Casing f/7,011' to 9,087'MD(220 Joints in Hole) P/U 255,S/O 150 03/28/2011 Finish running 7"casing-Circ&cond.for cmt iob-Cemented 7"casing 1st&2nd stages-RD lines&cmt head-LD landing jt.set&test pack-off-Change top oipe rams&test-LD 5"DP 00:00 01:15 1.25 9,087 9,087 INTRMI CASING CIRC T Circulate and Condition Mud 9087' Staging Pumps up to 5 BPM @ 570 Psi 01:15 06:00 4.75 9,087 10,298 INTRMI CASING RNCS T Continue to Run 7"Casing t/10,298' MD(250 jts total in hole) 06:00 08:45 2.75 10,298 10,298 INTRM1 CASING CIRC T Circulate and Condition Mud Staging Pumps up t/5 BPM @ 615 Psi Final Circulation Above HRZ(Top of HRZ 10,520'MD) Page 24 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:45 10:15 1.50 10,298 11,487 INTRMI CASING RNCS T Cont. RIH w/7"26#L-80 BTC-Mod. casing f/10,298'to 11,450'(278 jts total)PU landing jt w/FMC fluted hanger-Landed casing in wellhead on fluted hanger w/float shoe to 11,487'-FC @ 11,404'-Baffle collar @ 11,364'-stage collar @ 6830'- RIH f/top of HRZ to TD with no problems-SO wt. 160 to 165 k 10:15 10:45 0.50 11,487 11,487 INTRM1 CEMEN"RURD P RD fill up tool-Blow down TD-MU cmt head &lines 10:45 12:00 1.25 11,487 11,487 INTRMI CEMEN"CIRC P Break circ-circ&condition mud for cement job-staging pump up to 5 bbls/min @ 720 psi 12:00 14:30 2.50 11,487 11,487 INTRMI CEMEN"CMNT P Held PJSM on cement job- CY Cemented 1st stage of 7"casing as follows: Pumped 5 bbls CW-100- L 1 y itf Tested lines to 3700 psi-Pumped 25 bbls CW-100 @ 4.3 bbls/min @ 600 psi-Mixed&pumped 25 bbls 12.5 ppg MudPush-Dropped bottom plug-Pumped 5 bbls 12.5 ppg MudPush-Loaded top plug-Mixed &pumped 42 bbls tail slurry(Class G w/0.2% D46,0.3%D65,0.11%6155,0.4%D167 @ 15.8 ppg @ 4.5 bbls/min @ 600 psi-Dropped topplug w/20 bbls water f/Dowell-Switched over to rig pumps&displaced w/11.5 ppg LSND mud @ 6 bbls/min @ 800 psi for 395 bbls.slowed pump to 3.5 bbls for last 23.7 bbls-bumped plug w/ 1050 psi-bleed off pressure checked floats OK-CIP @ 14:20 hrs.-Loaded closing plug for 2nd stage-Pressured up to 3280 psi to open stage collar. Full circulation throughout job- Reciprocated pipe during job-PU wt. 280 SO wt 165 14:30 15:15 0.75 11,487 11,487 INTRMI CEMEN"CIRC P Circ bottoms up f/6832'(stage collar)@ 6 bbls/min @ 480 psi Page 25 of 39 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 15:15 16:30 1.25 11,487 11,487 INTRM1 CEMEN"CMNT P PJSM on cement job-Cemented \ 2nd stage of 7"casing as follows: • Pumped 30 bbls CW-100 @ 4.5 Q67 bbls/min @ 380 psi-Mixed& pumped 30 bbls 12.5 ppg MudPush `4 @ 4.5 bbls/min @ 450 psi-Mixed& Sic" pumped 46 bbls tail slurrv(Class G w/02.%D46,0.3%D65,0.8%S2)@ 15.8 ppg @ 4.5 bbls/min @ 300 psi- Dropped closing plug w/20 bbls water f/Dowell-Swtiched to rig pumps @ displaced cement w/11.5 ppg LSND mud @ 6 bbls/min @ 450 psi for first 230 bbls-slowed pump to 3 bbls/min for last 11.7 bbls- Bumped plug pressured up to 1890 psi to close stage collar-Bleed off pressure to check stage collar- collar closed-CIP @ 16:30 hrs.- Full circulation throughout job 16:30 17:30 1.00 INTRM1 WHDBO PULD P Pull Wear Ring,Set 7"Pack Off Assembly 17:30 18:00 0.50 INTRM1 WHDBO PRTS P R/U and Test Pack-Off t/5,000 Psi for 10 Minutes 18:00 18:30 0.50 INTRMI CEMEN"RURD P Clean and Clear the Rig Floor 18:30 19:30 1.00 INTRM1 WHDBO SEQP P Change Saver Sub and Top Pipe Rams t/3'/z"by 6"Variable 19:30 21:00 1.50 INTRM1 WHDBO BOPE P Set Test Plug and Test Upper Rams t/250/3500 Psi f/5 Minutes-Pull Test Plug and Set the Wear Ring 21:00 21:15 0.25 INTRM1 CEMEN"RURD P R/U to UD 5"DP f/the Mouse Hole (23 Stands) 21:15 00:00 2.75 INTRM1 CEMEN"PULD P Lay down 5"drill pipe f/the derrick via the mousehole. 03/29/2011 Continue to LD 5"DP,service rig,con't LD 5"dp,clear floor, PJSM,slip and cut drilling line, PU/MU stand back 10 stands of 4"in derrick, PU BHA#5(cleanout assembly),single in the hole f/292'to 6777', RU then test 7"casing to 1000 psi f/10 min-good, RD testing equipment,make a connection,tag up on Halliburton cementer @ 6830',drill cementer, ream to 7254',blow down the top drive, RU then test casing to 3500 psi f/ 10 min-good. 00:00 04:30 4.50 INTRMI DRILL PULD P Continue to lay down 5"drill pipe f/ the derrick via the mousehole. 04:30 05:00 0.50 INTRMI RIGMNI SVRG P Service rig. 05:00 09:00 4.00 INTRM1 DRILL PULD P Continue to lay down 5"drill pipe f/ the derrick via the mousehole.Total of 97 stands of 5"drill pipe,4 stands of 5"HWDP,a stand of flex drill collars. • 09:00 09:30 0.50 INTRMI DRILL RURD P Clear floor,change elevators to 4", pick up 4"slips, PU a joint of 4"drill pipe, make a top drive connection. 09:30 09:45 0.25 INTRM1 DRILL SFTY P Pre job safety meeting on slip and cut of the drilling line. 09:45 12:00 2.25 INTRM1 RIGMNTSVRG P Slip and cut 120'of the 1-3/8"drilling line.Service the drawworks and grease the blocks. Page 26 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 12:30 0.50 INTRMI RIGMNTSVRG P Change dies in the iron roughneck to 4", rig up to pick up 4"drill pipe. Bring BHA components to the floor. 12:30 13:30 1.00 INTRM1 DRILL PULD P Pick up/make up 10 stands of 4" drillpipe,stand back in the derrick. Rabbit w/2.15"teflon rabbit. 13:30 14:15 0.75 0 292 INTRM1 DRILL PULD P Make up BHA#5 per the directional driller to 292'. 14:15 20:15 6.00 292 6,777 INTRMI DRILL TRIP P Single in the hole w/4"drill pipe on top of BHA#5 f/292'to 6777'. Rabbit w/2.15"teflon rabbit. 20:15 20:30 0.25 6,777 6,777 INTRM1 DRILL RURD P Rig up to test the 7"casing 20:30 20:45 0.25 6,777 6,777 INTRM1 DRILL PRTS P Test 7"casing prior to drilling Halliburton cementer @ 6829.76'. Test to 1000 psi f/10 min-good. 20:45 21:00 0.25 6,777 6,777 INTRMI DRILL RURD P Rig down testing equipment. Blow down lines. 21:00 23:00 2.00 6,777 7,254 INTRMI CEMEN"DRLG P Wash down and tag up on Halliburton cementer @ 6830'. Drill cementer and continue to ream down to 7254'. 23:00 23:15 0.25 7,254 7,254 INTRMI DRILL RURD P Rig up to test the 7"casing 23:15 23:30 0.25 7,254 7,254 INTRM1 DRILL PRTS P Test 7"casing after drilling '(v5 •� Halliburton cementer @ 6829.76'. Gy)' Test to 3500 psi f/10 min-good-lost 10 psi. 23:30 23:45 0.25 7,254 7,254 INTRM1 DRILL RURD P Rig down testing equipment. Blow down lines. 23:45 00:00 0.25 7,254 7,254 INTRM1 DRILL CIRC P Pump a dry job prior to POOH w/ BHA#5. 03/30/2011 POOH w/BHA#5, pick up/make/stand back 7 stands of 4"drill pipe,pull FMC wear bushing, RU to test BOPE.Witness of test waived by AOGCC inspector John Crisp. Fill stack w/water,work out air.Test BOPE w/4"test joint.Test annular to 250 psi low and 2500 psi high.Test everything else to 250 psi low and 3500 psi high. Hold each test 5 minutes,chart tests. Upper IBOP failed 3500 psi test.Worked valve,then retested OK.Tested all vales in the choke manifold, Kill line and choke line valves,demco valve on mud line,floor safety valve and IBOP.Tested accumulator.Service top drive and drawworks.Work on electric brake f/rig.Test blind rams 250 psi low and 3500 psi high.Test BOPE w/3-1/2"test joint.Test annular to 250 psi low and 2500 psi high.Test upper pipe and lower pipe rams to 250 psi low and 3500 psi high. Hold each test 5 minutes,chart tests. Rig down testing equipment. Blow down lines. Pull FMC test plug,install FMC wear bushing w/8"ID.Trouble shoot and work on dynamic brake and elmago brake. Pick up BHA#6: Hycalog 6-1/8"PDC MSF513D-B2C(ser#A141336),GeoPilot 5200, nm geoPilot flex collar, nm stab,4-3/4"Slim Phase 4 collar, DM collar,ALD collar,CTN collar, PWD,TM Pulsar, nm float sub and a crossover to XT39.Total length 116.79'. Pick up,then upload MWD tools. No communication w/PWD tool(ser#90271917). Lay down x-o,flaot sub,TM pulsar.Then break and lay down PWD(ser#90271917). Pick up new PWD tool,make up same,MU TM pulsar,flaot sub,and x-o to 116'. Pick up,then upload MWD tools. 00:00 03:00 3.00 7,254 101 INTRM1 DRILL TRIP P Pull out of the hole w/BHA#5 f/ 7254'to 101'. 03:00 03:30 0.50 101 0 INTRM1 DRILL TRIP P Change elvators to 3-1/2". Break bit, bit sub,and stabilizer.Stand back a stand of 4-3/4"nm flex collars. 03:30 03:45 0.25 INTRM1 DRILL RURD P Clean floor,change elevators back to 4". 03:45 04:15 0.50 INTRM1 DRILL 'PULD P Pick up/Make up/stand back in the derrick 7 stands of 4"drill pipe. Rabbit w/2.15"teflon rabbit. Page 27 of 39 Time Logs Date From To Dur S.Depth E. Death Phase Code Subcode T Comment 04:15 04:30 0.25 INTRM1 WHDBO OTHR P Pull FMC wear bushing. 04:30 05:30 1.00 INTRM1 WHDBO BOPE P Rig up to test BOPE. Fill stack and manifold with water.Work air out of system.Witness of test waived by AOGCC inspector John Crisp. 05:30 09:30 4.00 INTRM1 WHDBO BOPE P Test BOPE w/4"test joint.Test annular to 250 psi low and 2500 psi high.Test everything else to 250 psi low and 3500 psi high. Hold each test 5 minutes,chart tests. Upper IBOP failed 3500 psi test. Worked valve,then retested OK. Tested all vales in the choke manifold, Kill line and choke line valves,demco valve on mud line,floor safety valve and IBOP.Tested accumulator. 09:30 10:30 1.00 INTRM1 RIGMNTSVRG P Service rig,top drive and drawworks. 10:30 11:00 0.50 INTRM1 RIGMNT RGRP T Work on electric brake. 11:00 12:30 1.50 INTRM1 WHDBO BOPE P Test blind rams 250 psi low and 3500 psi high.Test BOPE w/3-1/2"test joint.Test annular to 250 psi low and 2500 psi high.Test upper pipe and lower pipe rams to 250 psi low and 3500 psi high. Hold each test 5 minutes,chart tests. 12:30 13:00 0.50 INTRMI WHDBO RURD P Rig down testing equipment. Blow V down lines. Pull FMC test plug, I install FMC wear bushing w/8"ID. 13:00 20:15 7.25 INTRMI RIGMNT RGRP T Trouble shoot and work on dynamic tSl brake and elmago brake. 20:15 21:30 1.25 0 116 INTRMI DRILL PULD P Pick up BHA#6: Hycalog 6-1/8" PDC MSF513D-B2C(ser# A141336),GeoPilot 5200, nm geoPilot flex collar,nm stab,4-3/4" Slim Phase 4 collar, DM collar,ALD collar,CTN collar, PWD,TM Pulsar, nm float sub and a crossover to XT39.Total length 116.79'. 21:30 22:30 1.00 116 116 INTRM1 DRILL OTHR P Pick up,then upload MWD tools. No communication w/PWD tool(ser# 90271917). 22:30 23:00 0.50 116 90 INTRMI DRILL PULD T Lay down x-o,flaot sub,TM pulsar. Then break and lay down PWD(ser #90271917) 23:00 23:15 0.25 90 116 INTRM1 DRILL PULD T Pick up new PWD tool,make up same,MU TM pulsar,flaot sub,and x-o to 116'. 23:15 00:00 0.75 116 116 INTRM1 DRILL PULD T Pick up,then upload MWD tools. Page 28 of 39 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 03/31/2011 24 hr Summary Shallow test MWD tools @ 116'. Pumping 206 gpm w/875 psi. Rotate 74 rpm w/3.3k ft lbs of torque. PU wt 77k,SO 77k, Rot 77k. Break in seals on GeoPilot. Blow down the top drive. PJSM, Load nuke sources.Con't w/BHA from derrick to 410'. RIH w/BHA#6 f/410'to 2313'. Single in the hole w/4"drill pipe. Rabbit drill pipe w/2.15"teflon rabbit. Fill pipe,obtain PU and SO wt's @ 2313'. Perform a function of the BOP test.Close top pipe rams(3-1/2"x 6"variables).Circulate through adjustable choke @ 2 bpm, required 6.8 bbls to see fluid at the bottom of the gas buster.While circulating at 2 bpm w/380 psi,then adjust choke until approx 1100 psi was observed on the drill pipe pressure(4/64th to 5/64th reading on choke panel guage); in the middle of the orange).Shut down,then line up on the manual choke. Pump 2 bpm, adjust choke until 870 psi observed on dp pressure(4/64th choke setting). Blow down the choke line,blow down the gas buster. RIH w/BHA#6 f/ 2313'to 4538'.Single in the hole w/4"drill pipe. Rabbit drill pipe w/2.15"teflon rabbit. Fill pipe every 20 stands,obtain PU&SO wt's every 20 stands.Service rig,con't in hole to 6796', precautionary ream through Halliburton cementer to 6892'-no problems,con't in hole to 11184', RU,then test 7"26 ppf L-80 casing to 3500 psi f/30 min(chart test), RD, ream f/11184'to 11323'(TOC),con't to ream to 11339',change mud over to new 9.6 ppg Flo-thru w/power vis, ream down f/11339'to baffle adapter @ 11363',drill wiper rubber and baffle,then cement to 11402', POOH stand back stand#116 to 11375',change out shaker motor on#2 shaker, make a connection-continue to drill shoe track f/11402'to 11487', rat hole to 11504',then 20'of new 6-1/8"hole to 11524'(6997'ND),circulate prior to performing Formation Integrity Test. 00:00 00:45 0.75 116 116 INTRM1 DRILL CIRC P Shallow test MWD tools @ 116'. Pumping 206 gpm w/875 psi. Rotate 74 rpm w/3.3k ft lbs of torque. PU wt 77k,SO 77k, Rot 77k. Break in seals on GeoPilot. Blow down the top drive. 00:45 01:00 0.25 116 116 INTRM1 DRILL SFTY P Pre job safety meeting on loading nuke sources. 01:00 01:15 0.25 116 116 INTRM1 DRILL PULD P Load nuke sources. 01:15 01:45 0.50 116 410 INTRM1 DRILL TRIP P Continue w/BHA from derrick to 410' 01:45 04:00 2.25 410 2,313 INTRMI DRILL TRIP P RIH w/BHA#6 f/410'to 2313'. Single in the hole w/4"drill pipe. Rabbit drill pipe w/2.15"teflon rabbit. 04:00 04:15 0.25 2,313 2,313 INTRMI DRILL CIRC P Fill pipe,obtain PU and SO wt's @ 2313'. PU wt 110k,SO wt 107k, Rot wt110k. 04:15 04:45 0.50 2,313 2,313 INTRMI WHDBO BOPE P Perform a function of the BOP test. Close top pipe rams(3-1/2"x 6" variables).Circulate through adjustable choke @ 2 bpm, required 6.8 bbls to see fluid at the bottom of the gas buster.While circulating at 2 bpm w/380 psi,then adjust choke until approx 1100 psi was observed on the drill pipe pressure(4/64th 5/64th reading on choke panel guage); in the middle of the orange). Shut down,then line up on the manual choke. Pump 2 bpm,adjust choke until 870 psi observed on dp pressure(4/64th choke setting). 04:45 05:00 0.25 2,313 2,313 INTRM1 WHDBO OTHR P Blow down the choke line,blow down the gas buster. 05:00 07:15 2.25 2,313 4,538 INTRMI DRILL TRIP P RIH w/BHA#6 f/2313'to 4538'. Single in the hole w/4"drill pipe. Rabbit drill pipe w/2.15"teflon rabbit. Fill pipe every 20 stands,obtain PU &SO wt's every 20 stands. @ 4221: PU wt 130k,SO wt 112k. Page 29 of 39 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 07:15 07:45 0.50 4,538 4,538 INTRM1 RIGMNT SVRG P Service rig. 07:45 09:30 1.75 4,538 6,796 INTRMI DRILL TRIP P RIH w/BHA#6 f/4538'to 6796'. Single in the hole w/4"drill pipe. Rabbit drill pipe w/2.15"teflon rabbit. Fill pipe every 20 stands, obtain PU &SO wt's every 20 stands. PU wt 163k,SO wt 123k. @ 6129': PU wt 152k, SO wt 120k, Rot wt 135k,torque 8k ft lbs. 09:30 09:45 0.25 6,796 6,892 INTRMI CEMEN"REAM P Make a top drive connection on a stand f/the derrick. Rotate down through the Halliburton ES cementer to 6892'. Rot wt 142k.Torque 9k ft lbs. Cementer tool @ 6830'. Note: Precautionary reaming; had observed a 10k overpull when pulling out of the hole w/cleanout assembly. 09:45 10:00 0.25 6,892 6,796 INTRM1 DRILL TRIP P POOH f/6892'to 6796',stand back a stand of 4"drill pipe in the derrick. 10:00 12:00 2.00 6,796 8,036 INTRM1 DRILL TRIP P RIH w/BHA#6 f/6796'to 8036'. Single in the hole w/4"drill pipe. Rabbit drill pipe w/2.15"teflon rabbit. Fill pipe every 20 stands,obtain PU &SO wt's every 20 stands. @ 8036': PU wt 183k,SO wt 129k, Rot wt 150k w/9.5k ft lbs of torque. 12:00 13:30 1.50 8,036 11,184 INTRM1 DRILL TRIP P RIH w/BHA#6 f/8036'to 11184'. Single in the hole w/4"drill pipe. Rabbit drill pipe w/2.15"teflon rabbit. Fill pipe every 20 stands,obtain PU &SO wt's every 20 stands. @ 10421': PU wt 230k,SO wt 135k. 13:30 14:00 0.50 11,184 11,184 INTRMI DRILL PRTS P Rig up to test 7"casing. Break circulation pumping 126 gpm w/1250 V/ psi. 14:00 14:45 0.75 11,184 11,184 INTRM1 DRILL PRTS P Test 7"26 ppf L-80 casing to 3500 psi f/30 minutes.Chart test. Plot on form. Note:Rig electricain tested gas alarms. 14:45 15:00 0.25 11,184 11,184 INTRMI DRILL PRTS P Rig down testing equipment. Blow down lines. 15:00 15:15 0.25 11,184 11,339 INTRMI CEMEN"REAM P Ream from 11184'to 11323'(top of cement).Continue to ream to 11339' while attempting to change mud out while drilling. Decision to change over prior to continuing to drill. Page 30 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:15 16:45 1.50 11,339 11,339 INTRMI CEMENCOCF P Change mud over to new 9.6 ppg Flow Thru w/Power vis. Pump a 40 bbl 9.8 ppg hi vis sweep,follow with new mud. Initial pumping 200 gpm w/ 2300 psi,final 220 gpm w/1880 psi. Note:With old mud: PU 240k,SO 140k, Rot 188k. Rot w/60 rpm w/ 13.5k ft lbs of torque off bottom.With new mud: PU wt 215k, SO wt 160k, Rot wt 185k. Rot w/30 rpm w/10k ft lbs of torque off bottom. 16:45 17:00 0.25 11,323 11,363 INTRMI CEMEN"COCF P Reaming down f/11339'to the baffle adapter @ 11363.82'. 17:00 19:15 2.25 11,363 11,402 INTRM1 CEMEN"DRLG P Drill Baffle adapter wiper plug, baffle adapter,cement, wiper rubber,to float collar @ 11404.16' 19:15 19:30 0.25 11,402 11,375 INTRM1 DRILL TRIP T Set back stand#116 f/11402'to 11375', blow down the top drive.All shakers tripped off line,because of problems w/#2 shaker motor. Install floor safety valve in stump. 19:30 21:00 1.50 11,375 11,375 INTRM1 RIGMNT RGRP T Replace a shaker motor on#2 shaker in the pit room.Change shaker screens to 325 on shaker#1. Change 2 screens on shaker#2 due to damage while changing motor. 21:00 21:15 0.25 11,375 11,402 INTRMI CEMEN REAM T Make a top drive connection on stand#116. Ream in the hole f/ 11375'to 11402'. 21:15 23:00 1.75 11,402 11,504 INTRMI CEMEN"DRLG P Drill float collar @ 11404.16', cement,then Ray's silver bullet float shoe @ 11485'to 11487'.Clean out rat hole f/11487'to TD of 11504'. Drill w/200 gpm w/1600 psi, rotate 60 rpm w/10.5k ft lbs of torque. 23:00 23:30 0.50 11,504 11,524 INTRM1 DRILL DDRL P Drill 20'of new hole f/11504'to 11524'(6996'TVD).ADT.5 hrs. Drill w/5/10 WOB, Pumping 200 gpm w/ 1600 psi, Rotate 60 rpm w/10.5k ft lbs of torque. PU wt 215k,SO wt 160k, Rot wt 185k. 23:30 00:00 0.50 11,524 11,524 INTRMI DRILL CIRC P Circulate and condition mud f/ FIT/LOT @ 11524'. Pumping 200 gpm w/1600 psi. 04/01/2011 Continue to circulate prior to performing Formation Integrity Test,monitor well-static, RU then perform FIT to 12.7 ppg-chart test, RD testing equip. Directional drill 6-1/8"production hole per geologists f/11524'to 12976'(7027'TVD), using Sperry Sun GeoPilot 5200(ser#TL081).ADT 15.9 hrs.Total hrs on bit 16.4 hrs. Total hrs on jars 16.4 hrs. Drill w/8 to 15 WOB, Pumping 200-225 gpm w/1600-2230 psi, Rotate 80-120 rpm w/13.5 to 10.5k ft lbs of torque on bottom,torque off bottom 12 to 10.5 ft lbs. PU wt 215 to 212k,SO wt 160 to 152k, Rot wt 185 to 180k. ECD's 10.7 ppg to 11.29 ppg. Note:275 bbls dilution @ 12500'. 00:00 00:45 0.75 11,524 11,524 INTRM1 DRILL CIRC P Circulate and condition mud f/ FIT/LOT @ 11524'. Pumping 200 gpm w/1600 psi. MW 9.5+ 00:45 01:00 0.25 11,524 11,524 INTRM1 DRILL OWFF P Monitor well f/flow-static. Page 31 of 39 c1 )e l( Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 01:45 0.75 11,524 11,524 INTRM1 DRILL RURD P Stand back a stand. Rig up to perform Formation Integrity Test. ti` 01:45 02:00 0.25 11,524 11,524 INTRM1 DRILL FIT P Perform FIT:MW 9.6 ppg,applied fp')- pressure 1110 psi,Shoe @ 11487' (6991'TVD). Drilled depth 11524' t2 (6997'TVD)=20'new hole. F 1 02:00 02:15 0.25 11,524 11,524 PROD1 DRILL RURD P Rig down testing equipment. 02:15 12:00 9.75 11,524 12,139 PROD1 DRILL DDRL P Directional drill 6-1/8"production hole per geologists f/11524'to 12139' 3 Pr?' (7007 TVD), using Sperry Sun r// GeoPilot 5200(ser#TL081).ADT 7.71 hrs.Total hrs on bit 8.21 hrs. ,(' Total hrs on jars 8.21 hrs. Drill w/8 (µvJ to 15 WOB, Pumping 200 to 224 gpm w/1600-2040 psi, Rotate 80-120 rpm w/13.5 to 12k ft lbs of torque on bottom,torque off bottom 12 to 10.5 ft lbs. PU wt 215 to 210k, SO wt 160 to 150k, Rot wt 185 to 180k. ECD's 10.7 ppg to 11.19 ppg. 12:00 00:00 12.00 12,139 12,976 PROD1 DRILL DDRL P Directional drill 6-1/8"production hole per geologists f/12139'to 12976' (7027'TVD), using Sperry Sun GeoPilot 5200(ser#TL081).ADT 8.19 hrs.Total hrs on bit 16.4 hrs. Total hrs on jars 16.4 hrs. Drill w/ 5-15 WOB, Pumping 225 gpm w/ 2010-2230 psi, Rotate 120 rpm w/ 13 to 10.5k ft lbs of torque on bottom,torque off bottom 10.5 ft lbs. PU wt 210 to 212k,SO wt 150 to 152k, Rot wt 180 to 182k. ECD's 11.19 ppg to 11.26 ppg. Note:275 bbls dilution @ 12500'. 04/02/2011 Continue to directional drill 6-1/8"production hole per geologists f/12976'to 14525'(7044'TVD), using Sperry Sun GeoPilot 5200(ser#TL081).ADT 15.69 hrs.Total hrs on bit 32.09 hrs.Total hrs on jars 32.09 hrs. Drill w/8 to 14 WOB, Pumping 200-225 gpm w/2190-2480 psi, Rotate 120 rpm w/10.5 to 12k ft lbs of torque on bottom,torque off bottom 9 to 10.5 ft lbs. PU wt 210 to 221k,SO wt 150 to 145k, Rot wt 180 to 184k. ECD's 11.29 ppg to 11.62 ppg. Note:275 bbls dilution @ 13200' and 275 bbls @ 13900'. Circulate to reduce ECD's. Pumping 220 gpm w/2400 psi,rotate 120 rpm w/10k ft lbs of torque. 00:00 12:00 12.00 12,976 13,856 PROD1 DRILL DDRL P Directional drill 6-1/8"production hole per geologists f/12976'to 13856' (7042'TVD), using Sperry Sun GeoPilot 5200(ser#TL081).ADT 8.72 hrs.Total hrs on bit 25.12 hrs. Total hrs on jars 25.12 hrs. Drill w/ 7-13 WOB, Pumping 200-225 gpm w/2140-2330 psi, Rotate 120 rpm w/ 10.5 to 12k ft lbs of torque on bottom,torque off bottom 9-10.5 ft lbs. PU wt 210 to 218k,SO wt 150 to 148k, Rot wt 180 to 182k. ECD's 11.29 ppg to 11.37 ppg. Note: 275 bbls dilution @ 13200'. Page 32 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 13,856 14,525 PROD1 DRILL DDRL P Directional drill 6-1/8"production hole per geologists f/13856'to 14525' (7044'TVD), using Sperry Sun GeoPilot 5200(ser#TL081).ADT 6.97 hrs.Total hrs on bit 32.09 hrs. Total hrs on jars 32.09 hrs. Drill w/ 7-13 WOB, Pumping 200-225 gpm w/2140-2330 psi, Rotate 120 rpm w/ 10.5 to 11.5k ft lbs of torque on bottom,torque off bottom 9-10.5 ft lbs. PU wt 215 to 221k,SO wt 148 to 145k, Rot wt 184 to 180k. ECD's 11.37ppg to 11.62 ppg. Note:275 bbls dilution @ 13900'. 04/03/2011 Continue to directional drill 6-1/8"production hole per geologists f/14525'to 15097'(7052'TVD), using Sperry Sun GeoPilot 5200(ser#TL081).ADT 6.32 hrs.Total hrs on bit 38.41 hrs.Total hrs on jars 38.41 hrs. Drill w/ 8 to 14 WOB, Pumping 200-225 gpm w/2190-2480 psi, Rotate 120 rpm w/10.5 to 12k ft lbs of torque on bottom,torque off bottom 9 to 10.5 ft lbs. PU wt 210 to 221k,SO wt 150 to 145k, Rot wt 180 to 184k. ECD's 11.62 ppg to 11.62 ppg. Circulate to reduce ECD's. Pumping 220 gpm w/2400 psi, rotate 120 rpm w/10k ft lbs of torque. ECD's pumping 219 gpm were 11.74 ppg, ECD's after-pumping 213 gpm were 11.57 ppg. Continue to directional drill 6-1/8"production hole per geologists f/15097'to 15765'(7040.7'TVD), using Sperry Sun GeoPilot 5200(ser#TL081).ADT 9.37 hrs.Total hrs on bit 47.78 hrs.Total hrs on jars 47.78 hrs. Drill w/5 to 10 WOB, Pumping 220 gpm w/2450 to 2630 psi, Rotate 120 rpm w/10.5 to 12k ft lbs of torque on bottom,torque off bottom 9 to 10.5 ft lbs. PU wt 225 to 230k, SO wt 145 to 138k, Rot wt 184 to 176k. ECD's 11.81 ppg to 11.59 ppg. Note:Geologist noted a fault @ 15440'and again @ 15590'. Note:275 bbls dilutions @ 14600'and 15150',then 550 bbl dilution @ 15400'with new 9.6 ppg mud 00:00 09:00 9.00 14,525 15,097 PROD1 DRILL DDRL P Directional drill 6-1/8"production hole per geologists f/14525'to 15097' (7052'TVD), using Sperry Sun GeoPilot 5200(ser#TL081).ADT 6.32 hrs.Total hrs on bit 38.41 hrs. Total hrs on jars 38.41 hrs. Drill w/ 7-10 WOB, Pumping 215-220 gpm w/2380-2630 psi, Rotate 120 rpm w/ 11 to 11.5k ft lbs of torque on bottom,torque off bottom 10-10.5 ft lbs. PU wt 220 to 225k,SO wt 145 k, Rot wt 180 to 184k. ECD's 11.62 ppg to 11.83 ppg. Note:275 bbls dilution @ 14600' with new mud. 09:00 10:00 1.00 15,097 15,097 PROD1 DRILL REAM P Ream while circulating to reduce ECD's and clean hole. Pumping 220 gpm w/2400 psi. Rotate 120 rpm w/ 10k ft lbs of torque.Work f/15097'to 15000'. ECD's pumping 219 gpm were 11.74 ppg, ECD's after--pumping 213 gpm were 11.57 ppg. Page 33 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 12:00 2.00 15,097 15,193 PROD1 DRILL DDRL P Directional drill 6-1/8"production hole per geologists f/15097 to 15193' (7052'TVD), using Sperry Sun GeoPilot 5200(ser#TL081).ADT 1.21 hrs.Total hrs on bit 39.62 hrs. Total hrs on jars 39.62 hrs. Drill w/ 7-11 WOB, Pumping 220 gpm w/ 2490 psi, Rotate 120 rpm w/11.5 k ft lbs of torque on bottom,torque off bottom 10 ft lbs. PU wt 226 k,SO wt 144k, Rot wt 183k. ECD's 11.81 ppg. Note:275 bbls dilution @ 15150' with new 9.6 ppg mud. 12:00 00:00 12.00 15,193 15,765 PROD1 DRILL DDRL P Directional drill 6-1/8"production hole per geologists f/15193'to 15765' (7040.77'TVD), using Sperry Sun GeoPilot 5200(ser#TL081).ADT 8.16 hrs.Total hrs on bit 47.78 hrs. Total hrs on jars 47.78 hrs. Drill w/ 5-10 WOB, Pumping 220 gpm w/ 2490-2630 psi, Rotate 120 rpm w/ 11.5 to 10.5 k ft lbs of torque on bottom,torque off bottom 10 ft lbs. PU wt 226-230 k,SO wt 144-135k, Rot wt 183-176k. ECD's 11.81 to 11.59 ppg. Note:550 bbls dilution @ 15400' with new 9.6 ppg mud. Note:Geologist noted a fault @ 15440'and again @ 15590'. 04/04/2011 Continue to directional drill 6-1/8"production hole per geologists f/15765'to 16529'(7069.73'TVD), using Sperry Sun GeoPilot 5200(ser#TL081).ADT 16.88 hrs.Total hrs on bit 64.66 hrs.Total hrs on jars 64.66 hrs. Drill w/5 to 25 WOB, Pumping 210-220 gpm w/2590 to 2850 psi, Rotate 120 rpm w/11.5 to 15.5k ft lbs of torque on bottom,torque off bottom 11.5 to 13 ft lbs. PU wt 230 to 245k, SO wt 135 to 130k, Rot wt 176 to 180k. ECD's 11.55 ppg to 11.87 ppg. Circulate bottom's up,obtain sample prior to POOH to sidetrack @ approx 15130'. Pumping 210 gpm w/ 2850 psi.Work string f/16529'to 16433'. Note:Geologist noted a fault @ 15440'and again @ 15590'.Out of zone f/15590'to 16175'(585'). Back in Nechilik formation @ 16175'to 16529'(354') Note:275 bbls dilutions @ 16100'with new 9.6 ppg mud. 00:00 12:00 12.00 15,765 16,040 PROD1 DRILL DDRL P Directional drill 6-1/8"production hole per geologists f/15765'to 16040' (7032'ND), using Sperry Sun GeoPilot 5200(ser#TL081).ADT 8.59 hrs.Total hrs on bit 56.37 hrs. Total hrs on jars 56.37 hrs. Drill w/ 7-25 WOB, Pumping 220 gpm w/ 2590-2800 psi, Rotate 120 rpm w/ 11.5 to 12 k ft lbs of torque on bottom,torque off bottom 11.5 ft lbs. PU wt 230-235 k,SO wt 135-134k, Rot wt 176-181k. ECD's 11.59 to 11.65 ppg. Note:Geologist noted a fault @ 15440'and again @ 15590'. Drilling out of Nechilik sand. Page 34 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 23:30 11.50 16,040 16,529 PROD1 DRILL DDRL P Directional drill 6-1/8"production hole per geologists f/16040'to 16529' (7069'ND), using Sperry Sun GeoPilot 5200(ser#TL081).ADT 8.29 hrs.Total hrs on bit 64.66 hrs. Total hrs on jars 64.66hrs. Drill w/ 5-20 WOB, Pumping 211-220 gpm w/2590-2740 psi, Rotate 120 rpm w/ 12 to 13.5 k ft lbs of torque on bottom,torque off bottom 11.5 to 13 ft lbs. PU wt 235-240 k,SO wt 134-130k, Rot wt 181-183k. ECD's 11.59 to 11.82 ppg. Note:Geologist noted a fault @ 15440'and again @ 15590'.Out of zone f/15590'to 16175'(585'). Back in Nechilik formation A 16175' •�p t9 16529'(354') 23:30 00:00 0.50 16,529 16,529 PROD1 DRILL CIRC T Circulate bottoms up,obtain sample prior to POOH to sidetrack @ approx 15130'. Pumping 210 gpm w/2850 psi.Work string f/16529'to 16433'. 04/05/2011 Circulate bottoms up,obtain sample prior to POOH to sidetrack @ approx 15130'. Pumping 210 gpm w/2850 psi.Work string f/16529'to 16433'. Stand back stand#169,monitor well-static, Back ream out of hole f/ 16433'to 15790',pump 210 gpm w/2480 psi and pull f/15790'to 15097',Make connection on stand#154 @ 15097',pull up to 15067'to trough hole straight down,trough f/15067'to 15097'.Start time drilling. Decision made by Anch office to call well TD and run liner with shoe planned at 15445'MD. Note:Geologist noted a fault @ 15440'and again @ 15590'.Out of zone f/15590'to 16175'(585'). Back in Nechilik formation @ 16175'to 16529'(354'). 00:00 00:45 0.75 16,529 16,433 PROD1 DRILL CIRC T Circulate bottoms up,obtain sample prior to POOH to sidetrack @ approx 15130'. Pumping 210 gpm w/2850 psi.Work string f/16529'to 16433'. 00:45 01:00 0.25 16,433 16,433 PROD1 DRILL TRIP T Stand back stand#169,monitor well- static. 01:00 02:30 1.50 16,433 15,790 PROD1 DRILL REAM T Back ream out of hole f/16433'to 15790'. Pumping 211 gpm w/2480 psi. Rotate 60-70 rpm w/12k ft lbs of torque. 02:30 04:15 1.75 15,790 15,097 PROD1 DRILL TRIP T Pull out of the hole while pumping 210 gpm w/2480 psi and pull f/ 15790'to 15097'. 04:15 04:30 0.25 15,067 15,067 PROD1 DRILL CIRC T Make a top drive connection on stand#154 @ 15097',pull up to 15067'to trough hole straight down. 04:30 08:00 3.50 15,067 15,097 PROD1 DRILL DDRL T Trough f/15067'to 15097'. Pumping 220 gpm w/2490 psi, ECD's 11.57 PP9. Rotate 70-80 rpm w/11k ft lbs of torque. 08:00 10:30 2.50 15,097 15,098 PROD1 DRILL DDRL T Time drill f/15097'-15098'Ca)215 gp 520 • ecisi.n made to call TD and run 3.5"lower completion(liner)to 15445'MD. 10:30 11:15 0.75 15,098 15,574 PROD1 DRILL TRIP T - . ,s. • . , - - • ..- - static. Page 35 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:15 12:30 1.25 15,574 15,574 PROD1 DRILL CIRC T CBU-210 gpm @ 2350 psi and 120 rpm. 12:30 20:30 8.00 15,574 11,480 PROD1 DRILL REAM P Back ream from 15574'to 7"casing shoe at 11487'MD.210 gpm @ 2350 psi. Drop 2.1"hollow drift on std#120. Flow check well-slight drop in fluid level at flow line(-2"). 20:30 23:00 2.50 11,480 11,480 PROD1 DRILL CIRC P Circulate and pump 40 bbls 9.8 ppg viscosified KCI brine spacer followed by 9.8 ppg brine. Displace 7"casing vol to 9.8 ppg brine.5 bpm @ 1650 psi. 23:00 23:30 0.50 11,480 11,480 PROD1 DRILL OWFF P Flow check well-static. Blow down top drive. 23:30 00:00 0.50 11,480 11,000 PROD1 DRILL TRIP P POH to run 3.5"lower completion. 04/06/2011 POH to run 3.5"lower completion. LD BHA components.Clear rig floor. RU liner running tools.MU 124 jts 3 1/2"liner with 9 swell packers,7 ball actuated sleeves, liner hanger and liner top packer.Circ liner volume. RIH with liner on 4"DP to 10500'. 00:00 04:15 4.25 11,000 178 PROD1 DRILL TRIP P Continue POH with BHA#6. 04:15 08:00 3.75 178 0 PROD1 DRILL PULD P Flow check well at HWDP-OK. Stand back HWDP&jars. PJSM. Remove nuclear source and download MWD. LD flex collars and MWD tools. 08:00 09:00 1.00 0 0 PROD1 DRILL PULD P Clear and clean rig floor. LD all BHA components and Geo Span skid. 09:00 09:30 0.50 0 0 COMPZ CASING RURD P PJSM. RU liner running tools. 09:30 12:00 2.50 0 1,100 COMPZ CASING RUNL P MU 31/2"9.3#L-80 SLHT liner 12:00 12:30 0.50 1,100 1,100 COMPZ RIGMNT RGRP T Change out double stack tongs. 12:30 18:30 6.00 1,100 4,163 COMPZ CASING RUNL P Continue running 3 1/2"liner with:- 9 swell packers and 7 ball actuated frac sleeves. Baker Flex lock liner hanger with seal bore extension. Baker HRD ZXP liner top packer. PUW-96 klbs.SOW-95 klbs. Pour PAL Mix in liner setting sleeve and wait to gel. 18:30 19:00 0.50 4,163 4,260 COMPZ CASING CIRC P Change to 4"DP elevators. PU 1 stand 4"DP and circ liner volume(-50 bbls)at 4 bpm @ 440 psi. Obtain rotating torque with liner at 4253'-4000 ft lbs. 19:00 00:00 5.00 4,260 10,500 COMPZ CASING RUNL P RIH with liner on 4"DP-3000-3600 fph run speed. Top off every 20 stands while RIH. Shoe depth—10400'at MN. Page 36 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/07/2011 24 hr Summary RIH w/liner to shoe depth of 15442'MD. Drop setting ball and pump on seat. Pressure up to 2000 psi to set hanger-OK. Cont pressuring up to 3500 psi to release from liner hanger. Set and test LTP to 1000 psi.CBU. Flow check. Cut drlg line. POH LDDP. LD liner running tool. Pull drlg wear bushing and set tubing wear bushing. RU&run 3 1/2"completion. 00:00 00:30 0.50 10,500 11,500 COMPZ CASING RUNL P Continue running 3 1/2"liner on 4" DP to 11500'-just above 7"shoe. 00:30 01:15 0.75 11,500 11,500 COMPZ CASING CIRC P Circ DP and liner volume.4 bpm @ 770 psi 200kup. 135kdn. 163krot.7k ftlbs torque. Blow down TD. 01:15 04:30 3.25 11,500 15,442 COMPZ CASING RUNL P RIH with liner in to open hole. Work past areas of resistance at 11676, 11957', 15150-15160'. No rotation needed to get liner past these areas. RIH to setting depth with liner shoe at 15442'MD. SY- ,}L 04:30 06:15 1.75 15,442 15,442 COMPZ CASING RUNL P Get on depth and drop liner setting 1°- ball °-ball and pump on seat at 2 bpm reducing to 1 bpm as ball approaches landing seat. Ball on seat at 93 bbls away. Pressure up to 2000 psi to set liner hanger-OK. Increase pressure to 3500 psi to release from hanger. Pull up to expose setting dogs.Set down 35 klbs on liner top and rotate to set liner top packer. Test annulus to 1000 psi for 10 min to verify LTP set-OK. 06:15 06:30 0.25 15,442 15,442 COMPZ CASING RUNL P Pull up hole with liner running tool to 11269'(above liner top at 11288' MD). 06:30 07:45 1.25 15,442 15,442 COMPZ CASING CIRC P Circ and cond mud-5 bpm @ 850 psi. Blow down TD and flow check well- O K. 07:45 09:15 1.50 15,442 15,442 COMPZ RIGMNT SVRG P Slip&cut 75'drilling line.Service top drive and set block height. 09:15 10:45 1.50 15,442 9,633 COMPZ DRILL PULD P Flow check-OK. POH LDDP to pipe shed to 9633'. 10:45 11:15 0.50 9,633 9,633 COMPZ DRILL RGRP T Trouble shoot electrical problem on rig. Replaced UPS supporting Totco and Rig Sense PVT systems 11:15 20:45 9.50 9,633 0 COMPZ DRILL PULD P Continue POH LDDP. LD running tool 20:45 21:15 0.50 0 0 COMPZ RPCOM RURD P Retrieve drilling wear bushing and install tubing wear bushing. 21:15 22:30 1.25 0 0 COMPZ RPCOM RURD P RU tubing tongs and associated handling equipment for running 3 1/2" completion string. Page 37 of 39 Time Logs Date From To Dur S.Death E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 0 1,000 COMPZ RPCOM RCST P PJSM. Run 3 1/2"completion. MU seal assembly and no-go locator. 1 jt 3 1/2"9.3#L-80 EUE-M tubing. HES XN nipple-2.75"no-go. 1 jt 3 1/2"tubing. GLM with DCK-2 shear valve. 3 1/2"tubing-approx 20 jts tubing run at MN. 04/08/2011 Run 3 1/2"tubing-351 jts total+2 jts 4 1/2"tbg below hanger.Get space out and MU wear bushing retrieving tool. Retrieve same. MU tubing hanger and thread control line thru hanger.Test line-OK. Land tubing hanger and RILDS. 00:00 08:15 8.25 1,000 9,170 COMPZ RPCOM RCST P Continue running 3 1/2"completion with: 3 Camco KBMG GLM's with shear valve in bottom station. 08:15 09:45 1.50 9,170 9,170 COMPZ RPCOM RCST P Install TRMAXX safety valve and hook up single control line. Test line to 6000 psi for 10 min-OK. 09:45 13:30 3.75 9,170 11,203 COMPZ RPCOM RCST P Continue running 3 1/2"tubing clamping control line to tubing with one SS band per jt. 13:30 14:30 1.00 11,203 11,203 COMPZ RPCOM RCST P MU landing jt and run in to land no-go locator and calculate tubing space-out. PUW=154 klbs.SOW=108 klbs. Blocks=70 klbs. 14:30 16:30 2.00 11,203 11,203 COMPZ RPCOM CIRC P PJSM.RU circulating lines and displace well with 76 bbls 9.6 ppg KCI brine w/o corrosion inhibitor followed by 306 bbls 9.6 ppg KCL brine with corrosion inhibitor. 5 bpm @ 760 psi. 16:30 17:30 1.00 11,203 11,203 COMPZ RPCOM OWFF P Monitor well. Fluid bubbling in annulus but fluid level dropping. Monitor well until bubbling subsided. Blow down top drive.Well static. 17:30 19:45 2.25 11,203 11,315 COMPZ RPCOM RCST P PU 3.5 x 4.5 XO,4 1/2"spaceout pups and 2 jts 4 1/2"12.6#L-80 IBT-M tubing. MU wear bushing retrieval tool. MU handling jt to retrieval tool. RIH and retrieve wear bushing-OK. 19:45 21:00 1.25 11,315 11,315 COMPZ RPCOM RCST P MU tubing hanger.Cut and thread control line thru hanger port. Test control line port to 5000 psi- OK. Wrap control line above hanger body and install needle valve. Pump open safety valve. 21:00 22:00 1.00 11,315 11,347 COMPZ RPCOM RCST P MU landing jt(A)and land tubing hanger in wellhead. RILDS. NOTE: Used 71 stainless steel control line bands on tubing. 22:00 23:00 1.00 11,347 11,347 COMPZ RPCOM RURD P RU lines and testing manifold to pressure test tubing and annulus. Page 38 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 11,347 11,347 COMPZ RPCOM PRTS P Test inner annulus(IA)to 1000 psi for 30 min to verify seal assembly and LTP integrity-OK. Drop ball and rod and allow to fall on seat. Cementers fill lines with brine. 04/09/2011 Test tbg&IA to 3500 psi for 30 min-good tests. Install TWC and test tbg hanger seals to 5000 psi for 10 min-good test.Test TWC from below to 2600 psi for 10 min-good test. ND BOPE. NU xmas tree.Test tree and adapter void to 5000 psi for 10 min-good tests. Freeze protect well by pumping 76 bbls diesel to tubing and allowing to U tube in to IA to FP well to 2200'. Install BPV. LD excess 4"DP for rig move. LD mousehole. Release rig at 17:00 hrs. 00:00 01:45 1.75 11,347 11,347 COMPZ RPCOM PRTS P RU&test lines to 4000 psi.Test tubing to 3500 psi for 30 min. Good test. Lost 25 psi in 30 min. Bleed tubing to 2200 psi.Test lines to 400 psi.Test annulus to 3500 psi for 30 min. Good test. Lost 25 psi in 30 min. Bleed tubing pressure to zero and shear DCK valve. 01:45 02:45 1.00 11,347 11,347 COMPZ RPCOM PRTS P LD landing jt(A). Install TWC in hanger profile&MU landing jt(B). Test tubing hanger seals to 5000 psi 1/ for 10 min.Good test. No visible fluid leakage from weep holes on wellhead during test. 02:45 04:15 1.50 11,347 11,347 COMPZ WHDBO PRTS P Pressure test TWC to 2600 psi from below for 10 min.Good test. RD test equipment from rig floor. 04:15 07:45 3.50 11,347 11,347 COMPZ WHDBO NUND P PJSM. ND BOPE. NU Xmas tree. Test tree and tubing hanger void to 5000 psi for 10 min.Good tests. 07:45 08:15 0.50 11,347 11,347 COMPZ WHDBO RURD P Pull TWC. 08:15 11:00 2.75 11,347 11,347 COMPZ DRILL FRZP P RU hard line and manifold to Xmas tree and annulus valve. Pump 76 bbls diesel to tubing. connect tubing and IA. Allow diesel to U tube to balance to freeze protect tubing and IA to 2200'. 11:00 12:00 1.00 11,347 11,347 COMPZ DRILL MPSP P Install BPV.Secure wellhead and cellar area. 12:00 12:30 0.50 11,347 11,347 COMPZ DRILL RURD P Clear cellar area of rig equipment. 12:30 16:00 3.50 11,347 11,347 COMPZ DRILL PULD P PJSM. Install mousehole. LD excess 4"DP from derrick for rig move. 16:00 17:00 1.00 11,347 11,347 COMPZ DRILL RURD P LD mousehole.Clear rig floor. Prepare for move to CD3-128. Release rig at 17:00 hrs on 4/9/2011. Page 39 of 39 CD3-125 Well Work Summary DATE SUMMARY 4/16/11 PULLED BALL& ROD @ 11268' RKB. PULLED 1"SOV @ 11220' RKB & SET 1" v @ SAME. MIT IA, PASSED. PULLED RHC PLUG BODY @ 11268' RKB. MEASURED BHP @ 11185' SLM (MAX PSI= 3235.23/TEMP= 159.77) SET 2.81 ISO SLEEVE @ 2171' RKB (DRIFTED 2.29") COMPLETE 4/18/11 PUMPED ALPINE NECHELIK SAND FRAC WITH A TOTAL OF 753,075 LBS OF PROPPANT (335,000# 16/30 COLORADO WHITESAND AND 418,075# 16/20 CARBOLITE) PLACED BEHIND / av PIPE. FRAC PUMPED TO 102% DESIGN. FLUSH JOB TO COMPLETION, WITH 37 BBLS XL (/ GEL, 37 BBL LINEAR GEL AND 35 BBLS DIESEL FREEZE PROTECTION. 4/19/11 GAUGED TBG TO 2.86"TO 2171' RKB. PULLED 2.81 ISO SLEEVE @ 2171' RKB. GAUGED TBG TO 2.78"TO 11268' RKB. SET CATCHER SUB @ 11268' RKB. IN PROGRESS. 4/21/11 ATTEMPTED PULL SPG @ 11220' RKB WITHOUT SUCCESS, TOOLS FOULED WITH FRAC SAND. PULLED 3-1/2"CATCHER SUB @ 11268' RKB. BRUSHED& FLUSHED TBG TO 11268' RKB ATTEMPTING TO CLEAN UP FRAC SAND. IN PROGRESS. 4/22/11 SET CATCHER SUB @ 11268' RKB. PULLED SPG @ 11220' RKB, RECOVERED GOOD DATA. SET 1/4" OV @ SAME. PULLED CATCHER SUB FROM 11268' RKB. SET 2.81" ISO SLEEVE @ 2171' RKB. COMPLETE. . . HALLIBURTON | Sperry Drilling WELL LOG TRANSMITTAL To: State of Alaska April 13, 2011 Alaska Oil and Gas Conservation Commission Atn.: [hriytine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: C[]3'125, [D3-l35PBl AK-K4VV-0007896843 CD3-125PB1 50'103-20633'70 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log 3" x5"TVD TRIPLE COMBO Logs: 1 Color Log CD3-125 50-103-20632-00 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log 2" x5"TVD TRIPLE COMBO Logs: 1 Color Log Digital Log Images & LWDG-formatted LIS Data w/verification listing: 1 CD PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-273-3536 Fax: 9D7-273-3S35 ,l/��_/-��� ,]n�r��~�~— B om c�~ Date: Signed: 0,-- ~ Page 1 of 2 Schwartz, Guy L (DOA) From: Anderson, Nina M [Nina.Anderson@conocophillips.com] Sent: Sunday, April 10, 2011 9:51 PM To: Schwartz, Guy L (DOA) Subject: RE: Open Hole Sidetrack CD3-125 (PTD 210-189) Guy - The Alpine Asset team made the decision not to sidetrack CD3-125. The well was called at TD and there was not any new footage drilled. CD3-125 was completed per the permit, although the liner was not run to TD due to the excursion into the shales. The submitted 407 will have the final completion records for this well. Thanks. Liner TO C. ism' Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907)-265-6403 Cell: (907)229-4008 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, April 05, 2011 8:43 AM To: Anderson, Nina M Subject: RE: Open Hole Sidetrack CD3-125 (PTD 210-189) Nina, No Paperwork is necessary if you are staying with 500' of the PTD BHL. Also the revised PTD for CD3 -125 should be at your office as of today. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Anderson, Nina M [mailto:Nina.Anderson@conocophillips.com] Sent: Tuesday, April 05, 2011 7:25 AM To: Schwartz, Guy L (DOA) Subject: Open Hole Sidetrack CD3-125 (PTD Guy - While drilling CD3-125 Lateral hole section, approximately 500' of shale above the Nechelik was exposed after crossing a fault. The decision was made last night to come back and open hole sidetrack above the fault at 15,097' MD. Currently we are toughing preparing to time drill. Please advise on what paperwork is needed. Also, we have not received the Revised PTD for CD3-125 which was submitted March 22nd. Thanks. Nina Anderson 4/11/2011 Page 2 of 2 Drilling Engineer Alpine Drilling Team Office: (907)-265-6403 Cell: (907)229-4008 4/11/2011 Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Monday, March 21, 2011 8:55 AM To: Anderson, Nina M Subject: RE: CD3-125 Cut and cement 7"Casing (PTD 210-189) Nina, As follow-up to our phone call on Saturday I think I forgot to answer your question about needing a sundry. It will not be required. Your proposal as stated below is acceptable. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Anderson, Nina M [mailto:Nina.Anderson@conocophillips.com] Sent: Saturday, March 19, 2011 2:11 PM To: Schwartz, Guy L(DOA) Subject: RE: CD3-125 Cut and cement 7" Casing (PTD 210-189) Guy - The crews on Doyon 19 were eventually able to free the 7" casing and have begun pulling operations. Currently we have about 180 joints to go. Based on our unsuccessful attempts at a clean out run on the adjacent well CD3-127, we would like to propose running in with a 3-1/2" cement stinger to just above the HRZ to lay in an abandonment plug. This plug will be 15.8 ppg with a viscous plug placed below. Proposed top is 10,400' MD and bottom is 10,800' MD which is just above the HRZ. The cement volumes for this lower plug have a 40% excess included, therefore there is a potential for it to be a 700' plug. The second plug will be set from 7750' -7350' MD for a 400' total KOP. The KOP depth is 7500' MD. This second plug is below the Qannik reservoir which is 6124' MD. The depth of the KOP will be recorded when we run into make a tag. UPDATED Plan forward is as follows: • Pull 7" Casing • RIH with 3-1/2"cement stinger and place 15.8 ppg abandonment plug on top of HRZ with the base 10,800' MD. • Pump viscous plug, followed by 400'cement to 10,400' MD. • Pull uphole to sidetrack point and set KOP with viscous plug below. Bottom cement is planned for 7750' MD and top cement is 7350' MD. • Both plugs will be above the Nechelik/Kuparuk formations and the upper Qannik section (6124' MD) • RIH and kickoff with rotary steerable Please let me know if you have any questions or concerns with our proposed operation. Also please advise if a Sundry needs to be submitted on Monday. Currently the new sidetrack plan is within the 500' radius of the original permitted plan. Thanks, Nina Anderson Senior Drilling Engineer 6/16/2011 Page 2 of 2 Alpine 907-229-4008 ina M 18,2011 4:05 PM L(DOA) 15 Cut and cement 7"Casing(PTD 210-189) Guy- Doyon 19 is currently having difficulties running the 7" intermediate casing string on CD3-125. We are unable to circulate or move casing. After working the pipe since early this morning, the decision has been made to cut casing, plug back the hole, and sidetrack above the stuck point. Plan forward is as follows: • RIH with Halliburton string shot and cut casing - 100' above the top of HRZ at 10,800' MD • Pull 7" Casing • RIH with 3-1/2" cement stinger and place 15.8 ppg abandonment plug on top of 7"casing stub • Pull uphole to sidetrack point and set KOP • RIH and kickoff with motor or rotary steerable • Contingency if casing does not come free at first point, will move up hole and make a second cut below the Qannik. ConocoPhillips intentions are to save the upper hole and sidetrack below the Qannik. Thanks. Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907)-265-6403 Cell: (907)229-4008 6/16/2011 f � SirATIE [F ALASIKKA SEAN PARNELL,GOVERNOR r ALASKA OIL AND =AS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 T. Senden Wells Engineer \Q ConocoPhillips Alaska, Inc. Q v P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-125 Sundry Number: 311-115 Dear Mr. Senden: 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, Daniel T. Seamount, Jr. Chair DATED this day of April, 2011. Encl. STATE OF ALASKA t ALASN L AND GAS CONSERVATION COMMISS, `` APPLICATION FOR SUNDRY APPROVALS ViorL,dr 20AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Rill Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulatep. Alter casing g r Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r" • Exploratory r 210-189 3.Address: Stratigraphic r Service r 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20632-00 ` 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 r No P, CD3-125 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 372105,25538 ' Colville River Field/Fiord Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 16529 7070 16529' Casing Length Size MD TVD Burst Collapse Conductor 77' 16" 114' 114' Surface 2916' 9.625" 2916' 2462' Intermediate 11487' 7" 11487' 6990' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): none none none na na Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) no packer no SSSV 12.Attachments: Description Summary of Proposal r;► 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r✓ Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/15/2011 Oil r✓ , Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r 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: T.Senden @ 265-1544 Printed Name T. Sende Title: Wells Engineer Signature \iiIt3t\ Phone:265-1544 Date �� Commission Use Only 410 Sundry Number: ( 1- ( 15 Conditions of approval: Notify Commission so that a representative may witness R `� Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r '1 ' `EC E' '� Other: APR 0 5 2011 Alaska ail&Gas Cons.Comrrssiw Subsequent Form Required: /D ,,11 D ti 111.:Pordge OAPPROVED BY Approved by: �' , COMMISSIONER THE COMMISSION Date: 41ES)/1 I ���SS AA us Form 10-403 Revised112U10"PR 1 $ "tf :I R I G I NA L ;id) ' 6o 11 Submit in Duplicate G�// a • t ' Overview: CD3-125 is currently being drilled and an expected completion date of 4/10/11. A fracture stimulation is planned prior to putting the well on production. A 3-1/2" ported sleeve system will • be run in the openhole section with swell packers. A coil cleanout will only be performed should it •e necessary pos- rac. Procedure: 1. MIRU sixteen clean insulated frac tanks with a berm surrounding the tanks that holds the tank volume plus 10%. Load tanks with seawater from the injection system (approximately 4000 bbls are required for the treatment) 2. Rig up Schlumberger equipment and stab Tree Saver. (Test tree saver seals to expected pressure using warm diesel to assure seal integrity in tubing hanger). 3. Pressure test surface lines to 9500 psi 4. Pump the 250 bbl Breakdown with Schlumberger's YF125ST fluid system. Bring pumps up to maximum rate ASAP. 5. Pump the following schedule at 15-20 BPM with a maximum pressure of 4750 psi, add breaker as per lab results. Maintain 3000 psi on the IA during the treatment. • 300 bbls YF125ST Pad • 95 bbls YF125ST w/ 1 ppa 16/30 White Sand • 95 bbls YF125ST w/2 ppa 16/30 White Sand • 180 bbls YF125ST w/4 ppa 16/30 While • 140 bbls YF125ST w/6 ppa 16/30 White Sand • 110 bbls YF 125ST w/7 ppa 16/30 White Sand • Drop ball and repeat 7 more times • Flush with linear fluid and freeze protect Total Sand: —800,000 lbs. 6. Monitor the surface pressure fall-off at the end of the job for 30 min (or until closure is verified) if the well does not screen out. 7. Rig down equipment, (and prep for next well frac after evaluation by Engineering) move off location. FCO if required with slick diesel. slima Lig //\ [ SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 COMMISSION COMSSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Fiord Oil Pool, CD3-125 ConocoPhillips Alaska, Inc. Permit No: 210-189 revised Surface Location: 4023' FNL, 1185' FEL, SEC. 05, T12N, R5E, UM Bottomhole Location: 2201' FNL, 3762' FEL, SEC. 17, T12N, R5E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. 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. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 7 day of April, 2011. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) • , ConocoPhillips Alaska, Inc.P nct Offe Box 100360 a995 ConocoPhillips Anchorage, Alaska 99510-0360 Telephone 907-276-1215 March 22nd, 2011 "� ` RECE% Y EU Alaska Oil and Gas Conservation Commission Z(1" 333 West 7th Avenue, Suite 100 MAR + 3 Anchorage, Alaska 99501 k�ON a Ges Cons,Gomm Re: Application for REVISED Permit to Drill CD3-125gtpin8 iasioa Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a revised Permit to Drill an onshore production well from the CD3 (Fiord) pad. This application is a follow up to the e-mail approval granted today by Guy Schwartz. The spud date for this well was February 2"d, 2011. The permit revision is needed because the directional plan has changed. The new directional plan has a segment that is 700' away from the permitted wellbore. Hole problems prevented the original casing from going to TD, therefore the intermediate hole will be re- drilled starting from the top of the cement plug at 7,350' MD. 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. 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 Nina Anderson at 265-6403, or Liz Galiunas at 265-6247. Sincerely, Nina Ander o Drilling Engineer Attachments 1. Form 10-401 2. Directional Program cc: CD3-125 Well File/Sharon Allsup Drake ATO 1530 Liz Galiunas ATO 1500 Ryan Robertson ATO 1702 Mike A. Winfree ATO 1704 RECEIVED(\ STATE OF ALASKA AR 2 1 2011 � ALASKA OIL AND GAS CONSERVATION COMMISSION WLR l/ Sc-=�- PERMIT TO DRILLAlaska a Gas C�s.Got>Iuniaai� 20 AAC 25.005 Anchorage 1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil E Service-Winj ❑ Single Zone 1 c.Specify if well is proposed for: Drill E Re-drill ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: u Blanket H Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 CD3-125 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 18888' TVD: 7081' Colville River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): 4023'FNL, 1185'FEL, Sec.5,T12N, R5E, UM ADL 372105,025538,0 67 (t Fiord Oil Pool Top of Productive Horizon: 8.Land Use Permit: 40'45 13.Approximate Spud Date: 1509'FNL,2565'FEL,Sec.7,T12N, R5E, UM LAS2112 2/2/2011 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2201'FNL,3762'FEL,Sec. 17,T12N, R5E, UM 2560 +/-4.0 miles to ADL 391451 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 40.6 feet 15.Distance to Nearest Well Open Surface:x- 387896.0 y- 6003766.4 Zone- 4 GL Elevation above MSL: 28 feet to Same Pool: , 16.Deviated wells: Kickoff depth: 350 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 89.4° deg Downhole:3305 psig Surface:2462 psig 18.Casing Proccram: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Pre Installed 476 sx AS Lite 3,230 sx 15.8'G' 8.75" 7" 26 L-80 BTC-M 11559 37 37 11596 7009 1st-204 sx 15.8'G' 2nd-188 sx 15.8 G 3.5" 9.3 L-80 EUE 11128 32 32 11160 6655 Tubing 6.125" 3.5" 9.3 L-80 IBT-M 12685 11160 6655 19340 7081 Liner with Swell PKRS and SS for Frac 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 77.00 16" 114 114 Surface 2,916.00 9.625" 1892 c.f. Lead/275 c.f.Tail 2916 2,462 Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20.Attachments: Property Plat❑ BOP Sketch ❑ Drilling Program❑ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑✓ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements L 21.Verbal Approval: Commission Representative:Guy Schwartz(2/22/2011) Date: ') 22. I hereby certify that the foregoing is true and correct. Contact Nina Anderson 265-6403 N Printed Name Chip Alvord Title Alaska Drilling Manager /� Signature 0 Phone 265-6120 Date N.2...1z a ILA ,. Commission Use Only Permit to Drill API Number: Permit A royalSee cover letter Number: a?JD/89 50,Q��063'a0000 Date: I ij ( , , for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m thane,gas hydrates,or gas contained in shales: u ,If 3S t) ?Se,.?Se,. k Of ,I S�Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No � p Other: 0.066 s j/Inn,jai. -7e-7-5(_1-125 measures: Yes ❑ No d Directional svy req'd: Yes d No ❑ C -; / APPROVED BY THE COMMISSION DATE: tIii A •'' ,COMMISSIONER Form 10-401 (Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) 3-GbI/it in Duplicate ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad Rig: CD3-125 Plan: CD3-125 Plan: CD3-125wp09 Hold through HRZ and Kalubik. 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M _0 illma VCD 000LI- CO o o 0 co 000 0 0 Lo 0 000 'I� _0 0 I i o I r o II 0 0001.IIro o O I c o c-4o o M o0o I 1 —o o cv a) 00 I-8d9Z6-£aa 6i. 000 \.0 0 U O 00 4_• _ 0 D0 SSL Z L o °� 00 c'? 0007 6 —0 • J 0 O N 000 x Poo - x 0 ti r 000 ZI Co \00 000 0000 °9.9 Y cb o La It) 00 rn- o N ogOL Y , r o0 M X00 00 ❑ _ Vco 2 m Y 2 m O 0 I I 0 0 0 0 0 0 0 0 0 0 0 Lo oM ti (uill 0056) gTdaQ Ie3!1JeA anal ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Rig:CD3-125 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Rig:CD3-125 @ 49.19ft(D19) Project: Western North Slope MD Reference: Rig:CD3-125 @ 49.19ft(D19) Site: CD3 Fiord Pad North Reference: True Well: Rig:CD3-125 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-125 Design: CD3-125wp09 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 CD3 Fiord Pad Site Position: Northing: 469.98 ft Latitude: 53°58'43.652 N From: Map Easting: -401.27ft Longitude: 152° 19'30.231 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -1.88 ° Well Rig:CD3-125 Well Position +N/-S 0.00 ft Northing: 6,003,766.42 ft Latitude: 70°25'9.210 N +El-W 0.00 ft Easting: 387,895.98 ft Longitude: 150°54'47.701 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.60 ft Wellbore Plan:CD3-125 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2010 3/22/2011 16.22 79.78 57,322 Design CD3-125wp09 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,500.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 36.59 0.00 0.00 142.00 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +EI-W Rate Rate Rate Tool Face (ft) (0) (°) (ft) ft (ft) (ft) (°/100ft) (°1100ft) (°/100ft) (°) 7,500.00 60.44 263.20 4,731.42 4,682.23 -412.06 -5,121.48 0.00 0.00 0.00 0.00 7,550.00 60.45 262.34 4,756.08 4,706.89 -417.54 -5,164.63 1.50 0.01 -1.72 -90.00 7,600.00 60.46 260.90 4,780.74 4,731.55 -423.88 -5,207.66 2.50 0.02 -2.87 -90.00 7,833.14 55.00 258.47 4,905.19 4,856.00 -459.04 -5,401.53 2.50 -2.34 -1.04 -160.00 8,583.14 55.34 249.34 5,334.15 5,284.96 -629.53 -5,991.97 1.00 0.05 -1.22 -90.00 10,388.41 55.77 179.99 6,445.00 6,395.81 -1,726.37 -6,747.57 3.10 0.02 -3.84 -111.00 11,053.20 55.77 179.99 6,819.00 6,769.81 -2,275.99 -6,747.44 0.00 0.00 0.00 0.00 11,596.16 83.00 168.00 7,009.00 6,959.81 -2,774.99 -6,690.10 5.41 5.02 -2.21 -24.83 11,631.16 83.00 168.00 7,013.27 6,964.08 -2,808.97 -6,682.88 0.00 0.00 0.00 0.00 11,734.33 , 89.51 168.00 7,020.00 6,970.81 -2,909.61 -6,661.49 6.31 6.31 0.00 0.00 12,987.75 89.51 142.93 7,030.88 6,981.69 -4,040.75 -6,145.17 2.00 0.00 -2.00 -90.11 18,887.92 89.51 142.93 7,081.19 7,032.00 -8,748.36 -2,588.79 0.00 0.00 0.00 0.00 3/21/2011 11:49:26AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips I-IALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Rig:CD3-125 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Rig:CD3-125 @ 49.19ft(D19) Project: Western North Slope MD Reference: Rig:CD3-125 @ 49.19ft(D19) Site: CD3 Fiord Pad North Reference: True Well: Rig:CD3-125 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-125 Design: CD3-125wp09 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +El-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 4,682.23 7,500.00 60.44 263.20 4,731.42 4,682.23 -412.06 -5,121.48 6,003,431.34 382,769.33 0.60 -2,828.39 KOP:DLS 1.50 TFO-90.00 7,550.00 60.45 262.34 4,756.08 4,706.89 -417.54 -5,164.63 6,003,426.52 382,726.11 1.50 -2,850.64 Start DLS 2.50 TFO-90.00 7,600.00 60.46 260.90 4,780.74 4,731.55 -423.88 -5,207.66 6,003,420.82 382,682.99 2.50 -2,872.13 Start DLS 2.50 TFO-160.00 7,700.00 58.11 259.89 4,831.82 4,782.63 -438.21 -5,292.42 6,003,407.77 382,598.03 2.50 -2,913.02 7,800.00 55.77 258.83 4,886.37 4,837.18 -453.67 -5,374.78 6,003,393.55 382,515.45 2.50 -2,951.55 7,833.14 55.00 258.47 4,905.19 4,856.00 -459.04 -5,401.53 6,003,388.58 382,488.63 2.50 -2,963.78 Start DLS 1.00 TFO-90.00 7,900.00 55.00 257.65 4,943.54 4,894.35 -470.37 -5,455.11 6,003,378.06 382,434.89 1.00 -2,987.84 8,000.00 55.02 256.43 5,000.89 4,951.70 -488.74 -5,534.94 6,003,360.89 382,354.80 1.00 -3,022.52 8,100.00 55.04 255.21 5,058.20 5,009.01 -508.81 -5,614.39 6,003,342.02 382,275.06 1.00 -3,055.62 8,200.00 55.08 253.99 5,115.47 5,066.28 -530.57 -5,693.42 6,003,321.45 382,195.72 1.00 -3,087.12 8,300.00 55.13 252.78 5,172.68 5,123.49 -554.03 -5,772.02 6,003,299.18 382,116.79 1.00 -3,117.03 8,400.00 55.20 251.56 5,229.80 5,180.61 -579.16 -5,850.15 6,003,275.22 382,038.29 1.00 -3,145,33 8,500.00 55.27 250.35 5,286.82 5,237.63 -605.97 -5,927.80 6,003,249.58 381,960.26 1.00 -3,172.01 8,583.14 55.34 249.34 5,334.15 5,284.96 -629.53 -5,991.97 6,003,227.00 381,895.74 1.00 -3,192.95 Start DLS 3.10 TFO-111.00 8,600.00 55.16 248.74 5,343.76 5,294.57 -634.48 -6,004.91 6,003,222.24 381,882.74 3.10 -3,197.01 8,700.00 54.12 245.16 5,401.65 5,352.46 -666.38 -6,079.93 6,003,191.47 381,807.25 3.10 -3,218.06 8,800.00 53.18 241.49 5,460.93 5,411.74 -702.51 -6,151.89 6,003,156.43 381,734.76 3.10 -3,233.89 8,900.00 52.37 237.74 5,521.44 5,472.25 -742.76 -6,220.56 6,003,117.22 381,665.50 3.10 -3,244.46 9,000.00 51.67 233.90 5,583.00 5,533.81 -787.02 -6,285.75 6,003,073.95 381,599.66 3.10 -3,249.72 9,100.00 51.10 230.00 5,645.42 5,596.23 -835.15 -6,347.27 6,003,026.75 381,537.43 3.10 -3,249.66 9,200.00 50.66 226.05 5,708.52 5,659.33 -887.01 -6,404.94 6,002,975.76 381,478.99 3.10 -3,244.30 9,300.00 50.36 222.05 5,772.13 5,722.94 -942.46 -6,458.58 6,002,921.13 381,424.53 3.10 -3,233.63 9,400.00 50.20 218.02 5,836.05 5,786.86 -1,001.33 -6,508.04 6,002,863.02 381,374.19 3.10 -3,217.69 9,500.00 50.18 213.99 5,900.09 5,850.90 -1,063.45 -6,553.18 6,002,801.59 381,328.13 3.10 -3,196.54 9,600.00 50.29 209.96 5,964.07 5,914.88 -1,128.63 -6,593.87 6,002,737.03 381,286.47 3.10 -3,170.22 9,700.00 50.55 205.95 6,027.80 5,978.61 -1,196.69 -6,629.98 6,002,669.53 381,249.35 3.10 -3,138.82 9,800.00 50.94 201.98 6,091.10 6,041.91 -1,267.42 -6,661.41 6,002,599.28 381,216.86 3.10 -3,102.43 9,900.00 51.46 198.06 6,153.77 6,104.58 -1,340.62 -6,688.07 6,002,526.49 381,189.11 3.10 -3,061.16 10,000.00 52.11 194.20 6,215.64 6,166.45 -1,416.08 -6,709.87 6,002,451.38 381,166.17 3.10 -3,015.12 10,100.00 52.89 190.42 6,276.53 6,227.34 -1,493.57 -6,726.76 6,002,374.15 381,148.12 3.10 -2,964.46 10,200.00 53.78 186.71 6,336.25 6,287.06 -1,572.87 -6,738.69 6,002,295.05 381,135.01 3.10 -2,909.31 10,300.00 54.79 183.10 6,394.64 6,345.45 -1,653.75 -6,745.62 6,002,214.29 381,126.86 3.10 -2,849.85 10,388.41 55.77 179.99 6,445.00 6,395.81 -1,726.37 -6,747.57 6,002,141.72 381,123.83 3.10 -2,793.82 Start 664.80 hold at 10388.41 MD 10,400.00 55.77 179.99 6,451.52 6,402.33 -1,735.96 -6,747.57 6,002,132.13 381,123.68 0.00 -2,786.26 10,500.00 55.77 179.99 6,507.78 6,458.59 -1,818.63 -6,747.55 6,002,049.47 381,122.46 0.00 -2,721.10 10,550.50 55.77 179.99 6,536.19 6,487.00 -1,860.38 -6,747.54 6,002,007.73 381,121.84 0.00 -2,688.20 Top HRZ 10,600.00 55.77 179.99 6,564.04 6,514.85 -1,901.31 -6,747.53 6,001,966.82 381,121.24 0.00 -2,655.94 10,700.00 55.77 179.99 6,620.30 6,571.11 -1,983.98 -6,747.51 6,001,884.16 381,120.02 0.00 -2,590.78 3/21/2011 11:49:26AM Page 3 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Rig:CD3-125 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Rig:CD3-125 @ 49.19ft(D19) Project: Western North Slope MD Reference: Rig:CD3-125 @ 49.19ft(D19) Site: CD3 Fiord Pad North Reference: True Well: Rig:CD3-125 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-125 Design: CD3-125wp09 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +EI-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 6,627.36 10,800.00 55.77 179.99 6,676.55 6,627.36 -2,066.65 -6,747.49 6,001,801.50 381,118.79 0.00 -2,525.62 10,810.02 55.77 179.99 6,682.19 6,633.00 -2,074.94 -6,747.49 6,001,793.22 381,118.67 0.00 -2,519.10 Base HRZ/Top Kalubik 10,900.00 55.77 179.99 6,732.81 6,683.62 -2,149.33 -6,747.47 6,001,718.84 381,117.57 0.00 -2,460.46 11,000.00 55.77 179.99 6,789.07 6,739.88 -2,232.00 -6,747.45 6,001,636.18 381,116.35 0.00 -2,395.30 11,041.10 55.77 179.99 6,812.19 6,763.00 -2,265.98 -6,747.44 6,001,602.21 381,115.85 0.00 -2,368.52 Base Kalubik 11,053.20 55.77 179.99 6,819.00 6,769.81 -2,275.99 -6,747.44 6,001,592.21 381,115.70 0.00 -2,360.64 Start DLS 5.41 TFO-24.83 11,100.00 58.07 178.73 6,844.54 6,795.35 -2,315.19 -6,747.00 6,001,553.00 381,115.55 5.41 -2,329.47 11,200.00 63.04 176.25 6,893.69 6,844.50 -2,402.15 -6,743.14 6,001,466.00 381,118.10 5.41 -2,258.57 11,300.00 68.04 173.98 6,935.09 6,885.90 -2,492.81 -6,735.36 6,001,375.25 381,124.52 5.41 -2,182.34 11,400.00 73.07 171.86 6,968.37 6,919.18 -2,586.34 -6,723.72 6,001,281.56 381,134.76 5.41 -2,101.47 11,500.00 78.13 169.86 6,993.24 6,944.05 -2,681.93 -6,708.32 6,001,185.75 381,148.71 5.41 -2,016.66 11,596.16 83.00 168.00 7,009.00 6,959.81 -2,774.99 -6,690.10 6,001,092.44 381,165.53 5.41 -1,932.12 Start 35.00 hold at 11596.16 MD-7"x 8-3/4" 11,600.00 83.00 168.00 7,009.47 6,960.28 -2,778.72 -6,689.31 6,001,088.70 381,166.27 0.00 -1,928.69 11,631.16 83.00 168.00 7,013.27 6,964.08 -2,808.97 -6,682.88 6,001,058.36 381,172.24 0.00 -1,900.89 Start DLS 6.31 TFO 0.00 11,700.00 87.34 168.00 7,019.06 6,969.87 -2,876.05 -6,668.62 6,000,991.08 381,185.49 6.31 -1,839.25 11,734.33 89.51 168.00 7,020.00 6,970.81 -2,909.61 -6,661.49 6,000,957.42 381,192.12 6.31 -1,808.42 Start DLS 2.00 TFO-90.11 11,800.00 89.51 166.69 7,020.56 6,971.37 -2,973.69 -6,647.10 6,000,893.14 381,205.54 2.00 -1,749.06 11,900.00 89.50 164.69 7,021.42 6,972.23 -3,070.58 -6,622.38 6,000,795.90 381,228.81 2.00 -1,657.50 12,000.00 89.50 162.69 7,022.29 6,973.10 -3,166.54 -6,594.29 6,000,699.53 381,255.45 2.00 -1,564.58 12,100.00 89.50 160.69 7,023.16 6,973.97 -3,261.47 -6,562.87 6,000,604.15 381,285.43 2.00 -1,470.44 12,200.00 89.50 158.69 7,024.03 6,974.84 -3,355.24 -6,528.16 6,000,509.88 381,318.73 2.00 -1,375.17 12,300.00 89.50 156.69 7,024.91 6,975.72 -3,447.74 -6,490.20 6,000,416.82 381,355.30 2.00 -1,278.90 12,400.00 89.50 154.69 7,025.78 6,976.59 -3,538.87 -6,449.03 6,000,325.10 381,395.09 2.00 -1,181.75 12,500.00 89.50 152.69 7,026.66 6,977.47 -3,628.50 -6,404.70 6,000,234.82 381,438.06 2.00 -1,083.83 12,600.00 89.50 150.69 7,027.53 6,978.34 -3,716.52 -6,357.27 6,000,146.10 381,484.16 2.00 -985.27 12,700.00 89.50 148.69 7,028.40 6,979.21 -3,802.84 -6,306.80 6,000,059.04 381,533.32 2.00 -886.18 12,800.00 89.51 146.69 7,029.27 6,980.08 -3,887.35 -6,253.35 5,999,973.75 381,585.49 2.00 -786.68 12,900.00 89.51 144.69 7,030.13 6,980.94 -3,969.94 -6,196.98 5,999,890.33 381,640.61 2.00 -686.89 12,987.75 89.51 142.93 7,030.88 6,981.69 -4,040.75 -6,145.17 5,999,818.75 381,691.35 2.00 -599.19 12,987.94 89.51 142.93 7,030.88 6,981.69 -4,040.91 -6,145.06 5,999,818.59 381,691.46 0.00 -599.00 Start 5900.54 hold at 12987.94 MD 13,000.00 89.51 142.93 7,030.98 6,981.79 -4,050.52 -6,137.79 5,999,808.87 381,698.58 0.00 -586.94 13,100.00 89.51 142.93 7,031.84 6,982.65 -4,130.31 -6,077.51 5,999,728.19 381,757.65 0.00 -486.96 13,200.00 89.51 142.93 7,032.69 6,983.50 -4,210.10 -6,017.24 5,999,647.51 381,816.72 0.00 -386.98 13,300.00 89.51 142.93 7,033.54 6,984.35 -4,289.89 -5,956.96 5,999,566.84 381,875.78 0.00 -286.99 13,400.00 89.51 142.93 7,034.39 6,985.20 -4,369.67 -5,896.69 5,999,486.16 381,934.85 0.00 -187.01 13,500.00 89.51 142.93 7,035.25 6,986.06 -4,449.46 -5,836.41 5,999,405.48 381,993.91 0.00 -87.03 13,600.00 89.51 142.93 7,036.10 6,986.91 -4,529.25 -5,776.13 5,999,324.81 382,052.98 0.00 12.96 13,700.00 89.51 142.93 7,036.95 6,987.76 -4,609.04 -5,715.86 5,999,244.13 382,112.05 0.00 112.94 3/21/2011 11:49:26AM Page 4 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips HALLIBURTDN Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Rig:CD3-125 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Rig:CD3-125 @ 49.19ft(D19) Project: Western North Slope MD Reference: Rig:CD3-125 @ 49.19ft(D19) Site: CD3 Fiord Pad North Reference: True Well: Rig:CD3-125 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-125 Design: CD3-125wp09 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E(-W Northing Easting DLS Veil Section (ft) (°) (0) (ft) ft (ft) (ft) (ft) (ft) 6,988.61 13,800.00 89.51 142.93 7,037.80 6,988.61 -4,688.83 -5,655.58 5,999,163.45 382,171.11 0.00 212.92 13,900.00 89.51 142.93 7,038.66 6,989.47 -4,768.61 -5,595.31 5,999,082.78 382,230.18 0.00 312.90 14,000.00 89.51 142.93 7,039.51 6,990.32 -4,848.40 -5,535.03 5,999,002.10 382,289.24 0.00 412.89 14,100.00 89.51 142.93 7,040.36 6,991.17 -4,928.19 -5,474.75 5,998,921.42 382,348.31 0.00 512.87 14,200.00 89.51 142.93 7,041.21 6,992.02 -5,007.98 -5,414.48 5,998,840.74 382,407.38 0.00 612.85 14,300.00 89.51 142.93 7,042.07 6,992.88 -5,087.76 -5,354.20 5,998,760.07 382,466.44 0.00 712.84 14,400.00 89.51 142.93 7,042.92 6,993.73 -5,167.55 -5,293.93 5,998,679.39 382,525.51 0.00 812.82 14,500.00 89.51 142.93 7,043.77 6,994.58 -5,247.34 -5,233.65 5,998,598.71 382,584.57 0.00 912.80 14.600.00 89.51 142.93 7,044.63 6,995.44 -5,327.13 -5,173.37 5,998,518.04 382,643.64 0.00 1,012.79 14,700.00 89.51 142.93 7,045.48 6,996.29 -5,406.92 -5,113.10 5,998,437.36 382,702.71 0.00 1,112.77 14,800.00 89.51 142.93 7,046.33 6,997.14 -5,486.70 -5,052.82 5,998,356.68 382,761.77 0.00 1,212.75 14,900.00 89.51 142.93 7,047.18 6,997.99 -5,566.49 -4,992.55 5,998,276.01 382,820.84 0.00 1,312.74 15,000.00 89.51 142.93 7,048.04 6,998.85 -5,646.28 -4,932.27 5,998,195.33 382,879.90 0.00 1,412.72 15,100.00 89.51 142.93 7,048.89 6,999.70 -5,726.07 -4,871.99 5,998,114.65 382,938.97 0.00 1,512.70 15,200.00 89.51 142.93 7,049.74 7,000.55 -5,805.85 -4,811.72 5,998,033.97 382,998.03 0.00 1,612.69 15,300.00 89.51 142.93 7,050.59 7,001.40 -5,885.64 -4,751.44 5,997,953.30 383,057.10 0.00 1,712.67 15,400.00 89.51 142.93 7,051.45 7,002.26 -5,965.43 -4,691.17 5,997,872.62 383,116.17 0.00 1,812.65 15,500.00 89.51 142.93 7,052.30 7,003.11 -6,045.22 -4,630.89 5,997,791.94 383,175.23 0.00 1,912.64 15,600.00 89.51 142.93 7,053.15 7,003.96 -6,125.00 -4,570.61 5,997,711.27 383,234.30 0.00 2,012.62 15,700.00 89.51 142.93 7,054.01 7,004.82 -6,204.79 -4,510.34 5,997,630.59 383,293.36 0.00 2,112.60 15,800.00 89.51 142.93 7,054.86 7,005.67 -6,284.58 -4,450.06 5,997,549.91 383,352.43 0.00 2,212.58 15,900.00 89.51 142.93 7,055.71 7,006.52 -6,364.37 -4,389.79 5,997,469.24 383,411.50 0.00 2,312.57 16,000.00 89.51 142.93 7,056.56 7,007.37 -6,444.16 -4,329.51 5,997,388.56 383,470.56 0.00 2,412.55 16,100.00 89.51 142.93 7,057.42 7,008.23 -6,523.94 -4,269.23 5,997,307.88 383,529.63 0.00 2,512.53 16,200.00 89.51 142.93 7,058.27 7,009.08 -6,603.73 -4,208.96 5,997,227.21 383,588.69 0.00 2,612.52 16,300.00 89.51 142.93 7,059.12 7,009.93 -6,683.52 -4,148.68 5,997,146.53 383,647.76 0.00 2,712.50 16,400.00 89.51 142.93 7,059.97 7,010.78 -6,763.31 -4,088.41 5,997,065.85 383,706.83 0.00 2,812.48 16,500.00 89.51 142.93 7,060.83 7,011.64 -6,843.09 -4,028.13 5,996,985.17 383,765.89 0.00 2,912.47 16,600.00 89.51 142.93 7,061.68 7,012.49 -6,922.88 -3,967.85 5,996,904.50 383,824.96 0.00 3,012.45 16,700.00 89.51 142.93 7,062.53 7,013.34 -7,002.67 -3,907.58 5,996,823.82 383,884.02 0.00 3,112.43 16,800.00 89.51 142.93 7,063.39 7,014.20 -7,082.46 -3,847.30 5,996,743.14 383,943.09 0.00 3,212.42 16,900.00 89.51 142.93 7,064.24 7,015.05 -7,162.24 -3,787.03 5,996,662.47 384,002.16 0.00 3,312.40 17,000.00 89.51 142.93 7,065.09 7,015.90 -7,242.03 -3,726.75 5,996,581.79 384,061.22 0.00 3,412.38 17,100.00 89.51 142.93 7,065.94 7,016.75 -7,321.82 -3,666.47 5,996,501.11 384,120.29 0.00 3,512.37 17,200.00 89.51 142.93 7,066.80 7,017.61 -7,401.61 -3,606.20 5,996,420.44 384,179.35 0.00 3,612.35 17,300.00 89.51 142.93 7,067.65 7,018.46 -7,481.40 -3,545.92 5,996,339.76 384,238.42 0.00 3,712.33 17,400.00 89.51 142.93 7,068.50 7,019.31 -7,561.18 -3,485.65 5,996,259.08 384,297.49 0.00 3,812.32 17,500.00 89.51 142.93 7,069.35 7,020.16 -7,640.97 -3,425.37 5,996,178.40 384,356.55 0.00 3,912.30 17,600.00 89.51 142.93 7,070.21 7,021.02 -7,720.76 -3,365.09 5,996,097.73 384,415.62 0.00 4,012.28 17,700.00 89.51 142.93 7,071.06 7,021.87 -7,800.55 -3,304.82 5,996,017.05 384,474.68 0.00 4,112.27 17,800.00 89.51 142.93 7,071.91 7,022.72 -7,880.33 -3,244.54 5,995,936.37 384,533.75 0.00 4,212.25 17,900.00 89.51 142.93 7,072.77 7,023.58 -7,960.12 -3,184.27 5,995,855.70 384,592.81 0.00 4,312.23 18,000.00 89.51 142.93 7,073.62 7,024.43 -8,039.91 -3,123.99 5,995,775.02 384,651.88 0.00 4,412.21 18,100.00 89.51 142.93 7,074.47 7,025.28 -8,119.70 -3,063.71 5,995,694.34 384,710.95 0.00 4,512.20 18,200.00 89.51 142.93 7,075.32 7,026.13 -8,199.48 -3,003.44 5,995,613.67 384,770.01 0.00 4,612.18 3/21/2011 11:49:26AM Page 5 COMPASS 2003.16 Build 69 ORIGINAL • • ConocoPhillips HALLIBURTOIV Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Rig:CD3-125 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Rig:CD3-125 @ 49.19ft(D19) Project: Western North Slope MD Reference: Rig:CD3-125©49.19ft(D19) Site: CD3 Fiord Pad North Reference: True Well: Rig:CD3-125 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-125 Design: CD3-125wp09 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (0) (°) (ft) ft (ft) (ft) (ft) (ft) 7,026.99 18,300.00 89.51 142.93 7,076.18 7,026.99 -8,279.27 -2,943.16 5,995,532.99 384,829.08 0.00 4,712.16 18,400.00 89.51 142.93 7,077.03 7,027.84 -8,359.06 -2,882.89 5,995,452.31 384,888.14 0.00 4,812.15 18,500.00 89.51 142.93 7,077.88 7,028.69 -8,438.85 -2,822.61 5,995,371.63 384,947.21 0.00 4,912.13 18,600.00 89.51 142.93 7,078.73 7,029.54 -8,518.64 -2,762.33 5,995,290.96 385,006.28 0.00 5,012.11 18,700.00 89.51 142.93 7,079.59 7,030.40 -8,598.42 -2,702.06 5,995,210.28 385,065.34 0.00 5,112.10 18,800.00 89.51 142.93 7,080.44 7,031.25 -8,678.21 -2,641.78 5,995,129.60 385,124.41 0.00 5,212.08 18,887.92 89.51 142.93 7,081.19 7,032.00 -8,748.36 -2,588.79 5,995,058.67 385,176.34 0.00 5,299.99 CD3-I 25May10 Toe Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting ' -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) CD3-I 25May10 Toe 0.00 0.00 7,081.19 -8,748.36 -2,588.79 5,995,058.67 385.176.34 -plan hits target center -Circle(radius 100.00) CD3-I 20Mar11 Heel 0.00 7,009.00 -2,774.38 -6,690.29 6,001,093.06 381,165.35 -plan hits target center -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name C') C') 2,961.48 2,464.31 9-5/8"x 12-1/4" 9-5/8 12-1/4 11,596.16 7,009.00 7"x 8-3/4" 7 8-3/4 18,888.49 7,081.19 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 (0) (0) 10,550.50 6,536.19 Top HRZ 0.00 10,810.02 6,682.19 Base HRZ/Top Kalubik 0.00 11,041.10 6,812.19 Base Kalubik 0.00 3/21/2011 11:49:26AM Page 6 COMPASS 2003.16 Build 69 ORG1NAL • ConocoPhillips H A L LI URTDN Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Rig:CD3-125 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Rig:CD3-125 @ 49.19ft(D19) Project: Western North Slope MD Reference: Rig:CD3-125 @ 49.19ft(D19) Site: CD3 Fiord Pad North Reference: True Well: Rig:CD3-125 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-125 Design: CD3-125wp09 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 7,500.00 4,731.42 -412.06 -5,121.48 KOP:DLS 1.50 TFO-90.00 7,550.00 4,756.08 -417.54 -5,164.63 Start DLS 2.50 TFO-90.00 7,600.00 4,780.74 -423.88 -5,207.66 Start DLS 2.50 TFO-160.00 7,833.14 4,905.19 -459.04 -5,401.53 Start DLS 1.00 TFO-90.00 8,583.14 5,334.15 -629.53 -5,991.97 Start DLS 3.10 TFO-111.00 10,388.41 6,445.00 -1,726.37 -6,747.57 Start 664.80 hold at 10388.41 MD 11,053.20 6,819.00 -2,275.99 -6,747.44 Start DLS 5.41 TFO-24.83 11,596.16 7,009.00 -2,774.99 -6,690.10 Start 35.00 hold at 11596.16 MD 11,631.16 7,013.27 -2,808.97 -6,682.88 Start DLS 6.31 TFO 0.00 11,734.33 7,020.00 -2,909.61 -6,661.49 Start DLS 2.00 TFO-90.11 12,987.94 7,030.88 -4,040.91 -6,145.06 Start 5900.54 hold at 12987.94 MD 18,888.49 TD at 18888.49 3/21/2011 11:49:26AM Page 7 COMPASS 2003.16 Build 69 OkGtNAL ZN m 0 : H w I 3 _ M oJ J > QL L m Ia N CON Z 2. 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N L 0)M 0 __ D OF s$ As a. o L 0$g84ri rn F 0 1 ORIGINAL 1 HALLIBURTON ConocoPhillips CD3-125wp09 Alaska Sperry Drilling ANTI-COLLISION SETTINGS 11:59,March 202011 Interpolation Method: MD, interval: 25.00 Depth Range From: 7500.00 To 18888.49 Results Limited By: Centre Distance:2085.19 GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 85.06 868.06 Rig:CD3-125PB1 Gyro(R100)(Rig:CD3-125 p 962.29 2931.22 Rig:CD3-125PB1 MWD(R100)(Rig:CD3-129R'elDWRied9CAZ-SC 2998.33 7500.00 CD3-125PB1 MWD(R500)(Rig:CD3-125PB1MWD+IFR-AK-CAZ-SC 7500.00 11596.16 CD3-125wp09(Plan: CD3-125) MWD+IFR-AK-CAZ-SC 11596.16 18888.49 CD3-125w1 09(Plan: CD3-125) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2464.31 2961.48 9-5/8"x 12-1/4" 9-5/8 7009.00 11596.16 7"x 8-3/4" 7 7081.19 18888.49 3-1/2"x 6-1/8" 3-1/2 U a, CL - O) U JII 30 - 0) c a) U - A 0l i l l l l i l l i 7500 9000 10500 12000 13500 15000 16500 Measured Depth LEGEND -X- CD3-112,CD3-112,CD3-112 V3 CD3-123,CD3-123,CO3-123 VO -A- Plan:CD3-120,Plan:CD3-120,CD3-120wp06 VO CD3-113,CD3-113,CD3-113 V6 CD3-124,CD3-124,CD3-124 VO Plan:CD3-126,Plan:CD3-126,CD3-126wp04 VO - CO3-114,CD3-114,CD3-114 V14 -4- CD3-127,CD3-127PB1,CD3-127PB1 VO -0- Plan:CD3-128,Plan:CD3-128,CD3-128wp03 V0 CO3.115,CD3-115,CD3-115 VO -$- CD3-127,Plan:CD3-127,CD3-127wp05 VO -X- Plan:CD3-129,Plan:CD3-129,CD3-129wp01 VO -9- CD3-117,CD3-117,CD3-117 VO • CD3-316,CD3-316,CD3-316 VO $ Rig:CD3-125,Rig:CD3-125PB1,Rig CD3-125PB1 VO --(- CD3-118,CD3-118,CD3-118 VO -e- CD3-316,CD3-316A,CD3-316A V0 -0- Rig:CD3-125,Rig:CD3-125PB1(surface),Rig CD3-125PB1(surface)VO -9'- CD3-121,CD3-121,CD3-121 VO CD3-316,CD3316APB1,CD3316APB1 VO -g- CD3-125wp09 -9- CD3-122,CD3-122,CD3-122 VO -- Ran:CD3-119,Plan:CD3-119,CD3-119wp07 VO ORIGINAL Northing (4000 ft/in) 111111 11III1I111111111111111111111111111111111111111111111111111i LII I - - q R f - r — m 1 Q M - <G3 i}43 CC C) - 0 — c? 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" -- 88 X88 o t2 o m F 'A . g s s s E a rc o 88888888888E8o8 o _ r N $ 8 8 8 8 " 0 88888 2bA$ � � vasa 8 u y'u u o o y o Sou oo o'o o 0 o s s y s s y s rc¢ 0 1E s o $ *T���T�01�+;b+04.1404 � N 6 C 8 T. 3 i Vl W O O w 8 8 8 8 8 ° o 0 ari gas c N 4,0111 O 188sss a m 0 a) o co Lu0 d C ‹ 88888 8 8 0 Lu 0 t 0 8 8 8 8 II c -411k - ..... 03 o °r e 8 8 8 8 NN r r n `,1.' O w H r 01 0 E o N en_ 35 j • ,!" ggIn 0 lig g 0, v U . o ra pr ORIGINALN c O1i C Tu Ma rnO 48'48V Qg VN • 4sras Page 1 of 4 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, March 22, 2011 11:07 AM To: 'Anderson, Nina M' Subject: RE: CD3-125 Cut and cement 7" Casing (PTD 210-189) Nina, You have verbal approval to proceed with your planned Sidetrack on CD3-125 using the upper cement plug set from 7721-7350' and as your kickoff. Please submit the PTD revision as soon as possible. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Anderson, Nina M [mailto:Nina.Anderson@conocophillips.com] Sent: Tuesday, March 22, 2011 10:55 AM To: Schwartz, Guy L(DOA) Subject: RE: CD3-125 Cut and cement 7" Casing (PTD 210-189) Guy -We successfully set the second KOP yesterday with good pressures and returns. This plug was placed from 7721' to 7350' MD. Doyon 19 completed the BOPE testing this morning. Doyon 19 is currently proceeding with picking up the sidetrack BHA. ConocoPhillips is currently working on a revised PTD which should be submitted by the end of today. Pending a verbal approval, Conocophillips would like to proceed with drilling the sidetrack hole at the KOP of 7500' MD. Thanks. Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907)-265-6403 Cell: (907)229-4008 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, March 22, 2011 8:41 AM To: Anderson, Nina M Cc: Davies, Stephen F (DOA) Subject: RE: CD3-125 Cut and cement 7" Casing (PTD 210-189) Nina, Thanks for the update on the cement plugging. I checked and you will have to submit a revised PTD application or the new sidetrack since it has a segment that is 700' away from the permitted wellbore. . It only needs to include the cover page 401 sheet and a copy of the new directional. Please mark the 401 with "Revised" on the top. Regards, 4/1/2011 Page 2 of 4 Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Anderson, Nina M [mailto:Nina.Anderson@conocophillips.com] Sent: Monday, March 21, 2011 11:52 AM To: Schwartz, Guy L (DOA) Cc: Davies, Stephen F (DOA) Subject: RE: CD3-125 Cut and cement 7" Casing (PTD 210-189) Guy - The first cement plug was set at 10,808' MD early this morning for abandonment of CD3-125. The balanced plug was set with good returns. Currently the rig is in process of setting the second KOP at 7750' MD. The new sidetrack plan has been drafted. The heel target will be — 700' from the original permitted to drill heel. The plan will eventually meet up the original lateral toe. I've attached the proposed wellplan for CD3-127. Please advise if a new permit to drill needs to be generated. To clarify, the sidetrack will keep the name of CD3-125 and maintain API: 50-103-20632-00-00. The abandoned wellbore will be CD3-125PB1 and have API 50-103-20632-70-00. Thanks. Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907)-265-6403 Cell: (907)229-4008 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, March 21, 2011 8:55 AM To: Anderson, Nina M Subject: RE: CD3-125 Cut and cement 7" Casing (PTD 210-189) Nina, As follow-up to our phone call on Saturday I think I forgot to answer your question about needing a sundry. It will not be required. Your proposal as stated below is acceptable. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 4/1/2011 Page 3 of 4 From: Anderson, Nina M [mailto:Nina.Anderson@conocophillips.com] Sent: Saturday, March 19, 2011 2:11 PM To: Schwartz, Guy L (DOA) Subject: RE: CD3-125 Cut and cement 7" Casing (PTD 210-189) Guy - The crews on Doyon 19 were eventually able to free the 7" casing and have begun pulling operations. Currently we have about 180 joints to go. Based on our unsuccessful attempts at a clean out run on the adjacent well CD3-127, we would like to propose running in with a 3-1/2" cement stinger to just above the HRZ to lay in an abandonment plug. This plug will be 15.8 ppg with a viscous plug placed below. Proposed top is 10,400' MD and bottom is 10,800' MD which is just above the HRZ. The cement volumes for this lower plug have a 40% excess included, therefore there is a potential for it to be a 700' plug. The second plug will be set from 7750' -7350' MD for a 400' total KOP. The KOP depth is 7500' MD. This second plug is below the Qannik reservoir which is 6124' MD. The depth of the KOP will be recorded when we run into make a tag. UPDATED Plan forward is as follows: • Pull 7" Casing • RIH with 3-1/2"cement stinger and place 15.8 ppg abandonment plug on top of HRZ with the base 10,800' MD. • Pump viscous plug, followed by 400' cement to 10,400' MD. • Pull uphole to sidetrack point and set KOP with viscous plug below. Bottom cement is planned for 7750' MD and top cement is 7350' MD. • Both plugs will be above the Nechelik/Kuparuk formations and the upper Qannik section (6124' MD) • RIH and kickoff with rotary steerable Please let me know if you have any questions or concerns with our proposed operation. Also please advise if a Sundry needs to be submitted on Monday. Currently the new sidetrack plan is within the 500' radius of the original permitted plan. Thanks, Nina Anderson Senior Drilling Engineer Alpine 907-229-4008 ina M 18,2011 4:05 PM L(DOA) 15 Cut and cement 7"Casing(PTD 210-189) Guy - Doyon 19 is currently having difficulties running the 7" intermediate casing string on CD3-125. We are unable to circulate or move casing. After working the pipe since early this morning, the decision has been made to cut casing, plug back the hole, and sidetrack above the stuck point. Plan forward is as follows: • RIH with Halliburton string shot and cut casing — 100' above the top of HRZ at 10,800' MD • Pull 7" Casing • RIH with 3-1/2"cement stinger and place 15.8 ppg abandonment plug on top of 7"casing stub • Pull uphole to sidetrack point and set KOP • RIH and kickoff with motor or rotary steerable • Contingency if casing does not come free at first point, will move up hole and make a second cut below the Qannik. 4/1/2011 Page 4 of 4 ConocoPhillips intentions are to save the upper hole and sidetrack below the Qannik. Thanks. Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907)-265-6403 Cell: (907)229-4008 .i)3-125 PTD (210-181 Plug Back Schematic RKB - GL = 36.3' 3/19/2011 K Wellhead 16" Conductor to 114' 10.5 ppg mud in ' hole 10-3/4"40 ppf L-80 BTCM . 1 iiiii Surface Casing 2953' MD/2,462' TVD J Cemented to Surface Sidetrack KOP at 7500'MD. Too Qannik Below the Qannik and above the 6124' MD 14026'TVD cement plug Top of Plug#2 Mk::. •:E!. •:! •.!E: • DwtSG 7350' MD `1g l� Bottom of Plug #2 pT 7750' MD biar S Top of Plug#1 E . ':i 10,400' MD €M.4 11' Too HRZ WiTiliCiin Bottom of Plug#1 10.877' MD/6491'TVD 10,800' MD Co/%.pIt Aet� Base HRZ 11.228' MD/6682'TVD 7" Casing shoe stuck at 11,475' MD '-----4 iPX 00 tf Top Kuparuk C 11.678' MD I 6813'TVD Top Nechelik 12.673' MDI 6999'TVD 8-3/4" Intermediate Hole TD of hole at+/- 12,754' MD/7007'TVD TRANSMITTAL LETTER CHECKLIST WELL NAME e',E'L/ CAS-,!o?.S PTD#/ Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: :OGI/LGA 'j' 4*YPOOL: #QC0 c7 ASL Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability 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 through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and 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 program. 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W RD co Vt .Z 0- y i0 ,a 0 CO CO :O O �. m i .� • 0 y ,O . > 0' '- �v' F 0 0 00 ,� 3 < �0 ,m ,-0 .N n .y 01 'O 7 co co a a 0 N p 'O .* 1.) CD -0 thu 77 .N 0 p N a v a ;a f a 3 7 . = n o a( a o = .n � o � 1:3 CD 0 b: . n : ow * p o a Tr., o . o 0 o co moor C a 'o x .7 .7 _ 0) 0. 7) CD CO CO St 3a co co C)43 sis7 o v . iii � n z . . o 7 O 3 a .o Dp O Cifi (n . a r m co w c < .3 0 o co 0 o a o o . 3 c_ � O CI m - co fl p N ' Y DIF A1La SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMDIISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Ryan Robertson Alpine Drilling Engineerw ...- q6C1- ConocoPhillips Alaska, Inc. ( \, P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-125 Sundry Number: 311-034 Dear Mr. Robertson: 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, /9;_er,(4_,Cathy '. Foerster Commissioner v� DATED this � day of February, 2011. Encl. • t 1 lyan Robertson Alpine Drilling Engineer Drilling&Wells P.0.Box 100360 /11PV. Anchorage,AK 99510-0360 ConocoPhi I I i ps Phone: 907-265-6318 February 14, 2011 Commissioner State of Alaska }' Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Ur .;swn Subject: Application for Sundry Approval CD3-125 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the operational shutdown of the Alpine well CD3-125. i ConocoPhillips Alaska released Doyon Rig 141 from the CD3-125 well on February 6th, 2011. The 12.25" surface hole had been drilled to the planned depth of 2,966' MD / 2,462' TVD, followed by a successful 9-5/8" casing run and cement job. Once cementing operations had concluded, the 9-5/8" surface casing was successfully pressure tested to 3,500 psi for 30 minutes to prove its integrity. A 3.5" kill string was then ran in the hole to 2,833' MD and landed in the tubing hanger. At that point the tree was made up and pressure tested, prior to displacing the 10.0 ppg spud mud from the hole. The well was then freeze protected with 132 bbl of diesel, and secured by setting a BPV. The original plan was to complete the intermediate section of CD3-125 with Doyon 141, however due to ice road delays, the schedule was modified and Doyon 19 will now move in to drill the intermediate and lateral sections of this hole once it has completed - the CD3-127 well. If you have any questions regarding this matter, please contact me at 265-6318. Sincerely, R. Robertson Alpine Drilling Engineer • STATE OF ALASKA OA- , t APPLICATION FOR SUNDRY APPROVALS ' '' ' I' `l 2 41,400°.k` 20 AAC 25.280 1.Type of Request: Abandon r Flug for Redrifi r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Rill Tubing r Time Extension r Operational Shutdown 17. Re-enter Susp.Well r Stimulate r Alter casing r Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 7 • Exploratory r 210-189 • 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20632-00 • 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 r No 17 CD3-125 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 372105,25538 • Colville River Field/Fiord Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 2966' 2462' 2833' 2323' Casing Length Size MD ND Burst Collapse Conductor 80' 16" 114' 114' Surface 2920' 9.625" 2953' 2443' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): none none 3.5"kill string tbg L-80 2833' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) no packer no SSSV 12.Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/62011 Oil P • Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r 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: Ryan Robertson @ 265-6318 Printed Name Ryan Robertson Title: Alpine Drilling En'neer ./ Signature Signature / Phone:265-6318 Date 02,/Y,it Commission Use Only l I Sundry Number: ( �13// / Conditions of approval: Notify Commission so that a representative may witness . --�� ): Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: - E.iaLl no•f-t F-4• 'oN /c-t S1 " /d a/0er. Lvov'''. t- --E. , !j u dri01.,,,e iPf h s>LI pJ ;0hS. 4.P,47 cJ recta.,-74-.I' r i, 3r. .E' s skin Subsequent Form Required: ray( lotjeji /0-Y 0 7 - ., ru / / APPROVED BY Approved by: 9g (Li _— COMMISSIONER IGINALTHE COMMISSION Date: 2- 2-2- j Form 10-403 Revi�: • Page 1 of 2 Schwartz, Guy L (DOA) From: Robertson, Ryan G [Ryan.G.Robertson@conocophillips.com] Sent: Tuesday, February 15, 2011 10:32 AM To: Schwartz, Guy L(DOA) Subject: RE: CD3-125 Temporary Suspension (PTD 210-189) Guy, The sundry for operational shutdown on CD3-125 was filed this morning as per 20 ACC 25.072 (a). Doyon 19 is currently drilling the CD3-127 well, with the current rig schedule putting the rig back on CD3-125 during the second week of March. Doyon 19 will then drill the intermediate and lateral hole sections before completing the well as per the original permit to drill. Please correct me if I'm wrong, but to re-enter this well, a 10-403 sundry to restart operations is not required. It is my understanding that operations will revert back to the original PTD (210-189) including BOP testing requirements. As well, prior to operations beginning, an email notification is to be sent outlining the re-entry plan will be required. Thanks, Ryan From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, February 02, 2011 3:08 PM To: Robertson, Ryan G Cc: DOA AOGCC Prudhoe Bay Subject: RE: CD3-125 Temporary Suspension (PTD 210-189) Ryan, Your proposal looks fine as stated below. I cc'd the inspectors so they know your plan. We won't expect a full blown BOP test on Doyon 141 until the next well you move to. It is my understanding that Doyon 19 will be finishing the well sometime later in this 2011 drilling season. Be sure and submit a sundry for the operational shutdown as per 20 AAC 25.072 (a) Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Robertson, Ryan G [mailto:Ryan.G.Robertson@conocophillips.com] Sent: Wednesday, February 02, 2011 2:39 PM To: Schwartz, Guy L (DOA) Subject: CD3-125 Temporary Suspension (PTD 210-189) Guy 2/16/2011 . - Page 2 of 2 • CPAI proposes to temporarily suspend the CD3-125 well after drilling, casing and cementing the 12.25"surface interval with Doyon 141. As per our conversation, the following steps will be followed to ensure the wellbore is competent and sufficient barriers are in place while running the 3.5" kill string used to suspend the well. 1. Pressure test 12.25" surface casing to 3,500 psi for 30 minutes after cement plug bumps with 10.0 ppg spud mud. 2. Nipple down surface riser. 3. Nipple up wellhead and test to 1,000 psi 4. Rig up BOP. 5. Set 3.5"test plug. 6. Body test BOP from annular preventer down to 2,000 psi for 10 minutes—chart test. 7. Run 3.5" kill string to 2,000' MD. The original plan was to complete the intermediate section of CD3-125 with Doyon 141, however due to ice road delays, the schedule has been modified and Doyon 19 will now move in to drill the intermediate and lateral sections of this hole. Ryan Drilling Engineer;CanocoPhillips Alaska Direct (907)265-63181 Mobile(907)980-5107 2/16/2011 Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, February 15, 2011 11:10 AM To: 'Robertson, Ryan G' Subject: RE: CD3-125 Temporary Suspension (PTD 210-189) Ryan, You are correct.... No sundry is required . you revert to the original PTD. Just send an email outlining your plan just before you rig up and commence operations again. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Robertson, Ryan G [mailto:Ryan.G.Robertson@conocophillips.com] Sent: Tuesday, February 15, 2011 10:32 AM To: Schwartz, Guy L (DOA) Subject: RE: CD3-125 Temporary Suspension (PTD 210-189) Guy, The sundry for operational shutdown on CD3-125 was filed this morning as per 20 ACC 25.072 (a). Doyon 19 is currently drilling the CD3-127 well, with the current rig schedule putting the rig back on CD3-125 during the second week of March. Doyon 19 will then drill the intermediate and lateral hole sections before completing the well as per the original permit to drill. Please correct me if I'm wrong, but to re-enter this well, a 10-403 sundry to restart operations is not required. It is my understanding that operations will revert back to the original PTD (210-189) including BOP testing requirements. As well, prior to operations beginning, an email notification is to be sent outlining the re-entry plan will be required. Thanks, Ryan From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, February 02, 2011 3:08 PM To: Robertson, Ryan G Cc: DOA AOGCC Prudhoe Bay Subject: RE: CD3-125 Temporary Suspension (PTD 210-189) Ryan, Your proposal looks fine as stated below. I cc'd the inspectors so they know your plan. We won't expect a full blown BOP test on Doyon 141 until the next well you move to. It is my understanding that Doyon 19 will be finishing the well sometime later in this 2011 drilling season. Be sure and submit a sundry for the operational shutdown as per 20 AAC 25.072 (a) 2/15/2011 Page 2 of 2 J Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Robertson, Ryan G [mailto:Ryan.G.Robertson@conocophillips.com] Sent: Wednesday, February 02, 2011 2:39 PM To: Schwartz, Guy L (DOA) Subject: CD3-125 Temporary Suspension (PTD 210-189) Guy CPAI proposes to temporarily suspend the CD3-125 well after drilling, casing and cementing the 12.25"surface interval with Doyon 141. As per our conversation, the following steps will be followed to ensure the wellbore is competent and sufficient barriers are in place while running the 3.5" kill string used to suspend the well. 1. Pressure test 12.25"surface casing to 3,500 psi for 30 minutes after cement plug bumps with 10.0 ppg spud mud. 2. Nipple down surface riser. 3. Nipple up wellhead and test to 1,000 psi 4. Rig up BOP. 5. Set 3.5"test plug. 6. Body test BOP from annular preventer down to 2,000 psi for 10 minutes—chart test. 7. Run 3.5" kill string to 2,000' MD. The original plan was to complete the intermediate section of CD3-125 with Doyon 141, however due to ice road delays, the schedule has been modified and Doyon 19 will now move in to drill the intermediate and lateral sections of this hole. Ryan Drilling Engineer Conoco!Phiilips Alaska Direct:(907)265 6313 j Mohiie i9O7 980-5107 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday, February 02, 2011 3:08 PM To: 'Robertson, Ryan G' Cc: DOA AOGCC Prudhoe Bay Subject: RE: CD3-125 Temporary Suspension (PTD 210-189) Ryan, Your proposal looks fine as stated below. I cc'd the inspectors so they know your plan. We won't expect a full blown BOP test on Doyon 141 until the next well you move to. It is my understanding that Doyon 19 will be finishing the well sometime later in this 2011 drilling season. Be sure and submit a sundry for the operational shutdown as per 20 AAC 25.072 (a) Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Robertson, Ryan G [mailto:Ryan.G.Robertson@conocophillips.com] Sent: Wednesday, February 02, 2011 2:39 PM To: Schwartz, Guy L(DOA) Subject: CD3-125 Temporary Suspension (PTD 210-189) Guy CPAI proposes to temporarily suspend the CD3-125 well after drilling, casing and cementing the 12.25"surface interval with Doyon 141. As per our conversation, the following steps will be followed to ensure the wellbore is competent and sufficient barriers are in place while running the 3.5" kill string used to suspend the well. 1. Pressure test 12.25" surface casing to 3,500 psi for 30 minutes after cement plug bumps with 10.0 ppg spud mud. 2. Nipple down surface riser. 3. Nipple up wellhead and test to 1,000 psi 4. Rig up BOP. 5. Set 3.5"test plug. 6. Body test BOP from annular preventer down to 2,000 psi for 10 minutes—chart test. 7. Run 3.5" kill string to 2,000' MD. The original plan was to complete the intermediate section of CD3-125 with Doyon 141, however due to ice road delays, the schedule has been modified and Doyon 19 will now move in to drill the intermediate and lateral sections of this hole. Ryan Drilling Engineer GonocoPhillips Alaska I Direct.(907)265-6318 I Mobile:(907)980-5107 2/2/2011 scinflE oF AILAs - A 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 Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Fiord Oil Pool, CD3-125 ConocoPhillips Alaska, Inc. Permit No: 210-189 Surface Location: 4012' FNL, 1146' FEL, SEC. 05, T12N, R5E, UM Bottomhole Location: 2200' FNL, 3761' FEL, SEC. 17, T12N, R5E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. 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. Sincerely, V Daniel T. Seamount, Jr. Chair DATED this Sday of January, 2011. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 Dec 28th, 2010 RECEIVED Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 DEC 2 9 2010 Anchorage, Alaska 99501 Alaska Oil& Gas Cons. Commission Re: Application for Permit to Drill CD3-125 Anchorage Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the CD3 (Fiord) pad. The intended spud date for this well is Dec 21st, 2010. It is intended that Doyon Rig 141 be used to drill the well. CD3-125 will be completed as a horizontal producer in the Nechelik reservoir. The well will be flowed back to mitigate reservoir damage and then hooked up to begin production. It is very likely that due to the timing of Doyon 19 arriving on CD3, operations on CD3-125 will be suspended at a casing point. This will allow Doyon 19 to move onto the Western row of wells and Doyon 141 will then move down to the Eastern row. There will be a 10-403 package submitted to the state indicating an operational shutdown. It is CPAI's intent to complete CD3-125 with Doyon 19 duringthe 2n1 1 uv _,inter drilling season. It is expected that the K2 (Qannik) sand could be considered a significant hydrocarbon bearing zone. It is planned to pump lead cement, then open a stage tool and pump a second cement job to isolate the K2 with 500' of cement above and below the interval. This will leave a mud gap between the two stages. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. This will be the 7th winter season of drilling on the Fiord pad and there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. A proposed drilling program 3. A drilling fluids program summary. 4. Pressure information as required by 20 ACC 25.035 (d)(2). 5. 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 Nina Anderson at 265-6403, or Liz Galiunas at 265-6247. Sincerely, /7 1 Nina Anderson Drilling Engineer Attachments cc: CD3-125 Well File/Sharon Allsup Drake ATO 1530 Liz Galiunas ATO 1500 Ryan Robertson ATO 1702 Mike A. Winfree ATO 1704 Lanston Chin Kuukpik Corporation ORIGINAL EE1VED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION L) 2 9 2010 PERMIT TO DRILL 20 AAC 25.005 '"10,3<;ka Oii & GasG,o CommisS O la.Type of Work: 1 b.Proposed Well Class: Development-Oil 0 •Service-Winj ❑ Single Zone E. lc.S },,i sroposed for: Drill Q • Re-drill ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp E Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket iJ Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 - CD3-125 ' 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 19347' ' TVD: 7072' - Colville River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): 4012'FNL, 1146'FEL,Sec.5,T12N, R5E, UM , ADL 372105 , 23` , Fiord Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1938'FNL,2693'FEL,Sec.7,T12N, R5E, UM LAS2112 ' - `C �� 1/20/2011 Total Depth: 9.Acres in Property' 14.Distance to Nearest Property: 2200'FNL,3761'FEL,Sec. 17,T12N, R5E, UM 2560 +/-4.0 miles to ADL 391451 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Eleva'•n above MSL: / 40.6 feet 15.Distance to Nearest Well Open Surface:x- 387896.0 • y- 6003766.4, Zone- 4 GL Elev.ion above MSL: /`: , ee;v Same Pool: CD3 ,1820' 16.Deviated wells: Kickoff depth: 291 ft. 17.M- mum Anticipated Pressures,ti psig(see 20 MC 25.035) Maximum Hole Angle: 89.09° deg I.•wnhole:3309 psig . Surface:2493 psig 18.Casing Program: Specifications '' ,p - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length i 1.I, ', TVD MD ND (including stage data) 24" 16" 62.5 H-40 Weide.(' \\77 11.r 0, 37 114 114 • Pre Installed ll 2 12.25" 9.625" 40 L-80 BTC 90 9 37 2940 2450 y 476 sx AS Lite 3,230 sx 15.8'G' 8.75" 7" 26 L-80 BTC-M .7 37 12372 6945 1st-313 sx 15.8'G' 2nd-188 sx 15.8 G 3.5" 9.3 L-80 EUE I �1 32 32 11160 6655 Tubing 6. 125" 3.5" 9.3 L-80 IQT-0 11160 6655 19340 7081 Liner with Swell PKRS and SS for Frac ' 1 i 19 PRESENT WELL CONDI r , (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): ' • ea red) Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured) Casing _ Length a)' :'2 Cement Volume MD TVD Conductor/Structural 1 Surface _ 7\0' 1 Intermediate / iProduction Liner 1 - l • Perforation Depth MD(ft): l ` Perforation Depth TVD(ft): / fill � 20.Attachments: Property rd \t/ BOP Sketch El Drilling Program El Time v.Depth Plot ❑ Shallow Hazard Analysis Q I Diverter Sketch El Seabed Report 11 Drilling Fluid Program E20 AAC 25.050 requirements ❑ 21.Verbal Approval: Commi .io presentative: Date: 01. 22. I hereby certify that the oregoing is true and correct. Contact Nina Anderson 265-6403 Printed Name Chip Alvord Title Alaska Drilling Manager Azad, Phone265-6120 Date l 11.-1/6112 eco Commission Use Only Permit to Drill .6-:_...q API Number: Permit Approval See cover letter Number: 7 /l�' !( 50-//e ''' '27Y,:',3 1 r_ri Date: +`\\ \\ for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed me ane,gas hydrates,or gas contained in shales: El ,IL. 3 sex) P SL kioI I;s1 Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No E✓' Other: Zs-to r5(; ,heJa,, (CSi H2S measures: Yes ❑ No Directional svy req'd: Yes Q No ❑ D1ve-r,Fcr tt14i 11.c� . LO MC. ' " 035 01) 7J / ) 4 APPROVED BY THE COMMISSION 5 7!/ DATE: ( Elin / A ,COMMISSIONER Form 10-401 (Revised 7/2009) This permit is valid for 2• o t = r. • 'a • .'. • al(20 AAC 25.005 )) /•3•/ ubmit in Duplicate !a CD3-125 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 Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Gyro single shots, traveling cylinder diagrams Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud temperatures 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 density cement slurries 8-3/4" Hole / 7" Casing Interval Event Risk Level Mitigation Strategy 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 weight. Lost circulation Low 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, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. 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 practices, mud scavengers 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 8.8 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers ORIGiNAL Fiord Nechelik : CD3-125 Procedure 1. Move Doyon 19 on CD3-125, dewater cellar as needed. 2. Rig up riser. Giver-fe, �.J�ciiuP. 3. Drill 12-%4" 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 3500 psi high and 250 psi low. 6. Pressure test casing to 2500 psi. 7. Pick up and run in hole with 8-3/4"drilling BHA. Drill out 20' of new hole. Perform leak off test ' 8. Drill 8-3/4" hole to intermediate casing point in the reservoir sand. (LWD Program: GR/RES/PWD/Dens/Neut) 9. Run and cement 7" casing as per program. If needed, a second stage cement job will be pumped to isolate the K2 (Qannik)formation. 10. Perform 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 3500 psi high and 250 psi low. ` 12. PU and RIH with 6-1/8"drilling assembly. Pressure test casing to 3500 psi. 13. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 14. Displace well to Flo-Thru drilling fluid. 15. Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD/Dens/Neut). 16. Circulate the hole clean and pull out of hole. 17. Run lower completion of 3-1/2" liner and liner hanger with 8 stage Frac Sleeve system. 18. Run upper completion: 3-'/, 9.3#, L-80 tubing with SSSV, gas lift mandrels, packer, landing nipple and wireline entry guide. 19. Drop ball and rod to set packer. Displace drilling fluids with brine/diesel. 20. Sting in, space out, and land hanger. 21. Install 2 way check and pressure test hanger seals to 5000 psi. Pull TWC. 22. Test tbg to 3500 psi for 30 minutes. Bleed down tbg to 2000 psi and pressure test annulus to 3500 psi for 30 minutes. Bleed tbg to 0 psi to sheer casing to tbg DCK-2 SOV. Bleed tubing and annulus pressure to zero. 23. Install TWC and pressure test through SOV to 1000 psi in the direction of flow. Nipple down BOP. 24. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 25. Circulate tubing to diesel and install freeze protection in the annulus. 26. Set BPV and secure well. Move rig off. ORIGINAL Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD3-124 is the closest existing well. Ellipse to ellipse separation is 6.15' @ 590' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Nechelik 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 CD3-125 will be injected into a permitted annulus on CD3 pad or the class 2/class 1 disposal well on CD1 pad. The CD3-125 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 Nechelik reservoir, potential Kuparuk reservoir and the Qannik reservoir. There will be 500' of cement fill above the top of the Kuparuk reservoir along with 500' above and below the Qannik reservoir per regulations. Upon completion of CD3-125 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) * (2450') + 1,500 psi = 3028 psi Pore Pressure = 1,108 psi Therefore Differential = 3028— 1108 = 1920 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 40 L-80 3 BTC 3,090 psi 2,626 psi 5,750 psi 4,887 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi ORIGINAL DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point—8 3/4" Section —6 1/8" point— 12 Y4" Density 8.6— 10.0 ppg 9.6—9.8 ppg 9.0-9.3 ppg ✓ PV 6— 16 10—15 YP 30—60 11 — 19 25—30 Funnel Viscosity 70—300+ Initial Gels 8 - 10 10— 15 10 minute gels < 20 12 -20 API Filtrate NC— 10 cc/30 min 5— 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 3 % 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 MI Swaco's Flo-Thru drill-in fluid. The base fluid will consist of 3% KCI, with calcium carbonate bridging material to minimize formation damage. Flowzan Polymer and Thrutrol starch will be used for viscosity and fluid loss control respectively. Klagard will be used for inhibition. ECD's will be monitored with real time PWD data, and controlled by maintaining fluid rheology and pump rates within specifications. G1N L Completion Schematic Colville River Field CD3-125 Production Well Completion • Updated 12/28/2010 ,1s°Conductor to 114' Sperry Drilling Services CD3-125wpO5 Packer Fluid mix: Page 1 of 2 Inhibited Kill weight 6%KCI Brine with 2000'TVD diesel cap Upper Completion MD TVD 0 1)Tubing Hanger 36' 36' 9-5/8"40 ppf L-80 BTC-Mod 2)4-'/2"12.6#/ft IBT-Mod Tubing(2 jts),XO A iii. Surface Casing 3)3-'/2'9.3#/ft EUE-Mod Tubing @ 2940'MD/2450'TVD 4)Camco TRMAXX-5E SSSV(2.812"ID) 2152' 2000' cemented to surface with control line to surface TOC @+/- 6 OL 1 5)3-'/2"9.3#/ft EUE-Mod Tubing 5571'MD! 6)3-'/2"x 1"Camco KBMG GLM w/DV 4832' 3400' 3765'TVD 7)3-Y2"9.3#/ft EUE-Mod Tubing Qannik Interval 8)3-1/2"x 1"Camco KBMG GLM w/DV 9184' 5600' Top+/- 6071'MD/4015 TVD 9)3-'/2'9.3#/ft EUE-Mod Tubing 10)Camco KBMG GLM(2.867"ID)w/DCK2 10930' 6564' Pinned for 2500 psi casing to tbg shear i. 0 O 02 1 1)3-'/2"Tubing Joints EUE-Mod (2 joints) ES Cementer 16)Baker Premier Packer 11030' 6606' +/-6610' MD/4285'TVD 17)3-'/z'9.3#/ft P-110 EUE-mod Tubing(1 joint) 18)HES XN 2.813"(2.75"NoGo)-with RHC Plug 11100' 6633' 19)3-'/2"9.3#/ft P-110 EUE-mod Tubing 20)BOT Stinger w/Fluted WLEG stinger 11160' 6655' 8 GL fl 3-1/2" 9.3 ppf L-80 EUE M tubing run with Jet Lube Run'n'Seal pipe dope 0 rgi goo TOC Calculated @+/-10,730'MD 6468'TVD (300'above Packer &500'MD above .:,: Kuparuk) tII 11111 1111 \°*#.'AiL:: , Top Kuparuk C 11649'MD/6801 TVD Top Nechelik 6-1/8" Hole TD 12372'MD/6945'TVD 7"26 ppf L-80 BTC Mod from 36'to 11000'MD/6593'TVD at 7"26 ppf P-110 BTC Mod from 11000'MD to 12372'MD/6945'TVD at 19,347'MD/ 7,072'TVD ORIGINAL Lower Completion: Colville River Field CD3-125 Production Well Completion Updated 12/28/2010 Sperry Drilling Services ,16"Conductor to 114' CD3-125wp05 N Packer Fluid mix: Page 2 of 2 • Inhibited Kill weight Lower Completion MQ DLQ 6%KCI Brine with 2000'TVD 21)Baker 5"X 7"Flex Lock Hanger w/Sealbore Extension 1116(T 6655' diesel cab 22)XO 5-1/2"Hydril 521 X 3-%"SLHT 23)3-1/2',9.3#/ft,SLHT Tubing 24)3-1/2"x 6-1/2"Centralizers SLHT Box x Box 9-5/8"40 ppf L-80 BTC Mod 25)Swell Packer(3-1/"SLHT)OD 5.75"w/5 sealing element TBD TBD 26)3-1/2"x 6-1/2"Centralizers SLHT Box x Pin Surface Casing 27)3-1/2",9.3#/ft,SLHT Tubing @ 3031'MD/2500'TVD 28)3-W SLHT Ball Actuated Sleeve(2.000"Seat ID)(2.125"Bat) TBD TBD cemented to surface 29)3-1/2",9.2#/ft,SLHT Tubing TOC @+/- GL J 30)3-1/2"x 6-W Centralizers SLHT Box x Box 5571'MD/ 31)Swell Packer(3-W SLHT)OD 5.75"w/5'sealing element TBD TBD 3765'TVD 32)3-1/2"x 6-1/2"Centralizers SLHT Box x Pin 33)3-W,9.3#/ft,SLHT Tubing Qannik Interval 34)3-%"SLHT Ball Actuated Sleeve(1.875"Seat ID)(2.00("Ball) TBD TBD ' r Top+/- 6071'MD 4015'TVD 35)3-%"',9.3#/ft,SLHT Tubing 36)3-1/2"x 6-1/2"Centralizers SLHT Box x Box 37)Swell Packer(3-W SLHT)OD 5.75"w/5'sealing element TBD TBD 0 0 O : ES Cementer 38)3-%"x 6 "Centralizers SLHT Box x Pin 39)3-W,9 3#/ft,SLHT Tubing +/-6610'MD/4285'TVD 40)3-W SLHT Bat Actuated Sleeve(1.750"Seat ID)(1.875"Ball) TBD TBD 41)3-1/2",9.3#/ft,SLHT Tubing 42)3-W x 6-W Centralizers SLHT Box x Box 43)Swell Packer(3-1/2"SLHT)OD 5.75"w/5'sealing element TBD TBD 44)3-1/2"x 6-W Centralizers SLHT Box x Pin 45)3-1/2",9.3#/ft,SLHT Tubing 46)3-W SLHT Ball Actuated Sleeve(1.625"Seat ID)(1.750"Ball) TBD TBD 47)3-1/2",9.3#/ft,SLHT Tubing 48)3-'/"x 6-1/2"Centralizers SLHT Box x Box 49)Swell Packer(3-W SLHT)OD 5.75"w/5'sealing element TBD TBD GL J 50)3-1/2"x 6-W Centralizers SLHT Box x Pin 51)3-1/2",9.3#/ft,SLHT Tubing 3-1/2" 9.3 ppf L-80 EUE M 52)3-1/:"SLHT Ball Actuated Sleeve(1.500"Seat ID)(1 625"Ball) TBD TBD 53)3-W,9.3#/ft,SLHT Tubing tubing run with Jet Lube Run'n'Seal 54)3-1/2"x 6-1/2"Centralizers SLHT Box x Box pipe dope 55)Swell Packer(3-W SLHT)OD 5.75"w/5'sealing element TBD TBD 56)3-1/2"x 6-W Centralizers SLHT Box x Pin 57)3-W,9.3#18,SLHT Tubing 58)3-'/"SLHT Ball Actuated Sleeve(1.375"Seat ID)(1.500"Ball) TBD TBD' 59)3-1/2",9.3#/ft,SLHT Tubing 60)3-W x 6-1/2"Centralizers SLHT Box x Box 61)Swell Packer(3-W SLHT)OD 5.75"w/5'sealing element TBD TBD 62)3-W x 6-W Centralizers SLHT Box x Pin 63)3-W,9.3#/ft,SLHT Tubing 00111..0/1 64)3-1/"SLHT Ball Actuated Sleeve(1.250"Seat ID)(1.375"Ball) TBD TBD S ► 65)3-W',9.3#/ft,SLHT Tubing 66)3-W'x 6-%"Centralizers SLHT Box x Box 67)Swell Packer(3-1/2"SLHT)OD 5.75"w/5'sealing element TBD TBD TOC Calculated 68)344"x 6-W'Centralizers SLHT Box x Pin @+/-10,730'MD/ 69)3-',4",9.3#/ft,SLHT Tubing 6468'TVD70)3-W SLHT Mule Shoe 19340' 7081" (300'above Packer 1111\i/s/4' &500'MD above Kupafuk) ' A (D ® 37 37 40 ®®°0 3 46 49 - 52 55 66 61 0C)-041 • 21 II ■ in S 1111 1111 Top Kuparuk C 11649' 11111 :C :C :C :C :C : i MD/6801 TVD 1. • • • • • • • Top Nechelik 12372'MD/ 6-1/8" Hole TD 6945'TVD 7"26 ppf L-80 BTC Mod from 36'to 11000'MD/6593'TVD at 7"26 ppf P-110 BTC Mod from 11000'MD to 12381'MD/6954'TVD at 19,347'MD/ 7,072'TVD ' R! G1N L CD3-125 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) (lbs. /gal) (psi) (psi) 16 114/ 114 10.9 52 53 9 5/8 2940/2450 14.5 1108 1602 7" 12372 /6945 16.0 3142 2493 N/A 19347/7072 16.0 3200 N/A • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3500 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 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 conductor casing (16") ASP = [(FG x 0.052)—0.1] D = [(10.9 x 0.052)—0.1]x 114 = 53 psi OR ASP = FPP—(0.1 x D) = 1108—(0.1 x 2450') = 863 psi 2. Drilling below surface casing (9 5/8") ASP= [(FG x 0.052)—0.1] D = [(14.5 x 0.052)—0.1] x 2450 = 1602 psi OR ASP = FPP—(0.1 x D) = 3142—(0.1 x 6945') = 2447 psi 3. Drilling below intermediate casing (7") ASP = Reservoir Pressure—(0.1 x D) = 3309—(0.1 x 7072') = 2602 psi 1 3I ► L Cementing Program: 9 5/8" Surface Casing run to 2940' MD/2450' TVD. Cement from 2940' MD to 2440' (500' of fill)with Class G+Adds @ 15.8 PPG, and from o 2440' to surface with Arctic Set Lite 3. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost(1555' MD). Lead slurry: (2440'-1555')X 0.3132 ft3/ft X 1.5 (50% excess)=415.77 ft3 below permafrost 1555' X 0.3132 ft3/ft X 3.5 (250% excess) = 1704.6 ft3 above permafrost Total volume=415.77+ 1704.6=2120.37 ft3 => 476 Sx @ 4.45 ft3/sk System: 476 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft3/sk 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% S001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 12372' MD/6945' TVD: Cemented in two stages Cement from 12,372' MD to 10730' MD (300' MD above the packer& minimum 500' MD above top of Kuparuk reservoir)with Class G+adds @ 15.8 PPG. Assume 40% excess annular volume. First Stage: Lead: (12372' -10730') X 0.1503 ft3/ft X 1.4 (40% excess)=345.5 ft3 annular vol. 80' X 0.2148 ft3/ft= 17.2 ft3 shoe joint volume Total volume = 345.5 + 17.2 = 362.71 ft3 =>313 Sx @ 1.16 ft3/sk System: 313 Sx Class G+ 0.2%D046 antifoamer, 0.25% D065 dispersant, 0.25%D800 / retarder and 0.18%D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk Second Stage: Cement from ports in a stage tool set 500' below the Qannik(K2) interval to +/-500' above the K2 interval with Class G+ additives @ 15.8 ppg. Assume 40% excess annular volume Lead: (6610' - 5571')X 0.1503 ft3/ft X 1.4 (40%excess)=218 ft3 annular vol. Total Volume=218 ft3=> 188 Sk @ 1.17 ft3/sk System: 188 Sx Class G+0.2%D046 antifoamer, 0.3%D065 dispersant and 1% S002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk ORIGINAL ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad Plan: CD3-125 Plan: CD3-125 Plan: CD3-125wp05 a.k.a. 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TVD Reference: Plan:28+12.6 @ 40.60ft(Doyon 141) - Project: Western North Slope MD Reference: Plan:28+12.6 @ 40.60ft(Doyon 141) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-125 Survey Calculation Method: Minimum Curvature - Wellbore: Plan:CD3-125 Design: CD3-125wp05 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 CD3 Fiord Pad Site Position: Northing: 469.98ft Latitude: 53°58'43.652 N From: Map Easting: -401.27ft Longitude: 152°19'30.231 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -1.88° Well Plan:CD3-125 Well Position +N/-S 0.00 ft Northing: 6,003,766.42ft ' Latitude: 70°25'9.210 N +E/-W 0.00 ft Easting: 387,895.98 ft Longitude: 150°54'47.701 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: . 12.60ft Wellbore Plan:CD3-125 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2009 12/20/2010 16.41 79.73 57,372 Design CD3-125wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 28.00 0.00 0.00 142.00 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (1 (°) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 28.00 0.00 0.00 28.00 -12.60 0.00 0.00 0.00 0.00 0.00 0.00 291.50 0.00 0.00 291.50 250.90 0.00 0.00 0.00 0.00 0.00 0.00 541.68 3.75 320.00 541.50 500.90 6.27 -5.26 1.50 1.50 0.00 320.00 895.08 11.53 320.00 891.50 850.90 42.24 -35.44 2.20 2.20 0.00 0.00 2,677.50 60.00 263.00 2,318.60 2,278.00 88.09 -988.26 3.04 2.72 -3.20 -63.49 8,603.30 60.00 263.00 5,281.50 5,240.90 -537.33 -6,081.90 0.00 0.00 0.00 0.00 10,822.58 62.43 180.03 6,511.50 6,470.90 -1,804.68 -7,180.54 3.20 0.11 -3.74 -111.50 11,208.36 70.15 180.03 6,666.50 6,625.90 -2,157.63 -7,180.70 2.00 2.00 0.00 0.00 12,372.49 83.00 142.73 6,945.60 6,905.00 -3,204.26 -6,817.41 3.30 1.10 -3.20 -75.68 12,422.49 83.00 142.73 6,951.69 6,911.09 -3,243.75 -6,787.36 0.00 0.00 0.00 0.00 12,623.95 89.08 142.73 6,965.60 6,925.00 -3,403.62 -6,665.70 3.02 3.02 0.00 0.00 13,870.58 89.09 142.66 6,985.52 6,944.92 -4,395.06 -5,910.25 0.01 0.00 -0.01 -83.03 19,346.97 89.09 142.66 7,072.60 7,032.00 -8,748.36 -2,588.79 0.00 0.00 0.00 0.00 12/20/2010 4.32:00PM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTDN Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-125 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:28+12.6 @ 40.60ft(Doyon 141) Project: Western North Slope MD Reference: Plan:28+12.6 @ 40.60ft(Doyon 141) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-125 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-125 Design: CD3-125wp05 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (if) (ft) (ft) (ft) -12.60 28.00 0.00 0.00 28.00 -12.60 0.00 0.00 6,003,766.42 387,895.98 0.00 0.00 100.00 0.00 0.00 100.00 59.40 0.00 0.00 6,003,766.42 387,895.98 0.00 0.00 200.00 0.00 0.00 200.00 159.40 0.00 0.00 6,003,766.42 387,895.98 0.00 0.00 291.50 0.00 0.00 291.50 250.90 0.00 0.00 6,003,766.42 387,895.98 0.00 0.00 Start Build 1.50 300.00 0.13 320.00 300.00 259.40 0.01 -0.01 6,003,766.43 387,895.97 1.50 -0.01 400.00 1.63 320.00 399.99 359.39 1.18 -0.99 6,003,767.62 387,895.01 1.50 -1.54 500.00 3.13 320.00 499.90 459.30 4.36 -3.66 6,003,770.84 387,892.39 1.50 -5.69 541.68 3.75 320.00 541.50 500.90 6.27 -5.26 6,003,772.77 387,890.81 1.50 -8.19 Start Build 2.20 600.00 5.04 320.00 599.65 559.05 9.70 -8.14 6,003,776.24 387,887.99 2.20 -12.65 700.00 7.24 320.00 699.07 658.47 17.88 -15.01 6,003,784.53 387,881.24 2.20 -23.33 800.00 9.44 320.00 798.01 757.41 28.99 -24.32 6,003,795.77 387,872.09 2.20 -37.82 895.08 11.53 320.00 891.50 850.90 42.24 -35.44 6,003,809.19 387,861.18 2.20 -55.11 Start DLS 3.04 TFO-63.49 900.00 11.60 319.33 896.32 855.72 42.99 -36.08 6,003,809.95 387,860.55 3.04 -56.09 1,000.00 13.26 307.45 993.98 953.38 57.59 -51.74 6,003,824.78 387,845.12 3.04 -77.23 1,100.00 15.35 298.45 1,090.89 1,050.29 70.87 -72.48 6,003,838.37 387,824.57 3.04 -100.47 1,200.00 17.71 291.67 1,186.76 1,146.16 82.79 -98.26 6,003,850.68 387,798.98 3.04 -125.74 1,229.28 18.44 290.02 1,214.60 1,174.00 86.02 -106.75 6,003,854.03 387,790.54 3.04 -133.51 Base Permafrost 1,300.00 20.25 286.50 1,281.33 1,240.73 93.33 -128.99 6,003,861.67 387,768.41 3.04 -152.96 1,400.00 22.91 282.46 1,374.31 1,333.71 102.44 -164.59 6,003,871.32 387,732.95 3.04 -182.06 1,500.00 25.65 279.22 1,465.47 1,424.87 110.11 -204.97 6,003,879.59 387,692.71 3.04 -212.96 1,600.00 28.44 276.58 1,554.53 1,513.93 116.31 -249.99 6,003,886.46 387,647.78 3.04 -245.56 1,700.00 31.28 274.38 1,641.24 1,600.64 121.02 -299.55 6,003,891.92 387,598.30 3.04 -279.79 1,800.00 34.16 272.52 1,725.37 1,684.77 124.24 -353.50 6,003,895.95 387,544.42 3.04 -315.54 1,900.00 37.05 270.91 1,806.67 1,766.07 125.95 -411.68 6,003,898.53 387,486.27 3.04 -352.70 2,000.00 39.97 269.50 1,884.91 1,844.31 126.15 -473.93 6,003,899.66 387,424.04 3.04 -391.19 2,100.00 42.90 268.26 1,959.88 1,919.28 124.83 -540.08 6,003,899.34 387,357.88 3.04 -430.88 2,200.00 45.84 267.14 2,031.36 1,990.76 122.01 -609.94 6,003,897.57 387,287.99 3.04 -471.66 2,300.00 48.79 266.13 2,099.15 2,058.55 117.68 -683.32 6,003,894.34 387,214.56 3.04 -513.43 2,400.00 51.75 265.21 2,163.05 2,122.45 111.87 -760.00 6,003,889.68 387,137.81 3.04 -556.06 2,500.00 54.72 264.36 2,222.90 2,182.30 104.58 -839.77 6,003,883.60 387,057.95 3.04 -599.42 2,600.00 57.69 263.58 2,278.51 2,237.91 95.85 -922.40 6,003,876.10 386,975.20 3.04 -643.41 2,649.84 59.18 263.20 2,304.60 2,264.00 90.96 -964.58 6,003,871.84 386,932.95 3.04 -665.53 C-40 2,677.50 60.00 263.00 2,318.60 2,278.00 88.09 -988.26 6,003,869.34 386,909.23 3.04 -677.85 Start 5925.80 hold at 2677.50 MD 2,700.00 60.00 263.00 2,329.85 2,289.25 85.72 -1,007.60 6,003,867.25 386,889.86 0.00 -687.89 2,800.00 60.00 263.00 2,379.85 2,339.25 75.16 -1,093.56 6,003,857.99 386,803.76 0.00 -732.49 2,900.00 60.00 263.00 2,429.85 2,389.25 64.61 -1,179.52 6,003,848.73 386,717.66 0.00 -777.10 2,940.30 60.00 263.00 2,450.00 2,409.40 60.35 -1,214.16 6,003,845.00 386,682.97 0.00 -795.07 9-5/8"x 12-1/4" 12/20/2010 4.32::00PM Page 3 COMPASS 2003.16 Build 69 .,\ ( tL ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-125 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:28+12.6 @ 40.60ft(Doyon 141) Project: Western North Slope MD Reference: Plan:28+12.6 @ 40.60ft(Doyon 141) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-125 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-125 Design: CD3-125wp05 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Easting DLS Vert Section (ft) (') (0) (ft) ft (ft) (ft) (ft) (ft) 2,432.00 2,985.50 60.00 263.00 2,472.60 2,432.00 55.58 -1,253.01 6,003,840.81 386,644.05 0.00 -815.23 C-30 3,000.00 60.00 263.00 2,479.85 2,439.25 54.05 -1,265.48 6,003,839.47 386,631.57 0.00 -821.70 3,100.00 60.00 263.00 2,529.85 2,489.25 43.50 -1,351.43 6,003,830.21 386,545.47 0.00 -866.30 3,200.00 60.00 263.00 2,579.85 2,539.25 32.94 -1,437.39 6,003,820.94 386,459.37 0.00 -910.91 3,300.00 60.00 263.00 2,629.85 2,589.25 22.39 -1,523.35 6,003,811.68 386,373.27 0.00 -955.51 3,400.00 60.00 263.00 2,679.85 2,639.25 11.84 -1,609.30 6,003,802.42 386,287.17 0.00 -1,000.11 3,500.00 60.00 263.00 2,729.85 2,689.25 1.28 -1,695.26 6,003,793.16 386,201.07 0.00 -1,044.72 3,600.00 60.00 263.00 2,779.85 2,739.25 -9.27 -1,781.22 6,003,783.90 386,114.98 0.00 -1,089.32 3,700.00 60.00 263.00 2,829.85 2,789.25 -19.83 -1,867.17 6,003,774.64 386,028.88 0.00 -1,133.92 3,743.50 60.00 263.00 2,851.60 2,811.00 -24.42 -1,904.56 6,003,770.61 385,991.43 0.00 -1,153.33 C-20 3,800.00 60.00 263.00 2,879.85 2,839.25 -30.38 -1,953.13 6,003,765.38 385,942.78 0.00 -1,178.53 3,900.00 60.00 263.00 2,929.85 2,889.25 -40.94 -2,039.09 6,003,756.12 385,856.68 0.00 -1,223.13 4,000.00 60.00 263.00 2,979.85 2,939.25 -51.49 -2,125.05 6,003,746.85 385,770.58 0.00 -1,267.73 4,100.00 60.00 263.00 3,029.85 2,989.25 -62.04 -2,211.00 6,003,737.59 385,684.48 0.00 -1,312.34 4,200.00 60.00 263.00 3,079.85 3,039.25 -72.60 -2,296.96 6,003,728.33 385,598.38 0.00 -1,356.94 4,300.00 60.00 263.00 3,129.85 3,089.25 -83.15 -2,382.92 6,003,719.07 385,512.29 0.00 -1,401.55 4,400.00 60.00 263.00 3,179.85 3,139.25 -93.71 -2,468.87 6,003,709.81 385,426.19 0.00 -1,446.15 4,500.00 60.00 263.00 3,229.85 3,189.25 -104.26 -2,554.83 6,003,700.55 385,340.09 0.00 -1,490.75 4,600.00 60.00 263.00 3,279.85 3,239.25 -114.81 -2,640.79 6,003,691.29 385,253.99 0.00 -1,535.36 ` 4,700.00 60.00 263.00 3,329.85 3,289.25 -125.37 -2,726.74 6,003,682.02 385,167.89 0.00 -1,579.96 4,800.00 60.00 263.00 3,379.85 3,339.25 -135.92 -2,812.70 6,003,672.76 385,081.79 0.00 -1,624.56 4,900.00 60.00 263.00 3,429.85 3,389.25 -146.48 -2,898.66 6,003,663.50 384,995.70 0.00 -1,669.17 5,000.00 60.00 263.00 3,479.85 3,439.25 -157.03 -2,984.62 6,003,654.24 384,909.60 0.00 -1,713.77 5,100.00 60.00 263.00 3,529.85 3,489.25 -167.59 -3,070.57 6,003,644.98 384,823.50 0.00 -1,758.37 5,200.00 60.00 263.00 3,579.85 3,539.25 -178.14 -3,156.53 6,003,635.72 384,737.40 0.00 -1,802.98 5,300.00 60.00 263.00 3,629.85 3,589.25 -188.69 -3,242.49 6,003,626.46 384,651.30 0.00 -1,847.58 5,400.00 60.00 263.00 3,679.85 3,639.25 -199.25 -3,328.44 6,003,617.19 384,565.20 0.00 -1,892.19 5,500.00 60.00 263.00 3,729.85 3,689.25 -209.80 -3,414.40 6,003,607.93 384,479.10 0.00 -1,936.79 5,600.00 60.00 263.00 3,779.85 3,739.25 -220.36 -3,500.36 6,003,598.67 384,393.01 0.00 -1,981.39 5,700.00 60.00 263.00 3,829.85 3,789.25 -230.91 -3,586.32 6,003,589.41 384,306.91 0.00 -2,026.00 5,733.50 60.00 263.00 3,846.60 3,806.00 -234.45 -3,615.11 6,003,586.31 384,278.07 0.00 -2,040.94 K-3 5,800.00 60.00 263.00 3,879.85 3,839.25 -241.46 -3,672.27 6,003,580.15 384,220.81 0.00 -2,070.60 5,900.00 60.00 263.00 3,929.85 3,889.25 -252.02 -3,758.23 6,003,570.89 384,134.71 0.00 -2,115.20 6,000.00 60.00 263.00 3,979.85 3,939.25 -262.57 -3,844.19 6,003,561.63 384,048.61 0.00 -2,159.81 6,029.50 60.00 263.00 3,994.60 3,954.00 -265.69 -3,869.54 6,003,558.89 384,023.22 0.00 -2,172.96 K-3 Basal 6,071.50 60.00 263.00 4,015.60 3,975.00 -270.12 -3,905.64 6,003,555.00 383,987.05 0.00 -2,191.70 K-2 6,100.00 60.00 263.00 4,029.85 3,989.25 -273.13 -3,930.14 6,003,552.37 383,962.51 0.00 -2,204.41 6,200.00 60.00 263.00 4,079.85 4,039.25 -283.68 -4,016.10 6,003,543.10 383,876.42 0.00 -2,249.01 6,279.50 60.00 263.00 4,119.60 4,079.00 -292.07 -4,084.43 6,003,535.74 383,807.97 0.00 -2,284.47 K-2 Basal 12/20/2010 4.32:00PM Page 4 COMPASS 2003.16 Build 69 OR ( GINAL ConocoPhillips HALLIBURTDN Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-125 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:28+12.6 @ 40.60ft(Doyon 141) Project: Western North Slope MD Reference: Plan:28+12.6 @ 40.60ft(Doyon 141) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-125 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-125 Design: CD3-125wp05 r Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (0) (0) (ft) ft (ft) (ft) (ft) (ft) 4,089.25 6,300.00 60.00 263.00 4,129.85 4,089.25 -294.24 -4,102.06 6,003,533.84 383,790.32 0.00 -2,293.62 6,400.00 60.00 263.00 4,179.85 4,139.25 -304.79 -4,188.01 6,003,524.58 383,704.22 0.00 -2,338.22 6,500.00 60.00 263.00 4,229.85 4,189.25 -315.34 -4,273.97 6,003,515.32 383,618.12 0.00 -2,382.82 6,600.00 60.00 263.00 4,279.85 4,239.25 -325.90 -4,359.93 6,003,506.06 383,532.02 0.00 -2,427.43 6,700.00 60.00 263.00 4,329.85 4,289.25 -336.45 -4,445.89 6,003,496.80 383,445.92 0.00 -2,472.03 6,800.00 60.00 263.00 4,379.85 4,339.25 -347.01 -4,531.84 6,003,487.54 383,359.83 0.00 -2,516.64 6,900.00 60.00 263.00 4,429.85 4,389.25 -357.56 -4,617.80 6,003,478.27 383,273.73 0.00 -2,561.24 7,000.00 60.00 263.00 4,479.85 4,439.25 -368.12 -4,703.76 6,003,469.01 383,187.63 0.00 -2,605.84 7,100.00 60.00 263.00 4,529.85 4,489.25 -378.67 -4,789.71 6,003,459.75 383,101.53 0.00 -2,650.45 7,200.00 60.00 263.00 4,579.85 4,539.25 -389.22 -4,875.67 6,003,450.49 383,015.43 0.00 -2,695.05 7,300.00 60.00 263.00 4,629.85 4,589.25 -399.78 -4,961.63 6,003,441.23 382,929.33 0.00 -2,739.65 7,400.00 60.00 263.00 4,679.85 4,639.25 -410.33 -5,047.58 6,003,431.97 382,843.23 0.00 -2,784.26 7,500.00 60.00 263.00 4,729.85 4,689.25 -420.89 -5,133.54 6,003,422.71 382,757.14 0.00 -2,828.86 7,600.00 60.00 263.00 4,779.85 4,739.25 -431.44 -5,219.50 6,003,413.44 382,671.04 0.00 -2,873.46 7,700.00 60.00 263.00 4,829.85 4,789.25 -441.99 -5,305.46 6,003,404.18 382,584.94 0.00 -2,918.07 7,800.00 60.00 263.00 4,879.85 4,839.25 -452.55 -5,391.41 6,003,394.92 382,498.84 0.00 -2,962.67 7,900.00 60.00 263.00 4,929.85 4,889.25 -463.10 -5,477.37 6,003,385.66 382,412.74 0.00 -3,007.28 8,000.00 60.00 263.00 4,979.85 4,939.25 -473.66 -5,563.33 6,003,376.40 382,326.64 0.00 -3,051.88 8,100.00 60.00 263.00 5,029.85 4,989.25 -484.21 -5,649.28 6,003,367.14 382,240.55 0.00 -3,096.48 , 8,200.00 60.00 263.00 5,079.85 5,039.25 -494.77 -5,735.24 6,003,357.88 382,154.45 0.00 -3,141.09 8,300.00 60.00 263.00 5,129.85 5,089.25 -505.32 -5,821.20 6,003,348.61 382,068.35 0.00 -3,185.69 ' 8,400.00 60.00 263.00 5,179.85 5,139.25 -515.87 -5,907.15 6,003,339.35 381,982.25 0.00 -3,230.29 8,500.00 60.00 263.00 5,229.85 5,189.25 -526.43 -5,993.11 6,003,330.09 381,896.15 0.00 -3,274.90 8,600.00 60.00 263.00 5,279.85 5,239.25 -536.98 -6,079.07 6,003,320.83 381,810.05 0.00 -3,319.50 8,603.30 60.00 263.00 5,281.50 5,240.90 -537.33 -6,081.90 6,003,320.53 381,807.21 0.00 -3,320.97 Start DLS 3.20 TFO-111.50 8,700.00 58.91 259.64 5,330.66 5,290.06 -549.88 -6,164.21 6,003,309.21 381,724.73 3.20 -3,361.75 8,800.00 57.87 256.08 5,383.08 5,342.48 -567.78 -6,247.46 6,003,292.57 381,641.24 3.20 -3,398.90 8,842.11 57.47 254.56 5,405.60 5,365.00 -576.79 -6,281.88 6,003,284.08 381,606.69 3.20 -3,412.99 Albian 97 8,900.00 56.94 252.45 5,436.96 5,396.36 -590.60 -6,328.53 6,003,270.97 381,559.83 3.20 -3,430.83 9,000.00 56.12 248.74 5,492.12 5,451.52 -618.30 -6,407.19 6,003,244.46 381,480.78 3.20 -3,457.43 9,100.00 55.40 244.97 5,548.41 5,507.81 -650.77 -6,483.19 6,003,213.13 381,404.31 3.20 -3,478.63 9,200.00 54.81 241.13 5,605.63 5,565.03 -687.92 -6,556.28 6,003,177.09 381,330.67 3.20 -3,494.36 9,300.00 54.34 237.25 5,663.61 5,623.01 -729.64 -6,626.25 6,003,136.43 381,260.09 3.20 -3,504.57 9,400.00 53.99 233.33 5,722.17 5,681.57 -775.78 -6,692.87 6,003,091.30 381,192.79 3.20 -3,509.22 9,500.00 53.77 229.37 5,781.13 5,740.53 -826.21 -6,755.94 6,003,041.82 381,128.98 3.20 -3,508.30 9,593.73 53.69 225.65 5,836.60 5,796.00 -877.24 -6,811.65 6,002,991.64 381,072.51 3.20 -3,502.40 Albian 96 9,600.00 53.69 225.40 5,840.31 5,799.71 -880.78 -6,815.25 6,002,988.16 381,068.85 3.20 -3,501.83 9,700.00 53.73 221.43 5,899.52 5,858.92 -939.30 -6,870.63 6,002,930.48 381,012.60 3.20 -3,489.80 9,800.00 53.91 217.48 5,958.57 5,917.97 -1,001.60 -6,921.91 6,002,868.96 380,960.41 3.20 -3,472.28 9,900.00 54.21 213.54 6,017.28 5,976.68 -1,067.49 -6,968.91 6,002,803.79 380,912.42 3.20 -3,449.30 10,000.00 54.64 209.64 6,075.47 6,034.87 -1,136.76 -7,011.50 6,002,735.18 380,868.80 3.20 -3,420.93 ' 10,100.00 55.20 205.79 6,132.95 6,092.35 -1,209.18 -7,049.54 6,002,663.34 380,829.68 3.20 -3,387.28 L. 12/20/2010 4:32:00PM 15G i t\ COMPASS 2003.16 Build 69 ConocoPhillips 1-IALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-125 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:28+12.6 @ 40.60ft(Doyon 141) Project: Western North Slope MD Reference: Plan:28+12.6 @ 40.60ft(Doyon 141) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-125 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-125 Design: CD3-125wp05 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (0) (0) (ft) ft (ft) (ft) (ft) (ft) 6,148.95 10,200.00 55.87 202.00 6,189.55 6,148.95 -1,284.55 -7,082.92 6,002,588.49 380,795.18 3.20 -3,348.44 10,300.00 56.66 198.27 6,245.09 6,204.49 -1,362.61 -7,111.52 6,002,510.87 380,765.41 3.20 -3,304.54 1 10,400.00 57.56 194.61 6,299.40 6,258.80 -1,443.14 -7,135.27 6,002,430.72 380,740.46 3.20 -3,255.70 10,500.00 58.57 191.03 6,352.31 6,311.71 -1,525.87 -7,154.08 6,002,348.29 380,720.41 3.20 -3,202.09 10,600.00 59.67 187.53 6,403.65 6,363.05 -1,610.54 -7,167.90 6,002,263.83 380,705.32 3.20 -3,143.87 10,700.00 60.86 184.11 6,453.27 6,412.67 -1,696.91 -7,176.68 6,002,177.62 380,695.24 3.20 -3,081.23 10,800.00 62.13 180.77 6,501.00 6,460.40 -1,784.69 -7,180.41 6,002,089.91 380,690.20 3.20 -3,014.35 10,822.58 62.43 180.03 6,511.50 6,470.90 -1,804.68 -7,180.54 6,002,069.93 380,689.76 3.20 -2,998.68 Start DLS 2.00 TFO 0.00 10,868.89 63.36 180.03 6,532.60 6,492.00 -1,845.90 -7,180.56 6,002,028.71 380,689.12 2.00 -2,966.20 Top HRZ 10,900.00 63.98 180.03 6,546.40 6,505.80 -1,873.78 -7,180.58 6,002,000.84 380,688.69 2.00 -2,944.24 11,000.00 65.98 180.03 6,588.68 6,548.08 -1,964.40 -7,180.62 6,001,910.24 380,687.29 2.00 -2,872.86 11,100.00 67.98 180.03 6,627.79 6,587.19 -2,056.43 -7,180.66 6,001,818.23 380,685.87 2.00 -2,800.36 11,200.00 69.98 180.03 6,663.65 6,623.05 -2,149.77 -7,180.70 6,001,724.90 380,684.43 2.00 -2,726.84 11,208.36 70.15 180.03 6,666.50 6,625.90 -2,157.63 -7,180.70 6,001,717.05 380,684.30 2.00 -2,720.65 Start DLS 3.30 TFO-75.68 11,214.55 70.20 179.82 6,668.60 6,628.00 -2,163.45 -7,180.69 6,001,711.23 380,684.23 3.30 -2,716.05 Base HRZ 11,300.00 70.92 176.93 6,697.04 6,656.44 -2,243.99 -7,178.40 6,001,630.67 380,685.31 3.30 -2,651.18 11,357.51 71.43 175.00 6,715.60 6,675.00 -2,298.29 -7,174.57 6,001,576.33 380,688.33 3.30 -2,606.03 K-1 11,400.00 71.82 173.58 6,728.99 6,688.39 -2,338.41 -7,170.56 6,001,536.15 380,691.73 3.30 -2,571.94 11,477.19 72.56 171.03 6,752.60 6,712.00 -2,411.23 -7,160.71 6,001,463.20 380,700.48 3.30 -2,508.50 Top Kuparuk D 11,500.00 72.78 170.27 6,759.39 6,718.79 -2,432.72 -7,157.17 6,001,441.66 380,703.69 3.30 -2,489.39 11,600.00 73.80 167.00 6,788.15 6,747.55 -2,526.60 -7,138.30 6,001,347.52 380,721.16 3.30 -2,403.79 11,648.94 74.31 165.41 6,801.60 6,761.00 -2,572.30 -7,127.08 6,001,301.65 380,731.69 3.30 -2,360.87 Top Kuparuk C 11,678.83 74.63 164.44 6,809.60 6,769.00 -2,600.10 -7,119.59 6,001,273.75 380,738.76 3.30 -2,334.35 LCU 11,700.00 74.86 163.76 6,815.17 6,774.57 -2,619.75 -7,113.99 6,001,254.02 380,744.06 3.30 -2,315.42 11,760.36 75.52 161.82 6,830.60 6,790.00 -2,675.49 -7,096.73 6,001,198.03 380,760.49 3.30 -2,260.87 Top Nuiqsut 11,800.00 75.97 160.55 6,840.36 6,799.76 -2,711.85 -7,084.34 6,001,161.49 380,772.33 3.30 -2,224.59 11,895.36 77.06 157.52 6,862.60 6,822.00 -2,798.43 -7,051.16 6,001,074.43 380,804.20 3.30 -2,135.93 Base Nuiqsut 11,900.00 77.12 157.38 6,863.64 6,823.04 -2,802.61 -7,049.43 6,001,070.23 380,805.87 3.30 -2,131.58 12,000.00 78.31 154.23 6,884.92 6,844.32 -2,891.71 -7,009.38 6,000,980.54 380,844.57 3.30 -2,036.70 12,100.00 79.53 151.11 6,904.15 6,863.55 -2,978.88 -6,964.33 6,000,892.71 380,888.30 3.30 -1,940.28 12,200.00 80.78 148.02 6,921.25 6,880.65 -3,063.81 -6,914.42 6,000,807.04 380,936.93 3.30 -1,842.62 12,300.00 82.06 144.94 6,936.17 6,895.57 -3,146.24 -6,859.82 6,000,723.82 380,990.28 3.30 -1,744.06 12,372.49 83.00 142.73 6,945.60 6,905.00 -3,204.26 -6,817.41 6,000,665.17 381,031.81 3.30 -1,672.23 Start 50.00 hold at 12372.49 MD-Top Nechelik-7"x 8-3/4" 12,400.00 83.00 142.73 6,948.95 6,908.35 -3,225.99 -6,800.87 6,000,643.20 381,048.01 0.00 -1,644.92 12/20/2010 4.32:00PM Page 6 COMPASS 2003.16 Build 69 ORkiLNAL ConocoPhillips HALLIBI.JRTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-125 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:28+12.6 @ 40.60ft(Doyon 141) Project: Western North Slope MD Reference: Plan:28+12.6 @ 40.60ft(Doyon 141) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-125 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-125 Design: CD3-125wp05 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 6,911.09 12,422.49 83.00 142.73 6,951.69 6,911.09 -3,243.75 -6,787.36 6,000,625.23 381,061.26 0.00 -1,622.60 Start Build 3.02 12,500.00 85.34 142.73 6,959.57 6,918.97 -3,305.11 -6,740.66 6,000,563.19 381,107.02 3.02 -1,545.50 12,600.00 88.36 142.73 6,965.06 6,924.46 -3,384.56 -6,680.21 6,000,482.84 381,166.28 3.02 -1,445.67 12,623.95 89.08 142.73 6,965.60 6,925.00 -3,403.62 -6,665.70 6,000,463.57 381,180.49 3.02 -1,421.73 Start DLS 0.01 TFO-83.31 12,700.00 89.08 142.73 6,966.82 6,926.22 -3,464.13 -6,619.66 6,000,402.39 381,225.62 0.01 -1,345.70 12,800.00 89.08 142.72 6,968.42 6,927.82 -3,543.69 -6,559.10 6,000,321.93 381,284.97 0.01 -1,245.72 12,900.00 89.08 142.71 6,970.03 6,929.43 -3,623.24 -6,498.53 6,000,241.48 381,344.33 0.01 -1,145.74 13,000.00 89.08 142.71 6,971.63 6,931.03 -3,702.79 -6,437.95 6,000,161.04 381,403.70 0.01 -1,045.76 13,100.00 89.08 142.70 6,973.23 6,932.63 -3,782.33 -6,377.37 6,000,080.60 381,463.08 0.01 -945.78 13,200.00 89.08 142.70 6,974.83 6,934.23 -3,861.87 -6,316.78 6,000,000.17 381,522.47 0.01 -845.80 13,300.00 89.08 142.69 6,976.43 6,935.83 -3,941.40 -6,256.18 5,999,919.75 381,581.86 0.01 -745.82 13,400.00 89.09 142.68 6,978.02 6,937.42 -4,020.92 -6,195.57 5,999,839.33 381,641.26 0.01 -645.84 13,500.00 89.09 142.68 6,979.62 6,939.02 -4,100.44 -6,134.95 5,999,758.92 381,700.67 0.01 -545.86 13,600.00 89.09 142.67 6,981.21 6,940.61 -4,179.95 -6,074.33 5,999,678.51 381,760.09 0.01 -445.88 13,700.00 89.09 142.67 6,982.81 6,942.21 -4,259.46 -6,013.69 5,999,598.11 381,819.52 0.01 -345.90 13,800.00 89.09 142.66 6,984.40 6,943.80 -4,338.96 -5,953.05 5,999,517.72 381,878.95 0.01 -245.92 13,870.58 89.09 142.66 6,985.52 6,944.92 -4,395.06 -5,910.25 5,999,460.98 381,920.90 0.01 -175.36 13,900.00 89.09 142.66 6,985.99 6,945.39 -4,418.45 -5,892.40 5,999,437.33 381,938.40 0.00 -145.94 13,942.22 89.09 142.66 6,986.66 6,946.06 -4,452.01 -5,866.80 5,999,403.39 381,963.49 0.00 -103.73 Start 5405.32 hold at 13942.22 MD 14,000.00 89.09 142.66 6,987.58 6,946.98 -4,497.94 -5,831.75 5,999,356.94 381,997.84 0.00 -45.96 14,100.00 89.09 142.66 6,989.17 6,948.57 -4,577.44 -5,771.10 5,999,276.55 382,057.29 0.00 54.02 14,200.00 89.09 142.66 6,990.76 6,950.16 -4,656.93 -5,710.45 5,999,196.17 382,116.73 0.00 154.00 14,300.00 89.09 142.66 6,992.35 6,951.75 -4,736.42 -5,649.80 5,999,115.78 382,176.18 0.00 253.98 14,400.00 89.09 142.66 6,993.94 6,953.34 -4,815.91 -5,589.15 5,999,035.39 382,235.62 0.00 353.96 14,500.00 89.09 142.66 6,995.53 6,954.93 -4,895.40 -5,528.50 5,998,955.01 382,295.06 0.00 453.95 14,600.00 89.09 142.66 6,997.12 6,956.52 -4,974.90 -5,467.85 5,998,874.62 382,354.51 0.00 553.93 14,700.00 89.09 142.66 6,998.71 6,958.11 -5,054.39 -5,407.20 5,998,794.23 382,413.95 0.00 653.91 14,800.00 89.09 142.66 7,000.30 6,959.70 -5,133.88 -5,346.55 5,998,713.85 382,473.40 0.00 753.89 14,900.00 89.09 142.66 7,001.89 6,961.29 -5,213.37 -5,285.90 5,998,633.46 382,532.84 0.00 853.87 15,000.00 89.09 142.66 7,003.48 6,962.88 -5,292.86 -5,225.25 5,998,553.07 382,592.29 0.00 953.85 15,100.00 89.09 142.66 7,005.07 6,964.47 -5,372.36 -5,164.60 5,998,472.68 382,651.73 0.00 1,053.83 15,200.00 89.09 142.66 7,006.66 6,966.06 -5,451.85 -5,103.95 5,998,392.30 382,711.18 0.00 1,153.81 15,300.00 89.09 142.66 7,008.25 6,967.65 -5,531.34 -5,043.30 5,998,311.91 382,770.62 0.00 1,253.79 15,400.00 89.09 142.66 7,009.84 6,969.24 -5,610.83 -4,982.65 5,998,231.52 382,830.07 0.00 1,353.77 15,500.00 89.09 142.66 7,011.43 6,970.83 -5,690.32 -4,922.00 5,998,151.14 382,889.51 0.00 1,453.75 15,600.00 89.09 142.66 7,013.02 6,972.42 -5,769.82 -4,861.35 5,998,070.75 382,948.96 0.00 1,553.73 15,700.00 89.09 142.66 7,014.61 6,974.01 -5,849.31 -4,800.70 5,997,990.36 383,008.40 0.00 1,653.72 15,800.00 89.09 142.66 7,016.20 6,975.60 -5,928.80 -4,740.04 5,997,909.98 383,067.85 0.00 1,753.70 15,900.00 89.09 142.66 7,017.79 6,977.19 -6,008.29 -4,679.39 5,997,829.59 383,127.29 0.00 1,853.68 16,000.00 89.09 142.66 7,019.38 6,978.78 -6,087.78 -4,618.74 5,997,749.20 383,186.74 0.00 1,953.66 16,100.00 89.09 142.66 7,020.97 6,980.37 -6,167.28 -4,558.09 5,997,668.81 383,246.18 0.00 2,053.64 16,200.00 89.09 142.66 7,022.56 6,981.96 -6,246.77 -4,497.44 5,997,588.43 383,305.63 0.00 2,153.62 12/20/2010 4.32:00PM Page 7 COMPASS 2003.16 Build 69 0 RGIN At L ConocoPhillips HALLIBURT©IV Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-125 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:28+12.6 @ 40.60ft(Doyon 141) Project: Western North Slope MD Reference: Plan:28+12.6 @ 40.60ft(Doyon 141) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-125 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-125 Design: CD3-125wp05 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (0) (0) (ft) ft (ft) (ft) (ft) (ft) 6,983.55 16,300.00 89.09 142.66 7,024.15 6,983.55 -6,326.26 -4,436.79 5,997,508.04 383,365.07 0.00 2,253.60 16,400.00 89.09 142.66 7,025.74 6,985.14 -6,405.75 -4,376.14 5,997,427.65 383,424.52 0.00 2,353.58 16,500.00 89.09 142.66 7,027.33 6,986.73 -6,485.25 -4,315.49 5,997,347.27 383,483.96 0.00 2,453.56 16,600.00 89.09 142.66 7,028.92 6,988.32 -6,564.74 -4,254.84 5,997,266.88 383,543.41 0.00 2,553.54 16,700.00 89.09 142.66 7,030.51 6,989.91 -6,644.23 -4,194.19 5,997,186.49 383,602.85 0.00 2,653.52 1 16,800.00 89.09 142.66 7,032.10 6,991.50 -6,723.72 -4,133.54 5,997,106.11 383,662.30 0.00 2,753.50 16,900.00 89.09 142.66 7,033.69 6,993.09 -6,803.21 -4,072.89 5,997,025.72 383,721.74 0.00 2,853.48 17,000.00 89.09 142.66 7,035.28 6,994.68 -6,882.71 -4,012.24 5,996,945.33 383,781.19 0.00 2,953.47 17,100.00 89.09 142.66 7,036.87 6,996.27 -6,962.20 -3,951.59 5,996,864.94 383,840.63 0.00 3,053.45 17,200.00 89.09 142.66 7,038.46 6,997.86 -7,041.69 -3,890.94 5,996,784.56 383,900.08 0.00 3,153.43 17,300.00 89.09 142.66 7,040.05 6,999.45 -7,121.18 -3,830.29 5,996,704.17 383,959.52 0.00 3,253.41 3,353.39 17,400.00 89.09 142.66 7,041.64 7,001.04 -7,200.67 -3,769.64 5,996,623.78 384,018.97 0.00 17,500.00 89.09 142.66 7,043.23 7,002.63 -7,280.17 -3,708.99 5,996,543.40 384,078.41 0.00 3,453.37 3,553.35 17,600.00 89.09 142.66 7,044.82 7,004.22 -7,359.66 -3,648.34 5,996,463.01 384,137.85 0.00 17,700.00 89.09 142.66 7,046.41 7,005.81 -7,439.15 -3,587.68 5,996,382.62 384,197.30 0.00 3,653.33 17,800.00 89.09 142.66 7,048.00 7,007.40 -7,518.64 -3,527.03 5,996,302.24 384,256.74 0.00 3,753.31 17,900.00 89.09 142.66 7,049.59 7,008.99 -7,598.13 -3,466.38 5,996,221.85 384,316.19 0.00 3,853.29 18,000.00 89.09 142.66 7,051.18 7,010.58 -7,677.63 -3,405.73 5,996,141.46 384,375.63 0.00 3,953.27 18,100.00 89.09 142.66 7,052.77 7,012.17 -7,757.12 -3,345.08 5,996,061.08 384,435.08 0.00 4,053.25 18,200.00 89.09 142.66 7,054.36 7,013.76 -7,836.61 -3,284.43 5,995,980.69 384,494.52 0.00 4,153.23 18,300.00 89.09 142.66 7,055.95 7,015.35 -7,916.10 -3,223.78 5,995,900.30 384,553.97 0.00 4,253.22 18,400.00 89.09 142.66 7,057.54 7,016.94 -7,995.59 -3,163.13 5,995,819.91 384,613.41 0.00 4,353.20 18,500.00 89.09 142.66 7,059.13 7,018.53 -8,075.09 -3,102.48 5,995,739.53 384,672.86 0.00 4,453.18 18,600.00 89.09 142.66 7,060.72 7,020.12 -8,154.58 -3,041.83 5,995,659.14 384,732.30 0.00 4,553.16 18,700.00 89.09 142.66 7,062.31 7,021.71 -8,234.07 -2,981.18 5,995,578.75 384,791.75 0.00 4,653.14 18,800.00 89.09 142.66 7,063.90 7,023.30 -8,313.56 -2,920.53 5,995,498.37 384,851.19 0.00 4,753.12 18,900.00 89.09 142.66 7,065.49 7,024.89 -8,393.05 -2,859.88 5,995,417.98 384,910.64 0.00 4,853.10 19,000.00 89.09 142.66 7,067.08 7,026.48 -8,472.55 -2,799.23 5,995,337.59 384,970.08 0.00 4,953.08 19,100.00 89.09 142.66 7,068.67 7,028.07 -8,552.04 -2,738.58 5,995,257.21 385,029.53 0.00 5,053.06 19,200.00 89.09 142.66 7,070.26 7,029.66 -8,631.53 -2,677.93 5,995,176.82 385,088.97 0.00 5,153.04 19,300.00 89.09 142.66 7,071.85 7,031.25 -8,711.02 -2,617.28 5,995,096.43 385,148.42 0.00 5,253.02 19,346.97 89.09 142.66 7,072.60 7,032.00 -8,748.36 -2,588.79 5,995,058.67 385,176.34 0.00 5,299.99 CD3-I 25May10 Toe Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) C) (ft) (ft) (ft) (ft) (ft) CD3-I 25May10 Toe 0.00 0.00 7,072.60 -8,748.36 -2,588.79 5,995,058.67 385,176.34 -plan hits target center -Point CD3-I 25May10 Heel 0.00 0.00 6,945.60 -3,198.85 -6,850.26 6,000,671.08 380,999.04 -plan misses target center by 23.22ft at 12348.93ft MD(6942.67 TVD,-3185.57 N,-6831.45 E) -Point 12/20/2010 4:32.00PM Page 8 COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-125 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:28+12.6 @ 40.60ft(Doyon 141) Project: Western North Slope MD Reference: Plan:28+12.6 @ 40.60ft(Doyon 141) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-125 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-125 Design: CD3-125wp05 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 2,940.30 2,450.00 9-5/8"x 12-1/4" 9-5/8 12-1/4 12,372.49 6,945.60 7"x 8-3/4" 7 8-3/4 19,347.54 7,072.61 3-1/2"x6-1/8" 3-1/2 6-1/8 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (`) (') 8,842.11 5,405.60 Albian 97 6,279.50 4,119.60 K-2 Basal 12,372.49 6,945.60 Top Nechelik 2,649.84 2,304.60 C-40 0.00 11,648.94 6,801.60 Top Kuparuk C 11,357.51 6,715.60 K-1 11,477.19 6,752.60 Top Kuparuk D 11,678.83 6,809.60 LCU 1,229.28 1,214.60 Base Permafrost 0.00 6,029.50 3,994.60 K-3 Basal 2,985.50 2,472.60 C-30 3,743.50 2,851.60 C-20 11,760.36 6,830.60 Top Nuiqsut 5,733.50 3,846.60 K-3 11,895.36 6,862.60 Base Nuiqsut 11,214.55 6,668.60 Base HRZ 10,868.89 6,532.60 Top HRZ , 6,071.50 4,015.60 K-2 9,593.73 5,836.60 Albian 96 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 291.50 291.50 0.00 0.00 Start Build 1.50 541.68 541.50 6.27 -5.26 Start Build 2.20 895.08 891.50 42.24 -35.44 Start DLS 3.04 TFO-63.49 2,677.50 2,318.60 88.09 -988.26 Start 5925.80 hold at 2677.50 MD 8,603.30 5,281.50 -537.33 -6,081.90 Start DLS 3.20 TFO-111.50 10,822.58 6,511.50 -1,804.68 -7,180.54 Start DLS 2.00 TFO 0.00 11,208.36 6,666.50 -2,157.63 -7,180.70 Start DLS 3.30 TFO-75.68 12,372.49 6,945.60 -3,204.26 -6,817.41 Start 50.00 hold at 12372.49 MD 12,422.49 6,951.69 -3,243.75 -6,787.36 Start Build 3.02 12,623.95 6,965.60 -3,403.62 -6,665.70 Start DLS 0.01 TFO-83.31 13,942.22 6,986.66 -4,452.01 -5,866.80 Start 5405.32 hold at 13942.22 MD 19,347.54 TD at 19347.54 12/20/2010 4:32.00PM Page 9 COMPASS 2003.16 Build 69 ORIGINAL 2 N m LQ L L m 3 m M C W O J QL '6 I ° N Z "E a) O C O t0 N ■ LI c00. c • Q N a) CD , 2 v G o Ln iii et 2 A ,- oo�\ UCe x CC/ t Z2 - i Z a m o V+ eh c p E c V O c_ coirS p E N w CC 0 Z a o N 3 _ r s Q = Y m ... 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F8 eh 1 - HALLIBURTON Conor Phillips CD3-125wp05 Alaska Sperry Drilling ANTI-COLLISION SETTINGS 11:38,December 20 2010 Interpolation Method: MD, interval:25.00 Depth Range From: 28.00 To 19347.54 Results Limited By: Centre Distance:2131.95 GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 1550.00 CD3-125wp05(Plan: CD3-125) GYD-GC-SS 1550.00 2940.30 CD3-125wp05(Plan: CD3-125) MWD+IFR-AK-CAZ-SC 2940.30 12372.49 CD3-125wp05(Plan: CD3-125) MWD+IFR-AK-CAZ-SC 12372.49 19347.54 CD3-125wp05(Plan: CD3-125) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2450.00 2940.30 9-5/8"x 12-1/4" 9-5/8 6945.60 12372.49 7"x 8-3/4" 7 7072.60 19347.54 3-1/2"x 6-1/8" 3-1/2 a • L o am U tau MU gl- �lml6 l - • c 60 4g1Il II �1111�VIII" � � I Q III III in Ma' 'I IIIIII I1 I IIIIII im1' 11 '- 1111 r1111 V 111111 0 III II I ` I I I I I I I I I I I I I 0 2500 5000 7500 10000 12500 15000 17500 Measured Depth LEGEND -X- CD3-112,CD3-112,CD3-112 V3 $ CD3-122,CD3-122,CD3-122 VO -A- Plan:CD3-120,Plan:CD3-120,CD3-120wp06 VO CD3-113,CD3-113,CD3-113 V6 CD3-123,CD3-123,CD3-123 VO Plan:CD3-126,Plan:CD3-126,CD3-126wp04 VO -e-- CD3-114,CD3-114,CD3-114 V14 --A- CD3-124,CD3-124,CD3-124 VO - Plan:CD3-127,Plan:CD3-127,CD3-127wp03 VO -A- CD3-115,CD3-115,CD3-115 VO CD3-316,CD3-316,CD3-316 VO Plan:CD3-128,Plan:CD3-128,CD3-128wp02 VO �- CD3-117,CD3-117,CD3-117 VO -e- CD3-316,CD3-316A,CD3-316A VO -X- Plan:CD3-129,Plan:CD3-129,CD3-129wp01 VO -X- CD3-118,CD3-118,CD3-118 VO -8- CD3-316,CD3-316APB1,CD3-316APB1 VO CO3-125wp05 -e- CD3-121,CD3-121,CD3-121 VO -e- Plan:CD3-119,Plan:CD3-119,CD3-119wp07 VO URIGINAL HALLIBURTON ConocoPhillips CD3-125wp05 Alaska Sperry Drilling ANTI-COLLISION SETTINGS 11:38,December 202010 Interpolation Method: MD, interval: 25.00 Depth Range From: 28.00 To 19347.54 Results Limited By: Centre Distance:2131.95 GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 1550.00 CD3-125wp05(Plan: CD3-125) GYD-GC-SS 1550.00 2940.30 CD3-125wp05(Plan: CD3-125) MWD+IFR-AK-CAZ-SC 2940.30 12372.49 CD3-125wp05(Plan: CD3-125) MWD+IFR-AK-CAZ-SC 12372.49 19347.54 CD3-125wp05(Plan: CD3-125) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2450.00 2940.30 9-5/8"x 12-1/4" 9-5/8 6945.60 12372.49 7"x 8-3/4" 7 7072.60 19347.54 3-1/2" x 6-1/8" 3-1/2 0 n o. a 3 a N N_ C. !t V 0 U U 0 0 0 0 u V U U U U U 7/ '1' ')11 1 I' - 4#41/ i CZ /i r CI) - Ln a> - c U 030- hi h 0 , , I I 1- I I 1 I I I I I I 1 I I I I I I I I I I I I I 0 500 1000 1500 2000 2500 3000 3500 Measured Depth LEGEND -(- CD3-112,CD3-112,CD3-112 V3 -9-- CD3-122,CD3-122,CD3-122 VO -s- Plan:CD3-120,Plan:CD3-120,C133-120wp08 VO CD3-113,CD3-113,CD3-113 V6 -6- CD3-123,CD3-123,CD3-123 VO -i- Plan:CD3-126,Plan:CD3-126,CD3-126wp04 VO -e-- CD3-114,CD3-114,CD3-114 V14 CD3-124,CD3-124,CD3-124 VO -X- Plan:CO3-127,Plan:CD3-127,CD3-127wp03 VO CD3-115,CD3-115,CD3-115 VO - CD3-316,CD3-316,CD3-316 VO -.9.- Plan:CD3-128,Plan:CD3-128,CD3-128wp02 VO CO3-117,CD3-117,CD3-117 VO -- CD3-316,CD3-316A,CD3-316A V0 --- Plan:CD3-129,Plan:CD3-129,CD3-129wp01 VO -X- CD3-118,CD3-118,CD3-118 VO $ CD3-316,CD3-316APB1,CD3-316APB1 VO -1--. 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SEC.LINE 0/S EXIST WELL 'Y' 'X' LAT.(N) LONG.(W) FSL FEL GND PAD CD3-X98 6,003,630.37 1.528,434.35 70' 25' 09.267" 150' 54' 44.278" 1392' 642' 7.3 12.5 0D3-X99 6,003,625.99 1,528,415.38 70' 25' 09.221" 150' 54' 44.833" 1387' 661' 7.3 12.8 CD3-301 6,003,621.33 1.528,395.58 70' 25' 09.172" 150' 54' 45.411" 1382' 680' 7.3 13.5 0D3-302 6,003,616.72 1,528,376.38 70' 25' 09.124" 150' 54' 45.972" 1377' 700' 7.3 13.2 CD3-303 6.003,612.52 1,528,356.72 70' 25' 09.080" 150' 54' 46.547" 1373' 719' 7.3 13.3 CD3-304 6,003,607.82 1,528,337.04 70' 25' 09.031" 150' 54' 47.122" 1368' 739' 7.3 13.4 CD3-305 6,003,603.48 1,528,317.56 70' 25' 08.985" 150' 54' 47.691" 1363' 758' 7.3 13.6 CD3-106 6,003,599.43 1,528,298.37 70' 25' 08.942" 150' 54' 48.252" 1359' 777' 7.3 13.4 CD3-107 6,003,594.38 1,528,278.93 70' 25' 08.890" 150' 54' 48.820" 1354' 797' 7.3 13.2 CD3-108 6,003,589.85 1.528,259.61 70' 25' 08.842" 150' 54' 49.385" 1349' 816' 7.3 13.1 CD3-109 6,003,585.27 1,528,239.85 70' 25' 08.794" 150' 54' 49.962" 1344' 836' 7.3 13.1 CD3-110 6,003,580.97 1,528,220.32 70' 25' 08.749" 150' 54' 50.533" 1339' 855' 7.3 13.0 003-111 6,003,576.13 1,528.201.08 70' 25' 08.699" 150' 54' 51.095" 1334' 874' 7.3 12.9 CD3-112 6,003,572.43 1,528,181.20 70' 25' 08.660" 150' 54' 51.676" 1330' 894' 7.3 13.1 003-113 6,003,567.62 1,528,161.38 70' 25' 08.609" 150' 54' 52.255" 1325' 914' 7.3 13.1 CD3-114 6,003,563.04 1,528,142.21 70' 25' 08.561" 150' 54' 52.815" 1320' 933' 7.3 13.3 CD3-115 6,003,558.57 1,528,122.60 70' 25' 08.515" 150' 54' 53.388" 1315' 953' 7.3 13.2 CD3-316A 6,003,554.04 1,528,103.39 70' 25' 08.467" 150' 54' 53.950" 1311' 972' 7.3 , 13.2 003-117 6,003,549.51 1,528,083.99 70' 25' 08.420" 150' 54' 54.516" 1306' 991' 7.3 13.1 CD3-118 6,003,544.88 1,528,064.44 70' 25' 08.372" 150' 54' 55.086" 1301' 1011' 7.3 12.8 CD3-X19 6.003,540.17 1,528,044.86 70' 25' 08.322" 150' 54' 55.660" 1296' 1030' 7.3 12.8 CD3-X20 6,003,535.95 1.528,025.39 70' 25' 08.278" 150' 54' 56.229" 1291' 1050' 7.3 12.6 CD3-X21 6,003,531.41 1,528,006.04 70' 25' 08.230" 150' 54' 56.794" 1286' 1069' 7.3 12.5 CD3-122 6,003,527.00 1,527,986.67 70' 25' 08.184" 150' 54' 57.360" 1282' 1088' 7.3 12.6 CD3-X23 6,003,522.43 1,527,967.12 70' 25' 08.136" 150' 54' 57.932" 1777' 1108' 7.3 12.6 CD3-124 R 003 518 17 1 527 947 59 70' 75' 08 091" 150' 54' 58"507" 1777' 1177' 7 3 17 5 0D3-X25 6,003.513.62 1,527,927.89 70' 25' 08.044" 150' 54' 59.078" 1267' 1147' 7.3 12.6 UU.5-X2b 5,003,508.9/ 1,527,908.70 70' 25' 07.995" 150' 54" 59.6,59" 1263' 1166' /•5 12.6 CD3-X27 6,003,503.45 1,527.889.34 70' 25' 07.948" 150' 55' 00.204" 1258' 1185' 7.3 12.6 NOTES: 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L.) ALPINE MODULE:CD30 UNIT: CD Conoc.Phillips ALPINE PROJECT CD-3 WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05-03-03-1A-2 3-17-05 CE-CD30-111 2 OF 3 9 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME � /Z c> PTD# '/ Development Service Exploratory Stratigraphic Test Non div(i -Conventional/ Well FIELD: (� ( / t,�zv'✓ POOL: l 'yj (1C I Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability 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 through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and 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 program. • Rev: 1/11/2008 m 'a m I- 17 m -n -0 3 I 11 0 m 0 0 'a o c a o ° r 0 (13 � � -, o13 N _, 7 N .a) m N.co Wv Wv `° w v o ca 73 O co p) N a) O a) 7 0 3 N ° O (a Oo m O iv m co O W CO W W C.) W W W CO CO N IV N N N N N N.) N N.) CO CO V C) C.11 A W N o i (o co -.4 CA 01 A CO N.) -+ 0 CO CO V 0) Cr A C..) N -, 0 CO CO 0) 01 A W N -, 0 v "30 m y CD o n en o -a K vCW W 0 =... D = D C 0 CCc0 'U D * 0 m -0 o o �, cn * * * C r- m Z C O 0 CD CD 0) m CD 0 < Taa) o mmm0 =N CD Cn -� a = 73 3 m m m - _ _ _ co0 ( rm (jN3 "Oo -0 -oz O Q 3m . a C uxx m m Ca o c co < C) C oo 0 om ov v < o O O O mc m> . 0 0Nac ° m . 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' Oco co cr CD to ° QMO am d ( N mcn C a A cQm = o cn N a Q -° m y c c o ° < j_ 3 am4 T G. 0X O 9 a N N O CD o N °n C5 CO D D 2 = a n' ° O m ci a (.,) m O * 3 0 0, , . , O co 3 o 4k 3m 7 N7 � < C Nuc- •Z T " N m m 2 m O m 3 m 3 _ m 17.). ° CA C) N o Z z z -< -< z Z z -< -< -< -< z -< z -< -< -< z -< z -< z z z -< -< -< -< -< -< -< -< -< -< -< Z Z Z N .N > > > mn m > 0 0 �m mN n m > m D m m m o m > �m > > > m 'm m m 2 m m m m m m o D D 0 m < m x c 0 0 o K 0 m 0 z m 0 0 0 0 -1 D 3 O O > N < o co 7 ° N 7 7 7 O Q Z CD CD 2 CO cnX CD X CD 7 > 0 Cn cn r 3 m 3 N 6 p m 3 f .O O m CD m G O CD a' X cn a) n c c m Z 7 7 F D ° coZ a m N g o -° 0) m 0) m i_ 3 m 3 CO m X A ,� a) 76 N O O O 0 am 3 CO m °) CD m ° ° cn c A m D m C-D a o v N -v *. m D p. 0 0 0 < (n cD c o_ c < m m O = m m N o m n CD < O C "O N 7 O 0, 0 m m mZ ZZm cfl 6 (0 o CD w o - 0 O O O O O O r 0- o w a 3 7-0 �' ° CD 01 01 01 m CO 0 CI) 7 W CO Z m Cn N m m CA co O p co CO CO rn N 7 CO N n D N N ° 3 3 0 O O C) '� N 5 7 N CA 7 rcn C co — N m m . co N 3 co CO j y W (A O O =' N 4 O O - O A no 7 N 01 O c o A co _ = O N n Q O a O O co ° O ° m m ° O m C) rn v = o co 0 m y moo-'' K rn -m0 m v m m -o coo 0 w '' N a o o o a o° T m 7 C N 0_CT N * N C) (< if D a * a) 0 co N a) � Cn a — - * = a m 5 5 CD a 7 g C, a m a) -. m CO co N a m c v) s 4 < —co c 7 .n. .n-. CO= 01 o m O O O. W CO CO NO 0_ m a (O * cm .O fl. DD Cn 7 (n •Cn •cn = m o co 3 cQ c (' 7 a v Ei a c o m o m D O 3 0 w cD O F 0 w ? < 7 .^N. CD 0 --4 O 3 3 co o cD am) ° 3 "' O Cn CD = 7 c Q m s U N C 7 7 CJ) N = O O 0 = m c0an 3 c Q (7-, 0 O m y N O Ca (n a) L_I f___I 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 information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Apr 12 11:05:32 2011 Reel Header Service name LISTPE Date 11/04/12 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 11/04/12 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Colville River MWD/MAD LOGS WELL NAME: CD3-125 PB1 API NUMBER: 501032063270 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 12-APR-11 JOB DATA MWD RUN 3 JOB NUMBER: K-MW-000789684 LOGGING ENGINEER: PAUL ORTH OPERATOR WITNESS: DAVE BURLEY SURFACE LOCATION SECTION: 5 TOWNSHIP: 12N RANGE: 5E FNL: 4012 FSL: FEL: 1147 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRICK FLOOR: 49. 19 GROUND LEVEL: 12. 60 OA 0 — ( 15g e0S-95 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.750 9. 625 2961.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD) . 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) . 3. MWD RUN 100 WAS A CLEAN OUT RUN - NO DATA PRESENTED. 4 . MWD RUN 200 WAS DIRECTIONAL ONLY - NO DATA PRSENTED. 5. MWD RUN 300 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-P4) , PRESSURE WHILE DRILLING (PWD) , COMPENSATED THERMAL NEUTRON POROSITY (CTN) , AZIMUTHAL LITHO-DENSITY (ALD) ) , ACOUSTIC CALIPER (ACAL) , AND DRILLSTRING DYNAMICS SENSOR (DDSr) . 6. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILL SITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 7. MWD RUNS 100 - 300 REPRESENTS WELL CD3-125PB1 WITH API # 50-103-20632-70. THIS WELL REACHED A TOTAL DEPTH OF 12, 754 ' MD, 7, 006. 92 TVD. MNEMONIC CURVE DESCRIPTION RO9P 9in Phase Resistivity R15P 15in Phase Resistivity R27P 27in Phase Resistivity R39P 39in Phase Resistivity EWXT EWR Formation Exp Time ROPA Avg Rate of Penetration DGRC DGR Combined Gamma Ray APEL ALD LCRB Pe Factor ACDL ALD LCRB Comp Density ADCL ALD LCRB Den Correction TNPS CTN Porosity Sandstone TNFA CTN Far Avg Count Rate TNNA CTN Near Avg Count Rate ACHD ACAL Hole Diameter ALRPM ALD RPM PARAMETERS USED IN NUCLEAR LOG PROCESSING: HOLE SIZE: ACAL Hole Diameter MUD WEIGHT: 9.5 - 10.0 PPG WHOLE MUD CHLORIDES: 500 - 3, 800 PPM CL FORMATION WATER SALINITY: 14, 545 PPM CL FLUID DENSITY: 1.0 G/CC MATRIX DENSITY 2. 65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0. 6 FT, EXCEPT FOR GAMMA RAY AND ROP. THESE CURVES ARE SMOOTHED WITH A 1. 1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/12 Maximum Physical Record65535 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 NPHI 2952.5 12664 .5 NCNT 2952.5 12664 .5 RHOB 2952.5 12678.0 FCNT 2952.5 12664 .5 DRHO 2952.5 12678.0 RPX 2952.5 12713.5 RPM 2952.5 12713.5 GR 2952.5 12699.5 CALN 2952.5 12678.0 RPS 2952.5 12713.5 PEF 2952.5 12678.0 CALA 2952.5 12667.5 FET 2952.5 12713.5 RPD 2952.5 12713.5 ROP 2965.5 12754 .5 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 3 2952.5 12754 .5 $ 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 . 1IN 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 CALA MWD IN 4 1 68 4 2 RHOB MWD G/CC 4 1 68 8 3 DRHO MWD G/CC 4 1 68 12 4 CALN MWD IN 4 1 68 16 5 PEF MWD B/E 4 1 68 20 6 GR MWD API 4 1 68 24 7 FET MWD HR 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 RPS MWD OHMM 4 1 68 36 10 RPM MWD OHMM 4 1 68 40 11 RPD MWD OHMM 4 1 68 44 12 ROP MWD FPH 4 1 68 48 13 FCNT MWD CP30 4 1 68 52 14 NCNT MWD CP30 4 1 68 56 15 NPHI MWD PU 4 1 68 60 16 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2952.5 12754 .5 7853.5 19605 2952.5 12754 .5 CALA MWD IN 8.3 11.24 8.89775 19009 2952.5 12667.5 RHOB MWD G/CC 1.54 3.201 2.42136 19452 2952.5 12678 DRHO MWD G/CC -3.283 0.204 0.0493567 19452 2952.5 12678 CALN MWD IN 8 .25 12. 18 8.77391 19452 2952.5 12678 PEF MWD B/E 2.01 13.86 3.15903 19452 2952.5 12678 GR MWD API 27.53 457.08 118.04 19495 2952.5 12699.5 FET MWD HR 0. 16 827.55 3. 11142 19523 2952.5 12713.5 RPX MWD OHMM 0.59 1848. 15 5.43106 19523 2952.5 12713.5 RPS MWD OHMM 0.21 1848.28 5.52919 19523 2952.5 • 12713.5 RPM MWD OHMM 0.21 2000 6. 18251 19523 2952.5 12713.5 RPD MWD OHMM 0. 15 2000 7.55693 19523 2952.5 12713.5 ROP MWD FPH 19.81 438. 97 178. 163 19579 2965.5 12754 .5 FCNT MWD CP30 413. 17 2155 759. 155 19425 2952. 5 12664 .5 NCNT MWD CP30 85484 144528 108877 19425 2952. 5 12664 .5 NPHI MWD PU 12.56 60.73 31.5659 19425 2952.5 12664 .5 First Reading For Entire File 2952.5 Last Reading For Entire File 12754 .5 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/12 Maximum Physical Record65535 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 11/04/12 Maximum Physical Record65535 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH EWXT 2952.5 12713.5 TNNA 2952.5 12664 .5 TNFA 2952.5 12664 .5 R39P 2952.5 12713.5 R27P 2952.5 12713.5 R15P 2952.5 12713.5 TNPS 2952.5 12664 .5 R09P 2952.5 12713.5 DGRC 2952.5 12699.5 ADCL 2952.5 12678.0 APEL 2952.5 12678 . 0 ACHD 2952.5 12667 . 5 AHSI 2952.5 12678.0 ACDL 2952.5 12678.0 ROPA 2965.5 12754 .5 LOG HEADER DATA DATE LOGGED: 15-MAR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88 .2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 12754 .0 TOP LOG INTERVAL (FT) : 2965.0 BOTTOM LOG INTERVAL (FT) : 12754 .0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 58. 5 MAXIMUM ANGLE: 84 . 6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 275518 EWR4 ELECTROMAG. RESIS. 4 230203 CTN COMP THERMAL NEUTRON 185457 ALD Azimuthal Litho-Dens 125035 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 8 .750 DRILLER'S CASING DEPTH (FT) : 2961.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G) : 9. 65 MUD VISCOSITY (S) : 40.0 MUD PH: 9.0 MUD CHLORIDES (PPM) : 700 FLUID LOSS (C3) : 2. 6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 1.800 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .870 152.0 MUD FILTRATE AT MT: 1.500 70.0 MUD CAKE AT MT: 2.000 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MWD030 IN 4 1 68 4 2 RHOB MWD030 G/CC 4 1 68 8 3 DRHO MWD030 G/CC 4 1 68 12 4 CALN MWD030 IN 4 1 68 16 5 PEF MWD030 B/E 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 RPX MWD030 OHMM 4 1 68 32 9 RPS MWD030 OHMM 4 1 68 36 10 RPM MWD030 OHMM 4 1 68 40 11 RPD MWD030 OHMM 4 1 68 44 12 ROP MWD030 FPH 4 1 68 48 13 FCNT MWD030 CP30 4 1 68 52 14 NCNT MWD030 CP30 4 1 68 56 15 NPHI MWD030 PU 4 1 68 60 16 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2952.5 12754 .5 7853.5 19605 2952.5 12754 .5 CALA MWD030 IN 8.3 11.24 8.89775 19009 2952.5 12667.5 RHOB MWD030 G/CC 1.54 3.201 2. 42136 19452 2952. 5 12678 DRHO MWD030 G/CC -3.283 0.204 0.0493567 19452 2952.5 12678 CALN MWD030 IN 8.25 12. 18 8.77391 19452 2952.5 12678 PEF MWD030 B/E 2.01 13.86 3. 15903 19452 2952.5 12678 GR MWD030 API 27.53 457 . 08 118.04 19495 2952.5 12699.5 FET MWD030 HR 0. 16 827.55 3. 11142 19523 2952.5 12713.5 RPX MWD030 OHMM 0.59 1848.15 5.43106 19523 2952.5 12713.5 RPS MWD030 OHMM 0.21 1848.28 5.52919 19523 2952.5 12713.5 RPM MWD030 OHMM 0.21 2000 6. 18251 19523 2952.5 12713.5 RPD MWD030 OHMM 0. 15 2000 7.55693 19523 2952.5 12713.5 ROP MWD030 FPH 19.81 438 . 97 178. 163 19579 2965. 5 12754 .5 FCNT MWD030 CP30 413. 17 2155 759. 155 1925,42952.5 12664 .5 NCNT MWD030 CP30 85484 144528 108877 19425 2952.5 4 12664 .5 NPHI MWD030 PU 12.56 60.73 31.5659 19425 2952.5 12664 .5 First Reading For Entire File 2952.5 Last Reading For Entire File 12754 .5 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/12 Maximum Physical Record65535 File Type LO Next File Name STSLIB.003 Physical EOF Tape Trailer Service name LISTPE Date 11/04/12 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 11/04/12 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Apr 12 16:29: 17 2011 Reel Header Service name LISTPE Date 11/04/12 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 11/04/12 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services I'I Physical EOF Comment Record TAPE HEADER Colville River MWD/MAD LOGS WELL NAME: CD3-125 API NUMBER: 501032063200 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 12-APR-11 JOB DATA MWD RUN 3 MWD RUN 4 MWD RUN 6 JOB NUMBER: K-MW-000789684 K-MW-000789684 K-MW-000789684 LOGGING ENGINEER: PAUL ORTH PAUL ORTH JESSE BOBBIT OPERATOR WITNESS: DAVE BURLEY DON MICKEY DAVE BURLEY SURFACE LOCATION SECTION: 5 TOWNSHIP: 12N RANGE: 5E FNL: 4012 FSL: FEL: 1147 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRICK FLOOR: 49. 19 GROUND LEVEL: 12. 60 eco -lam got9.5 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.750 9. 625 2961.0 2ND STRING 6. 125 7.000 11487.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD) . 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) . 3. MWD RUN 100 WAS A CLEAN OUT RUN - NO DATA PRESENTED. 4 . MWD RUN 200 WAS DIRECTIONAL ONLY - NO DATA PRSENTED. 5. MWD RUN 300 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-P4) , PRESSURE WHILE DRILLING (PWD) , COMPENSATED THERMAL NEUTRON POROSITY ((CTN) , AZIMUTHAL LITHO-DENSITY (ALD) ) , ACOUSTIC CALIPER (ACAL) , AND DRILLSTRING DYNAMICS SENSOR (DDSr) , AND GEO-PILOT (RSS) . 6. WELLBORE CD3-125 SIDETRACKS FROM CD3-125PB1 AT 7, 500' MD, 4, 731' TVD. 7. MWD RUN 400 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-P4) , PRESSURE WHILE DRILLING (PWD) , AND DRILLSTRING DYNAMICS SENSOR (DDSr) . 8. MWD RUN 500 WAS A CLEAN OUT RUN - NO DATA PRESENTED. 9. MWD RUN 600 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-P4) , COMPENSATED THERMAL NEUTRON POROSITY (CTN) , AZIMUTHAL LITHO-DENSITY (ALD) , PRESSURE WHILE DRILLING (PWD) , DRILLSTRING DYNAMICS SENSOR (DDSr) , AND GEO-PILOT (RSS) . 10. 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 DRILL SITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 11. MWD RUNS 100 - 600 REPRESENT WELL CD3-125 WITH API #5 0-103-20632-00. THIS WELL REACHED A TOTAL DEPTH OF 16529'MD, 7069' TVD. MNEMONIC CURVE DESCRIPTION R09P 9in Phase Resistivity R15P 15in Phase Resistivity R27P 27in Phase Resistivity R39P 39in Phase Resistivity EWXT EWR Formation Exp Time ROPA Avg Rate of Penetration DGRC DGR Combined Gamma Ray APEL ALD LCRB Pe Factor ACDL ALD LCRB Comp Density ADCL ALD LCRB Den Correction TNPS CTN Porosity Sandstone TNFA CTN Far Avg Count Rate TNNA CTN Near Avg Count Rate ACHD ACAL Hole Diameter ALRPM ALD RPM HOLE SIZE: 8 3/4" - ACAL Hole Diameter 6 1/8" - Fixed MUD WEIGHT: 9. 6-10.0 PPG WHOLE MUD CHLORIDES: 8 3/4" - 500 - 3800 PPM 6 1/8" - 52000 - 60000 PPM FORMATION WATER SALINITY: 14545 PPM CL FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2. 65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0. 6 FT, EXCEPT FOR GAMMA RAY AND ROP. THESE CURVES ARE SMOOTHED WITH A 1. 1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. $ File Header Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/12 Maximum Physical Record65535 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 DRHO 2952.5 16458.5 RHOB 2952.5 16458.5 FCNT 2952.5 16443.5 NPHI 2952.5 16443.5 NCNT 2952.5 16443.5 RPS 2952.5 16487.0 RPD 2952.5 16487.0 PEF 2952.5 16458.5 RPM 2952.5 16487.0 GR 2952.5 16480.5 CALA 2952.5 7500.0 RPX 2952.5 16487.0 FET 2952.5 16487.0 CALN 2952.5 16458.5 ROP 2965.5 16529.5 $ 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 3 2952.5 7500.0 MWD 4 7500.5 11504.5 MWD 6 11505.0 16529.5 $ # 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 . 1IN 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 CALA MWD IN 4 1 68 4 2 RHOB MWD G/CC 4 1 68 8 3 DRHO MWD G/CC 4 1 68 12 4 CALN MWD IN 4 1 68 16 5 PEF MWD B/E 4 1 68 20 6 GR MWD API 4 • 1 68 24 7 FET MWD HR 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 RPS MWD OHMM 4 1 68 36 10 RPM MWD OHMM 4 1 68 40 11 RPD MWD OHMM 4 1 68 44 12 ROP MWD FPH 4 1 68 48 13 FCNT MWD CP30 4 1 68 52 14 NCNT MWD CP30 4 1 68 56 15 NPHI MWD PU 4 1 68 60 16 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2952.5 16529.5 9741 27155 2952.5 16529.5 CALA MWD IN 8 .3 9.48 8.88124 8775 2952.5 7500 RHOB MWD G/CC 0.799 3.004 2. 41193 19061 2952.5 16458 .5 DRHO MWD G/CC -3.283 0.451 0.0524022 19061 2952.5 16458 .5 CALN MWD IN 5. 69 13.42 7 .41852 19061 2952.5 16458 .5 PEF MWD B/E 1.33 13.86 2.54183 19061 2952.5 16458.5 GR MWD API 23.75 436. 16 94 .5612 27057 2952.5 16480.5 FET MWD HR 0. 17 827.55 2. 95626 27013 2952.5 16487 RPX MWD OHMM 0.09 1848. 15 6.71653 27013 2952.5 16487 RPS MWD OHMM 0. 11 2000 7. 44735 27013 2952.5 16487 RPM MWD OHMM 0.21 2000 9.0223 27013 2952. 5 16487 RPD MWD OHMM 0. 15 2000 9. 80498 27013 2952. 5 16487 ROP MWD FPH 0.52 456.38 131. 995 27129 2965.5 16529.5 FONT MWD CP30 215. 46 2704. 63 750.756 19031 2952.5 16443.5 NCNT MWD CP30 15587.4 144528 66433. 4 19031 2952. 5 16443.5 NPHI MWD PU 7.24 60.73 26.5921 19031 2952. 5 16443.5 First Reading For Entire File 2952.5 Last Reading For Entire File 16529.5 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/12 Maximum Physical Record65535 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 11/04/12 Maximum Physical Record65535 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH APEL 2952.5 7500.0 ACDL 2952.5 7500.0 ADCL 2952. 5 7500.0 TNFA 2952.5 7500.0 EWXT 2952.5 7500.0 AHSI 2952.5 7500.0 R27P 2952.5 7500.0 R39P 2952.5 7500.0 TNNA 2952.5 7500.0 R15P 2952.5 7500.0 DGRC 2952.5 7500.0 ACHD 2952.5 7500.0 R09P 2952.5 7500.0 TNPS 2952.5 7500.0 ROPA 2965.5 7500.0 $ LOG HEADER DATA DATE LOGGED: 15-MAR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 7500.0 TOP LOG INTERVAL (FT) : 2961.0 BOTTOM LOG INTERVAL (FT) : 7500.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 58.5 MAXIMUM ANGLE: 84 . 6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 275518 EWR4 ELECTROMAG. RESIS. 4 230203 CTN COMP THERMAL NEUTRON 185457 ALD Azimuthal Litho-Dens 125035 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 8 .750 DRILLER'S CASING DEPTH (FT) : 2961.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G) : 9. 65 MUD VISCOSITY (S) : 40.0 MUD PH: 9. 0 MUD CHLORIDES (PPM) : 700 ) FLUID LOSS (C3) : 2. 6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 1.800 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .870 152.0 MUD FILTRATE AT MT: 1.500 70.0 MUD CAKE AT MT: 2.000 70.0 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 I Data Reference Point Undefined Frame Spacing 60 . 1IN I Max frames per record Undefined I 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 CALA MWD030 IN 4 1 68 4 2 RHOB MWD030 G/CC 4 1 68 8 3 DRHO MWD030 G/CC 4 1 68 12 4 CALN MWD030 IN 4 1 68 16 5 PEF MWD030 B/E 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 RPX MWD030 OHMM 4 1 68 32 9 RPS MWD030 OHMM 4 1 68 36 10 RPM MWD030 OHMM 4 1 68 40 11 RPD MWD030 OHMM 4 1 68 44 12 ROP MWD030 FPH 4 1 68 48 13 FCNT MWD030 CP30 4 1 68 52 14 NCNT MWD030 CP30 4 1 68 56 15 1 NPHI MWD030 PU 4 1 68 60 16 First I Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2952.5 7500 5226.25 9096 2952. 5 7500 CALA MWD030 IN 8 .3 9.48 8.88124 8775 2952. 5 7500 RHOB MWD030 G/CC 1.54 2.714 2. 33016 9096 2952.5 7500 DRHO MWD030 G/CC -3.283 0. 174 0.0477277 9096 2952.5 7500 CALN MWD030 IN 8.25 11. 61 8.76766 9096 2952.5 7500 PEF MWD030 B/E 2.01 13. 86 2. 97159 9096 2952.5 7500 GR MWD030 API 50. 98 190. 97 115.508 9096 2952.5 7500 FET MWD030 HR 0.17 827.55 6.02556 9096 2952.5 7500 RPX MWD030 OHMM 0.59 1848. 15 5. 16041 9096 2952.5 7500 RPS MWD030 OHMM 0.21 1848.28 5.20336 9096 2952.5 7500 RPM MWD030 OHMM 0.21 2000 6.09202 9096 2952.5 7500 RPD MWD030 OHMM 0. 15 2000 8. 6605 9096 2952.5 7500 ROP MWD030 FPH 19.81 438. 97 174 . 679 9070 2965.5 7500 FCNT MWD030 CP30 413.17 2155 669.821 9096 2952. 5 7500 NCNT MWD030 CP30 85484 144528 104959 9096 2952.5 7500 NPHI MWD030 PU 12.56 60.73 33. 9951 9096 2952.5 7500 First Reading For Entire File 2952.5 Last Reading For Entire File 7500 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/12 Maximum Physical Record65535 File Type LO Next File Name STSLIB.003 Physical EOF File Header Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/12 Maximum Physical Record65535 File Type LO Previous File Name STSLIB. 002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH EWXT 7500.5 11447.5 R27P 7500.5 11447 .5 ROPA 7500.5 11504 .5 R15P 7500.5 11447.5 R09P 7500.5 11447.5 R39P 7500.5 11447 .5 DGRC 7500.5 11455.0 LOG HEADER DATA DATE LOGGED: 25-MAR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 11503.0 TOP LOG INTERVAL (FT) : 7500.0 BOTTOM LOG INTERVAL (FT) : 11503.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 48 .8 MAXIMUM ANGLE: 77. 6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 269077 EWR4 ELECTROMAG. RESIS. 4 216787 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 8.750 DRILLER'S CASING DEPTH (FT) : 2961.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9.80 MUD VISCOSITY (S) : 40.0 MUD PH: 9.7 MUD CHLORIDES (PPM) : 500 FLUID LOSS (C3) : 5. 6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 2. 150 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 1. 189 144 . 9 MUD FILTRATE AT MT: 1.830 70.0 MUD CAKE AT MT: 2.210 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD040 API 4 1 68 4 2 FET MWD040 HR 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 ROP MWD040 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7500. 5 11504 .5 9502.5 8009 7500.5 11504 .5 GR MWD040 API 40. 6 436. 16 120. 903 7910 7500.5 11455 FET MWD040 HR 0.28 251.25 1.08766 7895 7500.5 11447.5 RPX MWD040 OHMM 1.71 17 .47 5.02128 7895 7500.5 11447.5 RPS MWD040 OHMM 1.7 17 .26 5. 10452 7895 7500.5 11447.5 RPM MWD040 OHMM 1.76 16. 88 5.23161 7895 7500.5 11447 .5 RPD MWD040 OHMM 1.69 15.71 5.2777 7895 7500.5 11447.5 ROP MWD040 FPH 0.52 456.38 134 .35 8009 7500.5 11504 .5 First Reading For Entire File 7500.5 Last Reading For Entire File 11504 .5 File Trailer I Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/12 Maximum Physical Record65535 File Type LO Next File Name STSLIB. 004 Physical EOF I • File Header Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/12 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 11455.5 16480.5 R27P 11476.5 16487.0 EWXT 11476.5 16487.0 TNPS 11476.5 16443.5 APEL 11476.5 16458.5 R15P 11476.5 16487.0 AHSI 11476.5 16458.5 R09P 11476.5 16487.0 ADCL 11476.5 16458.5 R39P 11476.5 16487.0 ACDL 11476.5 16458.5 TNFA 11476.5 16443.5 TNNA 11476.5 16443.5 ROPA 11505.0 16529.5 $ LOG HEADER DATA DATE LOGGED: 04-APR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 16529.0 TOP LOG INTERVAL (FT) : 11503.0 BOTTOM LOG INTERVAL (FT) : 16529.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 81. 6 MAXIMUM ANGLE: 91.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 261396 CTN COMP THERMAL NEUTRON 280576 EWR4 Electromag Resis. 4 11198199 ALD Azimuthal Litho-Dens 231387 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 6. 125 DRILLER'S CASING DEPTH (FT) : 11487 .0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9. 60 MUD VISCOSITY (S) : 48.0 MUD PH: 9.0 MUD CHLORIDES (PPM) : 52000 FLUID LOSS (C3) : 3. 1 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .090 65.0 MUD AT MAX CIRCULATING TERMPERATURE: .038 169.7 MUD FILTRATE AT MT: . 120 65.0 MUD CAKE AT MT: . 140 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: # I Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RHOB MWD060 G/CC 4 1 68 4 2 DRHO MWD060 G/CC 4 1 68 8 3 CALN MWD060 IN 4 1 68 12 4 PEF MWD060 B/E 4 1 68 16 5 GR MWD060 API 4 1 68 20 6 FET MWD060 HR 4 1 68 24 7 RPX MWD060 OHMM 4 1 68 28 8 RPS MWD060 OHMM 4 1 68 32 9 RPM MWD060 OHMM 4 1 68 36 10 RPD MWD060 OHMM 4 1 68 40 11 ROP MWD060 FPH 4 1 68 44 12 FCNT MWD060 CP30 4 1 68 48 13 NCNT MWD060 CP30 4 1 68 52 14 NPHI MWD060 PU 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11455.5 16529.5 13992.5 10149 11455.5 16529.5 RHOB MWD060 G/CC 0.799 3.004 2.48656 9965 11476.5 16458.5 DRHO MWD060 G/CC -2.013 0. 451 0.0566691 9965 11476.5 16458.5 CALN MWD060 IN 5. 69 13.42 6.18704 9965 11476.5 16458.5 PEF MWD060 B/E 1.33 13.36 2. 14954 9965 11476.5 16458.5 GR MWD060 API 23.75 138.79 54 .8747 10051 11455. 5 16480.5 FET MWD060 HR 0.27 149.5 1. 64258 10022 11476. 5 16487 RPX MWD060 OHMM 0.09 73.81 9.46432 10022 11476. 5 16487 RPS MWD060 OHMM 0. 11 2000 11.3296 10022 11476. 5 16487 RPM MWD060 OHMM 2.37 2000 14 . 668 10022 11476.5 16487 RPD MWD060 OHMM 0.86 2000 14 . 4102 10022 11476.5 16487 ROP MWD060 FPH 1.02 285.65 91.5968 10050 11505 16529.5 FCNT MWD060 CP30 215. 46 2704 . 63 824 .856 9935 11476.5 16443.5 NCNT MWD060 CP30 15587.4 48803.4 31161.4 9935 11476.5 16443.5 NPHI MWD060 PU 7.24 41.25 19.8143 9935 11476.5 16443.5 First Reading For Entire File 11455.5 Last Reading For Entire File 16529.5 File Trailer Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/12 Maximum Physical Record65535 File Type LO Next File Name STSLIB.005 Physical EOF Tape Trailer Service name LISTPE Date 11/04/12 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 11/04/12 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
