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211-134
New Plugback Esets 6/25/2024 Well Name API Number PTD Number ESet Number Date 1J-127 PB1 50-029-23306-70-00 206-047 T39006 8-22-2006 1J-127 PB2 50-029-23306-71-00 206-047 T39007 8-22-2006 1J-170 PB1 50-029-23310-70-00 206-062 T39008 8-22-2006 1J-170 PB2 50-029-23310-71-00 206-062 T39009 8-22-2006 2K-28AL1 PB1 50-103-20385-71-00 211-134 T39010 10-13-2011 2K-28AL1 PB2 50-103-20385-72-00 211-134 T39011 10-13-2011 PBU 13-27B PB1 50-029-20947-70-00 211-048 T39012 8-11-2011 PBU 13-27B PB2 50-029-20949-71-00 211-048 T39013 8-11-2011 15-02B PB1 50-029-20697-71-00 206-072 T39014 3-7-2008 15-02B PB2 50-029-20697-72-00 206-072 T39015 3-7-2008 CD2-07 PB1 50-103-20472-70-00 203-187 T39016 2-22-2006 CD2-07 PB2 50-103-20472-71-00 203-187 T39017 2-22-2006 E-23C PB1 50-029-21763-71-00 211-053 T39018 9-30-2011 E-23C PB2 50-029-21763-72-00 211-053 T39019 9-30-2011 NS-25 PB1 50-029-23181-70-00 203-166 T39020 3-22-2004 NS-25 PB2 50-029-23181-71-00 203-166 T39021 3-22-2004 OP18-08 PB1 50-029-23449-70-00 211-059 T39022 10-14-2011 OP18-08 PB2 50-029-23449-71-00 211-059 T39023 10-14-2011 2K-28AL1 PB1 50-103-20385-71-00 211-134 T39010 10-13-2011 2K-28AL1 PB2 50-103-20385-72-00 211-134 T39011 10-13-2011 c o o N J J - co 0 CC CL in ca E E ao 0 0 p as m p a' R Ce X c X N 1 ea a a 9 9 U a 011 — 11.1 -23913°131:1 J0 aNJO Jp aa7sC9 MO > C ce pc o E aa2co m a) a) N N a) (1) N (1) 'o tii E a a cn 0a9 + 0 fnE mE m,E mE WE mE z Z. ° - U p p >p °) a �`o°LL p0 Oa) Om Ow paa)i pai a 2 2 1--I 2CroF 1-cC 2CC 2a 2 c i-W 2a a 0 r d 1 o o -) a 'd I o 0 0 0 0 O 0 0 0 O Z 1 o W V N N N N N N N N N N O ccr co r r co co co co r r r co O U p J O O O O O O O O O O 2 z E C 2 '� i = a) N a) c a) a) a) c a) a) c a) N a E I— m c a D. a a a a a a a co m OU O O O 0 0 0 0 0 0 0 E LL Q III '0 U N `) — - COD COO (OD Co N O a co ca o w ao oco co m V 'O o" N 0))CV O o O (0 cocoaao Co coo O-y 13 IL J E J LU a, � 1 Ce O O (N N N 01 N Co co N N 01 N CO O co N Z 0 N'N- C- n CD r- r- r- Co r- LU O -, III O Z y O Z > 71) Z • 5 " ` 7o Ce Qa) = j re J Q. 16 LI! 0 O rn'o o 0 o o o o o o o C CL N co= ZI -I2 U U U 0 0 0 0 0 0 I to s NN N N a. 1 a) C)16 LG E O. 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E 0 O a 4,,, 1 I E E a a 0 <Q II11 0 1 0o 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM ,BION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Rug Perforations r Ibrforate r Other r Convert WINJ to WAG Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension M"'' Change Approved Rogram r Operat.Shutdow n r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r ' 211-134 _ 3.Address: 6.API Number: Stratigraphic r Service [' P. O. Box 100360,Anchorage,Alaska 99510 50-103-20385-60-- 00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25588725605 2K-28AL1 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10811 feet Plugs(measured) None true vertical 6386 feet Junk(measured) None Effective Depth measured 7238 feet Packer(measured) none true vertical 6217 feet (true vertical) none Casing Length Size MD TVD Burst Collapse CONDUCTOR 190 16 220 220 SURFACE 3242 7.625 3272 2956 PRODUCTION 7105 5.5 7129 6126 LINER AU 407 3.5 7536 6470' LINER AL1 3573 2.375 10811 6386' Perforation depth: Measured depth: slotted liner 7238'-10811' True Vertical Depth: 6217'-6386' Tubing(size,grade,MD,and TVD) 3.5, L-80, 7110 MD,6109 TVD Packers&SSSV(type,MD,and TVD) no packer Camco DS nipple @ 497'MD,497'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 1561 580 2553 Subsequent to operation 1166 0 350 3531 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service E- Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r- Daily Report of Well Operations X ,. GSTOR r WINJ r WAGE GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt none Contact Darrell Humphry/Bob Christensen Email n1139@conocophillips.com Printed Name Darrell Humphry/Bob Christensen Title NSK Prod Eng Tech Signature -4-%-'A ` Aril Phone:659-7535 Date /0 . 7 , /z___ RA'DMS OCT 10 .n12 cc,Fhi 2z to •i./i Form 10-404 Revised 11/2011 Submit Original Only 2K-28AL1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/12/12 Convert from WINJ to WAG KUP 2K-28AL1 ConocoPhillips /' Well Attributes Max Angle&MD TD • Wellbore API/UWI Field Name Weii Stn... Ind(°) MD(ftKB) Act Btm(ftKB) Ala SI°'III.: 501032038560 KUPARUK RIVER UNIT INJ 95.65 9,441.24 10,817.0 CornmPtwaps Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date ••• Well Conrq:-2K-28A 4/11/2012 11 AM SSSV:NIPPLE Last WO: 34.59 8/26/2001 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:WLM 7,280.0 10/24/2011 Rev Reason:WELL REVIEW osborl 4/11/2012 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd LINER AL1 2 3/8 1.992 7,238.1 10,817.0 4.70 L-80 STL HANGER.25 i Liner Details Top Depth (ND) Top Incl Nomi... Top(ftKB) (R") (°) _Item Description Comment ID(In) 7,238.1 6,217.4 32.88 DEPLOY -SEAL BORE DEPLOYMENT SLEEVE 1.910 8,612.6 6,342.6 87.81 DEPLOY DEPLOYMENT SLEEVE 1.900 Perforations&Slots Shot Top(ND) Btm(TVD) Dens Top(RKB)Btm(ftKB) (ftKB) (ftKB) Zone Date (lift... Type Comment • 7,340.4 8,612.0 6,282.8 6,342.6 A-4,2K-28AL1 12/11/2011 32.0 SLOTS 8,613.3 10,816.6 6,342.6 A-4,2K-28AL1 12/11/2011 32.0 SLOTS coNDu�2 0 Notes:General&Safety End Date Annotation 11/15/2011 NOTE:WELL SIDETRACKED TO'A'8 AL1(AL1 COMES OFF MAIN WELLBORE) NIPPLE.427 • SURFACE. 30-3.272 GAS LIFT. 7.014 NIPPLE.7,083 LOCATOR. 7.108 SEAL ASST, 7.109 WHIPSTOCK. 7,240 PRODUCTION 5.5x3.5- 7129',25-7,538 SLOTS. 7,330-7,891 Mandrel Details Top Depth Top Port SLOTS, (TVD) Incl OD Valve Latch Size TRO Run 7008-5170 Stn Top(RIM) (ftKB) r) Make Model (in) Sery TYPe Tyne (in) (Psi) Run Date Corn... ( I 1' 7,013.6 6,032.6 36.42 CAMCO KBG 2-9 1 GAS LIFT DMY BTM 0.000 0.0 12/7/2001 SLOTS, 8,172-10,073 LINER A, 7,320-10073 TO(2K-28A), 10073 ,�` zt tG2 BAKER PRINT DISTRIBUTION LIST HUGHES COMPANY ConocoPhillips,Alaska Inc. INTERMEDIATE FINAL Yes (mandatory) WELL NAME 2K-28AL1PB2 RUN NUMBER (mandatory) FIELD Kuparuk BH SALESMAN Woods,Jim (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF (mandatory) LOG DATE: 2/12/2011 TODAYS DATE: 3/2/2012 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY FIELD FINAL (digital/ ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #OF F'HIN I S #OF COPIES #OF COPIES 1 ConocoPhillips Alaska,Inc. I 1 I I NSK Wells Aide,NSK 69 ATTN:MAIL ROOM 700 G Street, Anchorage,AK 99501 2 AOGCC I 1 1 I I Christine Mahnken 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 3BP I 1 I 1 I I Petrotechnical Data Center,MB33 David Douglas 900 East Benson Blvd Anchorage,Alaska 99508 4 Chevron/KRU REP I 1 I 1 1 I I Glenn Fredrick 3800 Center Point Drive,Suite 100 Anchorage,Alaska 99503 5 Brandon Tucker,NRT I 1 I I I State of Alaska;DNR,Div.of Oil and Gas 550 W.7th Ave,Suite 800 Anchorage,Alaska 99501-3510 TOTALS FOR THIS PAGE: 0 4 4 0 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 I/t Z•t‘�. BAKER PRINT DISTRIBUTION LIST HUGHES COMPANY ConocoPhillips,Alaska Inc. INTERMEDIATE FINAL Yes (mandatory) WELL NAME 2K-28AL1PB1 RUN NUMBER (mandatory\ `' FIELD Ku aruk e`V SALESMAN Woods,Jim (mandatory) O11 (mandatory) COUNTY North Slope Borough Q 6 1 BH D CT Alaska (mandatory) S GO�d� (mandatory) STATE Alaska oat G0111/1; � PAGE OF (mandatory) Vit (i 0 ' LOG DATE: 11/30/2011 TODAYS DATE: 3/2/2012 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. ndnddtory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY FIELD FINAL (digitalCD / ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #UI- PHIN I S #OF COPIES #OF COPIES 1 ConocoPhillips Alaska,Inc. 1 NSK Wells Aide,NSK 69 ATTN:MAIL ROOM 700 G Street, Anchorage,AK 99501 2 AOGCC 1 1 Christine Mahnken 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 3 BP I 1 1 Petrotechnical Data Center,MB33 David Douglas 900 East Benson Blvd Anchorage,Alaska 99508 4 Chevron/KRU REP I 1 I 1 I I Glenn Fredrick 3800 Center Point Drive,Suite 100 Anchorage,Alaska 99503 • 5 Brandon Tucker,NRT J I 1 I 1 State of Alaska;DNR,Div.of Oil and Gas 550 W.7th Ave,Suite 800 Anchorage,Alaska 99501-3510 TOTALS FOR THIS PAGE: 0 1 0 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 Zlk- Ili 2116z IrafillINI BAKER PRINT DISTRIBUTION LIST HUGHES COMPANY ConocoPhillips,Alaska Inc. INTERMEDIATE FINAL Yes (mandatory' WELL NAME 2K-28AL1 RUN NUMBER (mandatory) FIELD Kuparuk BH SALESMAN Woods,Jim (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF (mandatory) LOG DATE: 11/12/2011 TODAYS DATE: 3/2/2012 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY FIELD FINAL (digitalCD / ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #Or THIN I S #OF COPIES #OF COPIES 1 ConocoPhillips Alaska,Inc. I 1 I I NSK Wells Aide,NSK 69 ATTN:MAIL ROOM 700 G Street, Anchorage,AK 99501 2 AOGCC 1 1 I 1 I I I Christine Mahnken 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 3 BP T 1 I 1 I I I Petrotechnical Data Center,MB33 David Douglas 900 East Benson Blvd Anchorage,Alaska 99508 4 Chevron/KRU REP I 1 I 1 I I I Glenn Fredrick 3800 Center Point Drive,Suite 100 Anchorage,Alaska 99503 5 Brandon Tucker,NRT I I 1 I I I State of Alaska;DNR,Div.of Oil and Gas 550 W.7th Ave,Suite 800 Anchorage,Alaska 99501-3510 TOTALS FOR THIS PAGE: 0 4 4 0 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 Letter of Transmittal «k§ Date: BAKER December 15, 2011 HUGHES To: From: Corazon Manaois Carl Ulrich/ Sachin Gandra State of Alaska; DNR, Div. of Oil and Gas Baker Hughes INTEQ 550 W. 7t'Ave., Suite 800 795 East 94th Avenue Anchorage, Alaska 99501-3510 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 2K-28A Z \•V s 2K-28APB1 ` F 2K-28AL1PB1 2K-28AL1PB2 2K-28AL1 Zl1-l3� (5) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. 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Q0 7 7 •MO V ) Cb OD co 6 ? f� O) O) N O co O co In N N O cc O O COO N NC's] _ N N r CO O r co co n co N O f� CO r VI V C \ o n. = Y Y Y ':C o� ro m N N. ro UUD m CUO U co sr 01 m sr sr sr ° Q y1.i� 0 Y Y N N N p t /o 3 N O) N N (n N n O) V O t O CO O CO ,- 00 0 Q CO CO R CO M M CO to M V V M 7 N O r a.- O r A O O O O O O n O N to O to O Na 0 0 C L CO O N to 00 sr n O N to co O V co O M CO r (O _ O C >., CLr N N M co co V to N to to co co co r N. co Q O. d .0 0) d o 0 0 0 0 .0 0 0 0 0 0 0 0 0 c 0 N O O o O rt al d 0f 4 �+ en c Lo vain 3 3 0 CO a 1 L 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ 0 WAG ❑ WDSPL ❑ No.of Completions: Service 0 Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: December 12,2011 211-134/ 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 December 6,2011 50-103-20385-60 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 3'FNL,94'FEL,Sec. 11,T1ON,RO8E,UM December 10,2011 2K-28AL1 /2K-28AL1 PB1 &PB2 Top of Productive Horizon: 8.KB(ft above MSL): 30'RKB 15.Field/Pool(s): 947'FSL,2420'FWL,Sec. 11,T1ON, RO8E,UM GL(ft above MSL): 148.7'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 382'FNL,3223'FEL,Sec. 14,T1ON,RO8E,UM 7238'MD/6217'ND Kuparuk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-498310 y- 5938301 Zone-4 10811'MD/6386'ND ADL 25588,25605 TPI: x-495547 y- 5933972 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-495185 y- 5932644 Zone-4 nipple©497'MD/497'ND 2674,2679 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) 1515'MD/1489'ND 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res 7323'MD/6275'ND 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 30' 220' 30' 220' 24" 5.5 sx High Early 7.625" 29.7# L-80 30' 3272' 30' 2956' 9.875" 290 sx AS Lite,200 sx LiteCRETE 5.5" 15.5# L-80 25' 7129' 25' 6126' 6.75" 215 sx GasBLOK 3.5" 9.3# L-80 7129' 7536' 6126' 6470' 6.75" included above 2.375" 4.7# L-80 7238' 10811' 6217' 6386' 3" slotted liner 24.Open to production or injection? Yes ❑ No 0 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/ND) 3.5" 7110' none slotted liner:7238'-10811'MD 6217-6386' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. d ati4L'!"'' (.. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED L1 r 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting for 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 ❑✓ Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. ^. D NONE �, RADMS JAN 0 6,1 6D :. . ,ons.G� Form 10-407 Revised 12/2009 CONTINUED ON REVERSE 7,,n?'r3tat6 Submit original only 28. GEOLOGIC MARKERS(List all formations and markers e,,,,ountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 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 1515' 1489' needed,and submit detailed test information per 20 AAC 25.071. Kuparuk A5 9302' 6358' Kuparuk A4 9390' 6354' 2K-28AL1 PB1 KOP-Kuparuk A4 7852' 6299' Kuparuk A5 8324' 6313' Kuparuk A6 8516' 6300' Kuparuk A6 8722' 6300' Kuparuk A5 8829' 6311' N/A total depth 8860' 6316' 2K-28AL1 PB2 KOP-Kuparuk A4 8120' 6310' total depth 8760' 6354' Formation at total depth: Kuparuk A4 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey4V1/4) t 112ot-2. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Winfree @ 265-6820 Printed Name !lit ntt Li Title: crt, dl�p Supervisor / Signature J1 /1 • �1/C)P15 Phone 263-4021 Date 1/8/70 /S 7012 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 �p.1, Drilling msKUP 2K-28AL1 COnoCOPhillipS • s Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/UWI Field Name Well Status Incl(°) MD(MB) Act Btm(ftKB) 501032038560 KUPARUK RIVER UNIT PROD 10,817.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date •,• WellConfle:-2K-28,12/20/2011 5:J2a5AM SSSV:NIPPLE Last WO: 34.59 8/26/2001 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:WLM 7,280.0 10/24/2011 Rev Reason:ADD SIDETRACKS ninam 12/28/2011 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(1...Set Depth(TVD)...String Wt...String...String Top Thrd LINER AL1 2 3/8 1.992 7,238.1 10,817.0 4.70 L-80 STL Liner Details HANGER,25 i Top Depth (ND) Top Incl Nomi... Top(ftKB) (1KB) P1 Item Description Comment ID(in) 7,238.1 DEPLOY SEAL BORE DEPLOYMENT SLEEVE 1.992 8,612.6 DEPLOY DEPLOYMENT SLEEVE 1.992 I► Perforations&Slots ShotTop(ND) Btm(PAD) Dens Top(ftKB) Btm(ftKB) (ftKB) ((KB) Zone Date (oh-. Type Comment 7,340 10,817 A-4,2K-28 12/11/2011.32.0 SLOTS CONDUCTOR,^ 30-220 , NIPPLE.497 I I' SORFACE _.J l 303_72 GAS LIFT, 7,014 NIPPI F 7,063 LOCATOR, 7,106 SBE,7,109i\/ l J APERF 11 7 222 7 228 WHIPSTOCK, 7.240 APERF111 Mandrel Details 7 268 7 284 Top Depth Top Port (ND) Incl OD Valve Latch Size TRO Run Stn Top(ftKB) (ftKB) (°) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 7,013.6 6.031.1.34.46 CAMCO KBG 2-9 1 GAS LIFT DMY BTM 0.000 0.0 12/7/2001 IPERF, 7 300-7.3220 M. 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(n33o v) N --28 Pre and Post Rig Work Summary DATE SUMMARY 9/21/11 DRIFT TBG W/8'X 2.25" DD BLR (TS+ BLR OAL= 36') TO TAG @ 7427' SLM. JOB COMPLETE. 10/5/11 PERFORMED HOISTING OPERATIONS FOR GYRO DATA. GYRO DATA LOGGED CONTINUOUS SURVEY FROM SURFACE TO A DEPTH OF 7109'AT THE SBE. GYRO DATA LOGGED REPEAT PASS FORM 7109'TO SURFACE. RIGGED DOWN TURNED WELL OVER TO DSO. 10/24/11 DRIFT W/ 17' 10 1/2"X 2.78" DUMMY WHIP STOCK TO 7280' WLM NO PROBLEMS , PRE E-LINE 10/30/11 SET BAKER 35 KB PACKER WHIPSTOCK AT 7240' ORIENTED 18 DEGREES FROM HIGHSIDE LOOKING DOWNHOLE. PULL UPHOLE AFTER SET AND PERFORM 30 MINUTE TEMP/PRESS STATION LOG AT 7200'. 147 DEGF/3870 PSIG. PRESSURE FELL OF FROM INITIAL 3884 PSIG. PIP TAG SET AT 7246.5'. (2 PIPS= 2uCi OF Co-60). PIP TAG DATA SHEET ATTACHED IN WSR. 10/31/11 RIG IN HOLE WITH MIT 24 ARM CALIPER TO VERIFY THE ORIENTATION OF WHIPSTOCK SET/AFTER 3 LOG PASSES ACROSS THE WHIPSTOCK IT WAS VERIFIED THAT IT WAS SET 20 DEGREES RIGHT OF HIGH SIDE IN HOLE/ LITTLE RED CONNECT TO LUBRICATOR AND PUMP .10 BPM INTO TUBING AND PRESSURE INCREASED TO 3000 PSI /COULD NOT GET RATE INTO THE C SAND/ PERFORM BOTTOM HOLE PRESSURE SURVEY ( PRESSURE @ 7230'WAS 3958 PSI AT END OF 45 MINUTE STATION ) 12/21/11 ATTEMPT TO DRIFT FOR BHPS, MAX DEPTH ACHIEVED 2620' SLM WITH TOOLS FALLING 10' FPM DUE TO BRINE, CALL COMPANY MAN, JOB CALLED OFF. 12/28/11 TAGGED TOP OF LINER @ 7238' RKB WITH 2" LIB. MEASURED BHP @ 7233' RKB ( 3939 psi max ). JOB COMPLETE. ConocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: 2K-28 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 11/15/2011 8:00:00 PM Rig Release: Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11/15/2011 24 hr Summary Rig move.Spot rig over well,fix tree valves and flanges.Weld on reel. NUBOP's. Rig Accept at 20:00 HRS 06:00 20:00 14.00 MIRU MOVE MOB P Move rig from 2K-22 to 2K-28.***Rig accept at 20:00 hrs*** 20:00 23:00 3.00 MIRU SURFEC NUND T Call out valve crew tree problems- SSV External Seal/spacer ring out of place,inner OA valve leaking. Inpsect/grease to determine if replacement valves needed Prior to NUBOP stack.Cannot install valve on MP line. Rig up to continue with BOP test. 23:00 00:00 1.00 MIRU WHDBO NUND P Start NUBOP's 11/16/2011 Complete BOP test, pressure test tiger tank line and lubricator. Pull BPV SITP 1400 psi.Start cutting coil. Hold Safety Stand up&pre-spud meeting. 00:00 02:30 2.50 0 0 MIRU WHDBO NUND P Rig up and prepare for BOP testing. 02:30 12:30 10.00 0 0 MIRU WHDBO BOPE P Begin BOP testing High 4500psi/Low 250psi.State test Witnessed by John Crisp.Test Gas alarms Hi/Low. 0 Fails 12:30 14:30 2.00 0 0 MIRU WHDBO NUND T Reposition outer MP valve(T2)on stack. Unable to install valve handle to open/close valve due to it hitting on platform. PT(4000psi)good on MP line 14:30 14:36 0.10 0 0 MIRU WHDBO BOPE P Pressure test Inner reel valve.Good 14:36 15:36 1.00 0 0 SURPRI WELLPF CTOP P Lift injector off well.Cut CTC off, install boot on E-line 15:36 16:36 1.00 0 0 SURPRI WELLPF SLPC P MU injector head to well/, Reverse Circulate SW 20bbrls at 2.3 BPM for slack management, lift off well. 16:36 18:06 1.50 0 0 SURPRI WELLPF SLPC P PJSM, Set up rig floor for BPV removal and CT cutting. 18:06 19:36 1.50 0 0 PROD1 WELLPF SFTY P Safety Stand up with both crews 19:36 21:06 1.50 0 0 PROD1 WELLPF PRTS P Pressure test Lubricator and tiger tank line.Two small leaks in line. Blow down, hammer up. Re-test to 2000 psi. 21:06 22:36 1.50 0 0 PROD1 WELLPF MPSP P Pressure 1500psi, Equalize above BPV-Pull BPV. Bleed down WHP to zero-increase over 5 minutes. Shut in and bleed down lines. Rig down Lubricator. 22:36 23:36 1.00 0 0 PROD1 WELLPF SFTY P Pre-spud meeting with Maddy crew. PJSM for cutting pipe Page 1 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:36 00:00 0.40 0 0 PROD1 WELLPF CTOP P Start cutting 1400'of CT. 11/17/2011 Cut 1400ft of CT. Pump slack&cut back 18'to find cable. Re-head,pressure&pull test. Deploy BHA#1 with 2.80"mill/string mill. RIH and circ out well fluid with used flo-pro.Tag TOWS 7238.3'.Start milling window. 00:00 04:30 4.50 0 0 PROD1 WELLPF CTOP P Continue cutting 1400ft of CT. Re-tighten reel bolt. 04:30 06:00 1.50 0 0 PROD1 WELLPF CTOP P Reverse circ.CT to pump slack back. 06:00 06:15 0.25 0 0 PROD1 WELLPF SFTY P Crew change, PJSM 06:15 07:15 1.00 0 0 PROD1 WELLPF SLPC P Cut CT to find cable. 18'cut.Total CT cut entered into Cerberus-1420'. 07:15 08:45 1.50 0 0 PROD1 WELLPF SLPC P MU CTC,pull test 35K 08:45 10:00 1.25 0 0 PROD1 WELLPF SLPC P MU BHI drilling head, pressure test CTC 4000psi. 10:00 11:30 1.50 0 0 PROD1 WELLPF PRTS P Pressure test both PDL's 1500psi. Well Head pressure 1400 psi.Bleed down to 220psi out to tiger tank. Pressure build back up 360psi in 5 minutes.Shut in well. 11:30 11:45 0.25 0 0 PROD1 WHPST SFTY P PJSM, Deploy BHA 11:45 12:30 0.75 0 0 PROD1 WHPST PULD P Start to deploy BHA#1.(.6K AKO) 12:30 13:15 0.75 0 0 PROD1 WHPST SFTY P BHA made up in PDL and made up to well.Well shut in. Hold Pre-Spud meeting 13:15 14:15 1.00 0 0 PROD1 WHPST PULD P Continue to Deploy BHA#1.WHP 1125psi 14:15 18:15 4.00 73 7,239 PROD1 WHPST TRIP P RIH, Pumping slack forward,taking returns to tiger tank.Circ out SW with used Flo-pro. 18:15 00:00 5.75 7,239 7,241 PROD1 WHPST MILL P Dry tag TOWS=7239'Start pumping-tag TOW 7238.3'. Start milling window. 1.50 bpm, 3500, BHP 3624, ECD 11.5,WHP 0, WOB 1 -2.5K,Ct weight 17K.Auto drill-light medal returns after.5 ft milled. 11/18/2011 Complete milling window.TOW=7238'BOW=7243'. P/U build assembly with 2.5 AKO. Drilled to 7320'. Pull BHA for less motor AKO due to 50+doglegs. 00:00 04:00 4.00 7,241 7,245 PROD1 WHPST MILL P Mid-Point-Continue milling window- 1.50 bpm,3490, BHP 3630,WHP 0, ECD 11.6, ROP 1-2 fph,WOB 2.3K, CT weight 17.6K. Exit window 7243' Formation returns in surface. Continue following milling procedure. No-stalls. TOW=7238/BOW=7243'. 04:00 08:00 4.00 7,245 7,259 PROD1 WHPST MILL P Increase to 4-7 fph.Continue milling additional 15ft.Start holding WHP for ECD of 12.5 08:00 08:45 0.75 7,259 7,236 PROD1 WHPST MILL P Pick up backreaming window up, down,up 08:45 09:15 0.50 7,236 7,236 PROD1 WHPST MILL P Drift window. Good Page 2 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:15 11:00 1.75 7,236 0 PROD1 WHPST TRIP P Open EDC, POOH following 9.1ppg MP schedule 11:00 11:30 0.50 0 0 PROD1 WHPST SFTY P At surface, Crew change. PTM 11:30 11:45 0.25 0 0 PROD1 WHPST SFTY P PJSM, 11:45 14:15 2.50 0 0 PROD1 WHPST PULD P Undeploy BHA 1, Gauge mills, (2.80 No-Go mill,2.79 No-Go string mill). Service injector head and reel. Change stripper rubber 14:15 15:30 1.25 0 0 PROD1 DRILL PULD P Deploy BHA 2(2.5 AKO) 15:30 18:30 3.00 62 7,260 PROD1 DRILL TRIP P RIH with EDC open following MPD. Tie in correction+2.Circulate new mud at bottom. 18:30 20:00 1.50 7,260 7,270 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3730, BHP 3975, ECD 12.6,WHP 0, ROP 8, WOB 1.1K,Ct weight 15K.Tool orientation problems starting out. P/U and check orientator-works drill ahead slowly due to interference. 20:00 21:00 1.00 7,270 7,295 PROD1 DRILL DRLG P Drilling ahead normal-1.40 bpm, 3770, BHP 3940, ECD 12.5,WOB 2.1K,Ct weight 15K, ROP 40. 21:00 22:00 1.00 7,295 7,320 PROD1 DRILL WPRT P Wiper trip&Tie into K1 zero correction&pip tag @ 7245'.TOW= 7238'/BOW 7243'. Doglegs are showing 47-55 degrees.Average is 51 degrees. Drill to 7310'with lighter WOB for a few more data points-AVG 47 degrees. Call town. 22:00 00:00 2.00 7,320 2,500 PROD1 DRILL TRIP P Pull BHA to lower motor AKO.P/U weight 30K-Open EDC&follow MPD. 11/19/2011 P/U BHA#3 with 2.3 AKO&drill build section to TD of 7585'with 46-60 degree doglegs. POOH &P/U BHA #4 with RSM and bi-center. 00:00 01:00 1.00 2,500 72 PROD1 DRILL TRIP P POOH following MPD 01:00 02:30 1.50 72 0 PROD1 DRILL PULD P PJSM-Undeploy BHA 02:30 03:30 1.00 0 72 PROD1 DRILL PULD T Change to 2.3 AKO. Deploy BHA.#3 03:30 06:30 3.00 72 7,145 PROD1 DRILL TRIP T RIH with EDC open pumping .5 bpm. 06:30 06:45 0.25 7,145 7,145 PROD1 DRILL DLOG T Tie in depth+3'correction 06:45 10:00 3.25 7,320 7,470 PROD1 DRILL DRLG P Drill ahead 1.4 BPM,3350 CTP, 4000 BHP, 1.7K WOB 10:00 10:30 0.50 7,470 7,470 PROD1 DRILL WPRT P Wiper trip to window.30K PUW 10:30 11:30 1.00 7,470 7,500 PROD1 DRILL DRLG P Drill ahead 1.4 BPM,3350 CTP, 4000 BHP, 1.7K WOB 11:30 12:00 0.50 0 PROD1 DRILL WPRT PUH Getting 51, Discuss with town 12:00 14:45 2.75 7,500 7,585 PROD1 DRILL DRLG P Drill ahead next surveys 48 DLS. Control drill minimizing WOB. 1-1.5K WOB. 14:45 18:15 3.50 7,585 72 PROD1 DRILL TRIP P TD build section. Last 2 surveys 60+ DLS. POOH Page 3 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:15 20:15 2.00 72 0 PROD1 DRILL PULD P PJSM Undeploy BHA#3.Service injector and reel. 20:15 22:45 2.50 0 68 PROD1 DRILL PULD P PJSM Start P/U BHA#4 RSM with rebuild Bi-center.Auto choke WHP pressure reading not functioning.Still have secondary WHP reading. 22:45 00:00 1.25 68 5,500 PROD1 DRILL TRIP P RIH with EDC open following MPD running the choke on manual. Fix WHP while tripping in hole. 11/20/2011 Drilling ahead with RSM.Slow pump rate through higher Doglegs in build.Mud swap with 1210ft on system .8%solids. 00:00 01:30 1.50 5,500 7,583 PROD1 DRILL TRIP P RIH following MPD.+3 ft correction. Close EDC-RIH slowly through window,slight weight gain bottom of window. RIH min rate through build weight gain to 3K WOB @ 7275'with minimal CT weight change.WOB back down to 1K @ 7350'.Good down to 7572'WOB increase to 2K, dropped off 7578'. 01:30 03:30 2.00 7,583 7,645 PROD1 DRILL DRLG P Bring pumps up to drilling rate,zero WOB-Motor work @ 7585'.BHA& pressures look normal. 1.40 bpm,3680, BHP 4010,WOB 1.5K, CT weight 12k, ECD 12.6, WHP 80, ROP 50.Control drill for the first 60'. 03:30 05:00 1.50 7,645 7,735 PROD1 DRILL DRLG P Drill ahead normal-1.45 bpm,3800, BHP 4030,WHP 100, ECD 12.6, WOB 2.6K,Ct weight 14K, ROP 60. 05:00 05:18 0.30 7,735 7,735 PROD1 DRILL WPRT P Wiper trip to window,29K PUW 05:18 06:18 1.00 7,735 7,735 PROD1 DRILL DLOG P MADD pass build section 7590-7260 06:18 06:36 0.30 7,735 7,735 PROD1 DRILL WPRT P RBIH 06:36 11:00 4.40 7,735 7,885 PROD1 DRILL DRLG P Drill ahead 1.4 BPM,4016 BHP, 3616 CTP, holding 87 psi MP choke 11:00 11:30 0.50 7,885 7,885 PROD1 DRILL WPRT P Wiper trip to window,30K PUW. While PUH through 60 DLS 7600', Bore pressure increase 275psi, surface psi increase 230 psi. Continue wiper trip. 11:30 12:00 0.50 7,885 7,885 PROD1 DRILL WPRT P RBIH 12:00 14:45 2.75 7,885 8,035 PROD1 DRILL DRLG P Drill ahead 1.4 BPM,4052 BHP, 3854 CTP,holding 87 psi MP choke. Drilling pressures 200+psi higher on bottom after wiper trip. Drill ahead closely monitoring RSM. Discuss possible damage of RSM pulling through high DLS.Currently working fine. 14:45 15:30 0.75 8,035 8,035 PROD1 DRILL WPRT P Wiper trip to window.30K PUW. Lower pump rate and POOH speed when pulling RSM thru high DLS area. .75 BPM at 10-15 FPM Page 4 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 15:42 0.20 8,035 8,035 PROD1 DRILL DLOG P Tie in depth to RA marker+.5' correction. RBIH 15:42 17:12 1.50 8,035 8,185 PROD1 DRILL DRLG P Drill Ahead 1.44 BPM,4057 CTP, 4071 BHP, 10K CTW,70 psi MP choke. 17:12 18:42 1.50 8,185 8,185 PROD1 DRILL WPRT P Wiper trip slow pump rate and speed down through higher DLG. 18:42 20:30 1.80 8,185 8,335 PROD1 DRILL DRLG P Drilling ahead 1.45 bpm,4080, BHP 4144,WHP 70,WOB 1.8K,Ct weight 13K.8230'-annular pressure increasing slowly,open choke fully. BHP 4080psi. Run mud property check. .8%solids.Call out vac trucks. 20:30 22:00 1.50 8,335 8,335 PROD1 DRILL WPRT P Wiper trip-P/U weight 30K.Slow pump rates through DGL in build. Clean through build. 22:00 00:00 2.00 8,335 8,485 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,4150,BHP 4100,WHP 0,WOB 2K, ROP 80, Ct weight 12K.Start pumping new mud 8450'-1230ft on system.8%solids. 11/21/2011 Continue drilling ahead A Lateral utilizing RSM BHA, increase claystop to 2.5%in mud system. 00:00 02:00 2.00 8,485 8,485 PROD1 DRILL WPRT P Wiper trip P/U weight 30K.Tie in =+4ft. lincrease in cutting over shaker during top of wiper trip with new mud around.Oil saturated samples/cuttings. 02:00 03:30 1.50 8,485 8;635 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm,3790,BHP 4090,WHP 130, ECD 12.7,ROP 120,WOB 1.7K,CT weight 13K. 03:30 05:30 2.00 8,635 8,635 PROD1 DRILL WPRT P Wiper trip-P/U weight 30K. Drop pump rate to.75 BPM and slow down to 10-15 FPM thru high DLS 05:30 08:00 2.50 8,635 8,785 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm,3654 CTP, BHP 4080,WHP 120, ECD 12.7, ROP 120,WOB 1.7K,CT weight 11K. 08:00 10:00 2.00 8,785 8,785 PROD1 DRILL WPRT P Wiper trip to window 30K PUW. Drop pump rate to.75 BPM and slow down to 10-15 FPM thru high DLS 10:00 12:30 2.50 8,785 8,935 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm, 3756, BHP 4108,WHP 120, ECD 12.7,WOB 2-3K, CT weight 10K. 12:30 14:30 2.00 8,935 8,935 PROD1 DRILL WPRT P Wiper trip to window 30K PUW.Tie in depth to RA marker+4' corrrection. Drop pump rate to.75 BPM and slow down to 10-15 FPM thru high DLS 14:30 17:00 2.50 8,935 9,085 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm, 3904, BHP 4117,WHP 130, ECD 13, ROP 120, WOB 2K, CT weight 10K. 17:00 20:00 3.00 9,085 9,085 PROD1 DRILL WPRT P Wiper trip to window 30K PUW.Tie in depth to RA marker+4' corrrection. Drop pump rate to.75 BPM and slow down to 10-15 FPM thru high DLS Page 5 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 23:00 3.00 9,085 9,174 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm, 3800, BHP 4095,WHP 70, ROP 25,WOB 1.4K, Ct weight 12.3K. Poor shale/clay formation from 9050', increase claystop from 1.5%to 2.5%. @ 9100ft.Control drilling trying to get tool to drop. 23:00 00:00 1.00 9,174 9,190 PROD1 DRILL DRLG P BHA wiper P/U weight 30K. Drilling ahead. 11/22/2011 Drill into A6, POOH Set Anchored Billet @ 8410 00:00 02:00 2.00 9,190 9,237 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3900, BHP 4130, ECD 13,WOB.8K,CT weight 12K, ROP 25-40. Hard time turning down with RSM.Tried WOB/Less WOB no changes. Geo steering-samples 100% silt/claystone. 02:00 03:30 1.50 9,237 7,200 PROD1 DRILL WPRT T Wiper trip-P/U weight 30K Call town to discuss BHA change&Geo outlook.Clean through window. Determined sand drilled was non target A5 sand. Made decision to POOH and PU anchored billet for geologic ST in the A4. 03:30 06:00 2.50 7,200 0 PROD1 DRILL TRIP T POOH following MPD. 06:00 06:30 0.50 0 0 PROD1 DRILL SFTY T At surface.Crew change, PJSM 06:30 08:00 1.50 0 0 PROD1 DRILL PULD T Undeploy BHA 08:00 10:00 2.00 0 0 PROD1 DRILL SVRG T Service injector head and reel,repair PDL heat line.(waiting on BOT) 10:00 12:45 2.75 0 0 PROD1 DRILL PULD T Conduct TGSM. Deploy BHA. 12:45 15:45 3.00 0 8,410 PROD1 DRILL TRIP T RIH W/Anchored billet BHA,tie in for a+2'correction.stop at setting depth 15:45 16:00 0.25 8,410 8,410 PROD1 DRILL ANCR T Set anchor billet,top @ 8410' 16:00 18:15 2.25 8,410 73 PROD1 DRILL TRIP T TOOH 18:15 21:45 3.50 73 72 PROD1 STK PULD T PUD BHA#5 Billet Run, PD BHA#6, Drill by BHA with.7 degree motor and Bi-Center bit,Make up to Coil track and surface test tool,Tag up and set counters 21:45 23:30 1.75 72 7,155 PROD1 STK TRIP T RIH EDC Open 23:30 23:36 0.10 7,155 7,175 PROD1 STK DLOG T Log tie in for+3',Close EDC 23:36 00:00 0.40 7,175 8,031 PROD1 STK TRIP T Trip in to dry tag billet 11/23/2011 Drill past Billet @ 8410, Drill ahead to 9129 00:00 00:12 0.20 8,031 8,412 PROD1 STK TRIP T Continue in well to dry tag billet 00:12 03:42 3.50 8,412 8,440 PROD1 STK KOST T Tag TOB @ 8410.6 with pumps on, Start time milling,stalled @ 8410.7 and 8411.12, 1.4 BPM @ 3980 PSI FS, BHP=4070,WO Choke Page 6 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:42 03:54 0.20 8,440 8,440 PROD1 STK WPRT T Drill by down to 8440, PUW=30K, Drift past billet looks good 03:54 05:30 1.60 8,440 8,570 PROD1 DRILL DRLG T 8440', Drill Ahead 1.4 BPM @ 3910 PSI FS, RIW=15.3K,Wide Open Choke, BHP=4080 05:30 07:15 1.75 8,570 8,570 PROD1 DRILL WPRT T Pull wiper 30k off BTM,pull wiper to 7250'.RBIH 07:15 09:30 2.25 8,570 8,720 PROD1 DRILL DRLG T Drill ahead, 1.40 BPM 4330 PSI, ECD 12.91.Wide open choke 4115 BHP drill to 8720'. Had one stall @ 8708'. 09:30 10:45 1.25 8,720 8,000 PROD1 DRILL WPRT T Pull wiper,30k off btm. 10:45 11:15 0.50 8,000 8,260 PROD1 DRILL DLOG T Perform MAD pass from 8006'to 8260 @ 10 FPM 11:15 11:30 0.25 8,260 8,720 PROD1 DRILL TRIP T RBIH 11:30 14:45 3.25 8,720 8,870 PROD1 DRILL DRLG T Drill ahead. 1.40 BPM,4182 psi. ECD 12.92 4112 BHP 14:45 16:45 2.00 8,870 8,870 PROD1 DRILL WPRT T Pull wiper,31k Off BTM. RBIH,tie in for a+1'correction. Drill solids upto .65 Return trucks are on the way. 16:45 20:00 3.25 8,870 9,020 PROD1 DRILL DRLG T Drill ahead. Swap to new mud system.2 dirty trucks on location. 20:00 22:12 2.20 9,020 9,020 PROD1 DRILL WPRT T Wiper trip to window, PUW=30K, BHP=4110 22:12 00:00 1.80 9,020 9,129 PROD1 DRILL DRLG T 9020', Drill Ahead, 1.45 BPM @ 3950 PSI FS, BHP=4120, RIW=10.3K with DHWOB=1.6K Midnight Depth 9129 11/24/2011 Drill Ahead to 9465, POOH for HOT Failure 00:00 01:15 1.25 9,129 9,170 PROD1 DRILL DRLG T 9129 Midnight depth, Drill ahead, 1.48 BPM @3950 PSI FS, BHP=4120, ECD=12.9 01:15 03:39 2.40 9,170 9,170 PROD1 DRILL WPRT T Wiper to window, PUW=31K, BHP=4110, ECD=12.9 03:39 05:45 2.10 9,170 9,237 PROD1 DRILL DRLG T 9170', Drill Ahead, 1.46 BPM @ 3850 PSI FS, BHP=4155, Clean trip in and out, ECD=12.9 05:45 07:00 1.25 9,237 9,320 PROD1 DRILL DRLG P Drilled back to 9237',end troubled time.continue drilling. 07:00 09:30 2.50 9,320 9,320 PROD1 DRILL DRLG P Wiper to Window 09:30 11:45 2.25 9,320 9,465 PROD1 DRILL DRLG P Drill ahead, 1.46 BPM @ 3880 PSI. 12.96 ECD,4122 BHP. Directional driller having some tool issues.Call town to discuss. Stall out @ 9465', over pull to 35k-puh.wiper up,get call to TOOH to swap out HOT. 11:45 13:45 2.00 9,465 7,215 PROD1 DRILL WPRT P Wiper to window 13:45 15:15 1.50 7,215 72 PROD1 DRILL TRIP T Trip out to replace HOT Begin BHI NPT Page 7 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:15 18:45 3.50 72 72 PROD1 DRILL PULD T Tagged up&spaced out.Conduct PJSM. Undeploy BHA#6, PD BHA #7 with.7 degree motor and Hycalog Bi Center, Make uo to coil and surface test 18:45 19:15 0.50 72 1,704 PROD1 DRILL TRIP T RIH, EDC open.6 BPM 19:15 20:00 0.75 1,704 72 PROD1 DRILL TRIP T Communication lost with BHA. POOH to troubleshoot 20:00 21:30 1.50 72 72 PROD1 DRILL PULD T Tag up and space out, PJSM Strip off well maintaining MP.Trouble shoot problem to UQC and LQC. Change out and retest.Make up to coil and surface test.Strip on well 21:30 23:12 1.70 72 7,155 PROD1 DRILL TRIP T Trip in well with BHA#8, .7 degree motor and Bi center to TD"A"Lateral 23:12 23:15 0.06 7,155 7,171 PROD1 DRILL DLOG T 7155'Log tie in fora+3'correction, close EDC, PUW=30K End BHI NPT, 9.5 HRS 23:15 23:59 0.74 7,171 8,411 PROD1 DRILL TRIP P Trip in to drill,clean pass through window Midnight 8411 11/25/2011 Driill Ahead from 9465 to 10017' 00:00 00:30 0.50 8,411 9,465 PROD1 DRILL TRIP P Tripping in to Drill(cant) 00:30 00:42 0.20 9,465 9,467 PROD1 DRILL DRLG P 9465',Drill ahead, 1.45 BPM @ 3766 PSI FS, BHP=4165, RIW=9.6K DHWOB=2.6K 00:42 01:12 0.50 9,467 9,467 PROD1 DRILL WPRT P DD wiper to reboot computers, PUW=28K 01:12 01:48 0.60 9,467 9,474 PROD1 DRILL DRLG P 9467',Drill ahead, 1.48 BPM @ 3777 PSI FS, BHP=4139 01:48 03:18 1.50 9,474 9,474 PROD1 DRILL WPRT T 9474,Tool not holding tool face, PUH to re image CTK Computer 1.5 HRS BHI NPT 03:18 05:45 2.46 9,474 9,620 PROD1 DRILL DRLG P 9474', 1.45 BPM @ 3800 PSI FS, BHP=4170, ECD=13.1 Tool still acting up 05:45 09:45 4.00 9,620 9,620 PROD1 DRILL WPRT P Wiper up to window. RBIH,tie in for a+5'correction. 09:45 14:00 4.25 9,620 9,770 PROD1 DRILL DRLG P Drill ahead 1.45 BPM 4014 PSI, 4149 BHP 13.07 ECD 14:00 17:15 3.25 9,770 9,770 PROD1 DRILL WPRT P Wiper to the window,29k off BTM. 17:15 19:03 1.80 9,770 9,920 PROD1 DRILL DRLG P Drill ahead, 1.47 BPM 4113 PSI, 4214 BHP, 13.29 ECD 19:03 22:33 3.50 9,920 9,220 PROD1 DRILL WPRT P Wiper to window, PUW=28.5k 22:33 23:59 1.44 9,220 10,017 PROD1 DRILL DRLG P 9220', Drill Ahead, 1.45 BPM @ 3860 PSI FS, BHP=4223 Midnight 10117' 11/26/2011 Condition hole-Kill well,M/U 58 Jts lower liner segmet, RIH Page 8 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 10,017 10,070 PROD1 DRILL DRLG P Drilling ahead 1.45 BPM @ 3860 PSI FS, RIW=7.6K DHWOB=1.6K, BHP=4223 01:00 02:18 1.30 10,070 8,170 PROD1 DRILL WPRT P Wiper to window with tie in, PUW=30K 02:18 03:24 1.10 8,170 10,065 PROD1 DRILL WPRT P Coming upon wiper Geo's called T0, Turn around to pump sweeps and chase to swab,TD=10070' 03:24 07:45 4.36 10,065 0 PROD1 DRILL WPRT P 10065,sweeps coming out, PUW=27K,wipe to swab 07:45 11:15 3.50 0 10,073 PROD1 DRILL TRIP P Wiper to swab complete. RBIH. Note:Called state to give 24 hour BOP test notice(07:40)Test waived by Chuck Scheve.Tie in for+3. RIH to TD @ 10073' 11:15 14:45 3.50 10,073 0 PROD1 DRILL KLWL P Start laying in 9.8 PPG bead pill from TD to 7600'. 12.5 KWL to surface 14:45 15:15 0.50 0 0 PROD1 DRILL SFTY P Watch for no flow for 30 minutes while PJSM for laying down BHA. Well is on a vac. 15:15 16:30 1.25 0 0 PROD1 DRILL PULD P Lay down BHA.Service injectior. 16:30 21:00 4.50 0 1,900 COMPZ CASING PUTB P Run liner, (segment#1)Non-ported bullnose,58 jts slotted liner,& Shorty deployment Sleeve. 21:00 22:00 1.00 1,900 1,946 COMPZ CASING PULD P PJSM, M/U Coil track to liner,strip on well,surface test tool.Tag up and set counters 22:00 23:24 1.40 1,946 7,045 COMPZ CASING TRIP P Trip in hole with"A"later lower section. Non Ported bull nose,58 Jts (1900.49'),shorty deployment sleeve, EDC Closed 23:24 23:30 0.10 7,045 7,055 COMPZ CASING DLOG P Tie into flag for a+1.2'correction. 23:30 23:59 0.49 7,055 7,711 COMPZ CASING TRIP P Trip in with liner,Get PUW @ 7200 @ 30K Midnight Depth 7711' 11/27/2011 Ran"A"Lateral in two runs, 10073 to 7320, Start BOP Test.Witness waived by Chuck Sheve,AOGCC 00:00 00:42 0.70 7,711 9,035 COMPZ CASING TRIP P Continue in well with liner 00:42 00:48 0.10 9,035 9,057 COMPZ CASING DLOG P Log gamma tie in for+2'(+3'total correction with flag) 00:48 01:30 0.70 9,057 10,073 COMPZ CASING TRIP P Trip in liner,set down @ 10073, PUW=33K,Set back on bottom, Pump off liner PUW=28K TOL=8147 01:30 03:45 2.25 10,073 49 COMPZ CASING TRIP P PUH to 10057, remove liner length from counters 8156'.Continue out of well pumping 12.5 completion fluid across the top. Paint EOP flags @ 7200&6200' 03:45 04:45 1.00 49 0 COMPZ CASING PULD P PJSM,conduct 10 min no flow test. Lay down liner running BHA 04:45 05:15 0.50 0 0 COMPZ CASING RURD P Rig up floor to run liner/Service Injector Page 9 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:15 07:15 2.00 0 0 COMPZ CASING PUTB P PJSM, P/U A Lateral upper section 07:15 07:45 0.50 0 895 COMPZ CASING SFTY P PJSM, load up billet&BHI BHA. 07:45 11:45 4.00 895 8,173 COMPZ CASING TRIP P RIH w/lateral"A"upper section,stop @ flag-.05'.Get pu wt,33k.Set liner @ 8169'. Pump off liner,30k pu wt. 11:45 13:45 2.00 8,173 0 COMPZ CASING TRIP P PUH,tie into Gamma,+5' correction. Puts top of liner @ 7323'. TOOH to surface. 13:45 18:00 4.25 0 0 COMPZ CASING PULD P Tagged up. Lay down BHA.Cicurlate out 12.5 out of coil with water to prep for BOP test.Valve crew on location to service tree. Remove checks from UQC.Test inner reel valve 18:00 18:30 0.50 0 0 COMPZ WHDBO SFTY P Crew change, PJSM,Valve alignment, 18:30 00:00 5.50 0 0 COMPZ WHDBO BOPE P Perform Bi Weekly BOPE Test,Test witness waived by Chuck Scheve, AOGCC 11/28/2011 Complete BOPE Test, Drill By Billet @ 7323',TD Build/Turn to 7503',TOOH 00:00 03:00 3.00 0 0 COMPZ WHDBO BOPE P Continue BOPE Test,Complete test @ 0300 03:00 04:00 1.00 0 0 PROD2 STK CTOP P Skid cart forward and install check valves in UQC, Prep to circulate coil back to 12.5 KWF 04:00 05:00 1.00 0 0 PROD2 STK CIRC P Circ coil, Initialy looked like ice plug in putz? Take returns to TT,Open up well fill and check for flow 05:00 07:30 2.50 0 0 PROD2 STK PULD P Change out&PJSM. Load up/Deploy BHA 07:30 10:15 2.75 62 7,165 PROD2 STK TRIP P RIH W/BHA#11, had to slow speed down,counting collars on the way down.Start sending 15 bbls spacer &flo pro down coil to time out to bit @ window depth,Tie for a+3' correction. 10:15 11:45 1.50 7,165 7,323 PROD2 STK CIRC P Tie fora+3'correction.@ 7182'On like down coil w/9.8 flo-pro.Get flow pro all around,shut down to close EDC. RIH Tag TOB @ 7323'. 11:45 15:45 4.00 7,323 7,375 PROD2 STK KOST P PUH, Pumps up 3700 PSI FS. Ease down see light motor work @ 7322.3' Let it drill off,start time drilling 1 FPH,follow KO procedure. Drill down to 7375'. PUH and drift past billet clean.Continue drilling 1.42 BPM @ 3974 PSI,wide open choke,0 WHP. 12.43 ECD,4054 BHP 15:45 17:30 1.75 7,375 7,503 PROD2 DRILL DRLG P 7375', Drill Ahead, 1.4 BPM @ 4190 PSI FS, BHP=4090 17:30 20:15 2.75 7,503 64 PROD2 DRILL TRIP P 7503,Call End Of Build,Trip out for RSM following MP schedule, PUW=31 K 20:15 21:45 1.50 64 0 PROD2 DRILL PULD P At Surface, PJSM, PUD BHA#11 Build/turn BHA 21:45 22:30 0.75 0 0 PROD2 DRILL PULD P Configure BHA/Make up RSM/ load into PDL Page 10 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 0 68 PROD2 DRILL PULD P PD BHA#12,AL-1 lateral BHA with RSM and rebuild Hughs Bi Center, make up to coil track and surface test tool,strip on,tag up and set • counter 11/29/2011 RIH with RSM and Drill, 7503 to 8560 00:00 00:30 0.50 68 68 PROD2 DRILL PULD P prepare to run in hole 00:30 02:18 1.80 68 7,145 PROD2 DRILL TRIP P RIH W/BHA#12, RSM for AL1 lateral section, EDC Open 02:18 03:06 0.80 7,145 7,174 PROD2 DRILL DLOG P Log tie in for+9'correction, Inspect and adjust BHI counter on goose neck, Close EDC, PUW=28K 03:06 03:24 0.30 7,174 7,503 PROD2 DRILL TRIP P RIH to drill,clean pass through window 03:24 05:12 1.80 7,503 7,660 PROD2 DRILL DRLG P 7503', Drill ahead, 1.35 BPH @ 3723 PSI FS, BHP=4130, RIW=11.7K, DHWOB=1.9K 05:12 06:30 1.31 7,660 7,660 PROD2 DRILL WPRT P 7650',Wiper to window with MAD Pass, PUW=29K. RBIH 06:30 08:45 2.25 7,660 7,810 PROD2 DRILL DRLG P 7660, Drill ahead 1.35 BPM @ 3887 PSI,4091 BHP 08:45 09:30 0.75 7,810 7,810 PROD2 DRILL WPRT P 7810',Wiper up 28k PU WT.wipe up to 7242' 09:30 10:45 1.25 7,810 7,960 PROD2 DRILL DRLG P 7810',Drill ahead. 1.37 BPM @ 3860 psi,4129 BHP. ROP 120. 10:45 11:45 1.00 7,960 7,960 PROD2 DRILL WPRT P 7960',Wiper up to window. RBIH,tie in for 0 coreection. 11:45 13:15 1.50 7,960 8,110 PROD2 DRILL DRLG P 7960', Drill ahead 1.37 BPM @ 3850 PSI, 12.84 ECD,4110 BHP. ROP @ 130 FPH 13:15 14:15 1.00 8,110 8,110 PROD2 DRILL WPRT P Wiper up 30k PU WT.to window. RBIH. 14:15 16:15 2.00 8,110 8,260 PROD2 DRILL DRLG P Drill ahead. 1.39 BPM 3950 PSI, 4128 BHP, 12.90 ECD 16:15 17:15 1.00 8,260 8,260 PROD2 DRILL WPRT P 8260',Wiper up 30k 17:15 20:03 2.80 8,260 8,410 PROD2 DRILL DRLG P Drill ahead, 1.37 @ 3800 PSI, 20:03 21:48 1.75 8,410 8,410 PROD2 DRILL WPRT P Wiper to window with tie in, PUW=31K,Corrrect-1' Swap Mud 21:48 23:42 1.90 8,410 8,560 PROD2 DRILL DRLG P 8410', Drill ahead, 1.41 @ 3660 PSI FS, RIW=13K, BHP=4180 23:42 23:59 0.29 8,560 8,322 PROD2 DRILL WPRT P 8560'Wiper to window, PUW=30.5K 11/30/2011 Drilled Ahead to 8860,Out of zone,Set Anchored Billet @ 8120 00:00 01:30 1.50 8,322 8,560 PROD2 DRILL WPRT P Wiper to window, PUW=30.5K 01:30 06:00 4.50 8,560 8,710 PROD2 DRILL DRLG P 8560', Drill Ahead, 1.42 BPM @ 3500PSI FS, BHP=4090, ECD=12.7 06:00 08:00 2.00 8,710 8,710 PROD2 DRILL WPRT P 8710',Wiper up to window 08:00 12:15 4.25 8,710 8,860 PROD2 DRILL DRLG P 8710', Drill ahead. Slow going. continue to drill to identifiy zone. 12:15 15:30 3.25 8,860 91 PROD2 DRILL TRIP T Trip OOH Page 11 of 21 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 15:30 18:30 3.00 91 0 PROD2 DRILL PULD T Tagged up&spaced out. PJSM, PUD BHA Rig steer BHA#12. 18:30 20:00 1.50 0 73 PROD2 DRILL PULD T PD BHA#13 Aluminum Billet,make up coil track amd surface test tool 20:00 22:15 2.25 73 7,150 PROD2 DRILL TRIP T Trip in with billet, EDC Open 22:15 22:21 0.10 7,150 7,179 PROD2 DRILL DLOG T Log Tie in for+12, PUW=27K,Shut EDC 22:21 23:09 0.80 7,179 8,132 PROD2 DRILL TRIP T Trip in to set billet 23:09 23:54 0.75 8,132 5,490 PROD2 DRILL TRIP T 8131.92,Set Billet,TOB=8120,Set @ 180 degrees,Tool shift @ 4450 PSI,Set down 1K,TOOH for drill by BHA. 12/01/2011 Drill by Billet @ 8120, Drill to 8760, BHA Stuck at billet on wiper trip 00:00 01:15 1.25 5,490 69 PROD2 DRILL TRIP T Continue out of well after setting anchored billet 01:15 04:39 3.40 69 72 PROD2 STK PULD T PJSM,at surface, PUD BHA#13 Billet running tools, M/U BHA#14 Drill by and continue to TD. .8 degree motor and bi center bit. PD,make up to coil track and surface test,Strip on.tag up and set counters 04:39 07:15 2.60 72 8,121 PROD2 STK TRIP T Trip in with BHA#14,tie in for a+20'. Rih tag TOB @ 8120.5' 07:15 11:30 4.25 8,121 8,150 PROD2 STK KOST T Pumps up, 1.42 BPM @ 3500 PSI FS. Ease down until slight motor work is noticed,time drill per procedure. Had little to no progress right off the billet. Pick-up&ease back inti it. Had a caouple stalls and had a couple pressure spikes without stalls.Clean up and started to look good,drill down to 8150'. Puh and drift clean. 11:30 13:45 2.25 8,150 8,310 PROD2 DRILL DRLG T 8150',continue drilling, 1.45 BPM @ 3900 PSI, BHP @ 4126. 13:45 15:00 1.25 8,310 8,310 PROD2 DRILL WPRT T Pull wiper,29k pu wt. Pulled a little heavier just below billet @ 8125' otherwise clean. RBIH 15:00 16:15 1.25 8,310 8,460 PROD2 DRILL DRLG T 8310', Drill ahead. 1.39 BPM @ 3754 PSI, 12.54 ECD, BHP 4104 16:15 17:30 1.25 8,460 8,460 PROD2 DRILL WPRT T 8460.0, pull wiper,34k off btm.RBIH 17:30 19:24 1.90 8,460 8,610 PROD2 DRILL DRLG T Drill ahead, 1.4 BPM @ 3600 PSI FS, BHP=4120 19:24 21:24 2.00 8,610 8,610 PROD2 DRILL WPRT T Wiper to window with tie, PUW=31K, tie in correction-5' 21:24 22:36 1.20 8,610 8,760 PROD2 DRILL DRLG T 8606', Drill Ahead, 1.4 BPM @ 3625PS1 FS, BHP=4103, ECD=12.7 22:36 23:06 0.50 8,760 8,125 PROD2 DRILL WPRT T 8760',Wiper to window, PUW=31K 23:06 00:00 0.90 8,125 8,125 PROD2 DRILL WPRT T Coming up hole past billet,22 FPM Min pump rate pulled 4 K over.RBIH, unable to run past 8125, Unable to orient.motor stalled.Attemp to work down then up.Consult with town. Page 12 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/02/2011 24 hr summary RIH With Fishing BHA, Latch fish @ 8072, No jars down,Jar up 28 times, Release fish and POOH,Cut 540' coil rehead 00:00 02:00 2.00 8,125 8,125 PROD2 DRILL WPRT T Stuck at Billet,consult with town, work pipe,consult,work pipe to orienter limit--19k 02:00 02:15 0.25 8,125 8,125 PROD2 DRILL CTOP T Release from BHA.Left 56.27'fish in hole, Estimate TOF @ 8068.7, PUW=30K 02:15 02:45 0.50 8,125 7,189 PROD2 DRILL TRIP T PUH to above window, Remove length of fish left in well from counters. Prep pits to kill well 02:45 04:15 1.50 7,189 7,189 PROD2 DRILL KLWL T Trucks here empty pits for swap, 04:15 07:00 2.75 7,189 0 PROD2 DRILL CIRC T Pump 5 BBI Hi vis spacer/12.5 PPG KWF 07:00 07:30 0.50 0 0 PROD2 DRILL SFTY T Tagged up. PJSM and no flow check. Well dead. 07:30 08:45 1.25 0 0 PROD2 DRILL PULD T Lay down BHA. PJSM. Pick-up fishing BHA 08:45 12:30 3.75 0 7,950 PROD2 DRILL TRIP T RIH pumping 12.5 @ min rate. Tie in for a+22' 12:30 15:45 3.25 7,950 8,072 PROD2 DRILL FISH T 7950'Pick-up wt @ 33k. RBIH tag fish @ 8072'. Pull up 6k over, appear to be latched.Cycle 4 diferent times to Stack 6k WOB.Jars not going off down.Discuss options with town. Decided to jar up. Hit 28 up licks, starting @-7k WOB to-15 WOB. No movement. Pump off easily @ 1.3 BPM. 15:45 18:00 2.25 8,072 8,072 PROD2 DRILL TRIP T Trip OOH, keeping hole full of KWF across the top until above the window. Pump down coil for pipe displacement. 18:00 18:30 0.50 8,072 117 PROD2 DRILL SFTY T Crew change out/valve checklist 18:30 20:00 1.50 117 0 PROD2 DRILL PULD T At surface,flo check, PJSM Lay down BHA Fishing tools 20:00 23:24 3.40 0 0 PROD2 DRILL CTOP T PJSM. R/U and cut 500'pipe, Pump slack and cut 40'to find wire 23:24 00:00 0.60 0 0 PROD2 DRILL CTOP P Prep pipe and install CTC 12/03/2011 M/U Hip Tripper, RIH,Jar down/Up. Pump lube pill,Jar down/Up,trip out, POOH Make up Jars, RIH 00:00 00:30 0.50 0 0 PROD2 DRILL CTOP T continue install Coil connector,pull test to 35K 00:30 01:30 1.00 0 0 PROD2 DRILL CTOP T Install UQC 01:30 02:06 0.60 0 0 PROD2 DRILL CTOP T Pressure test CTC and upper quick connect. Roll coil back to 12.5 KWF, unstab injector, move off of floor 02:06 03:06 1.00 0 74 PROD2 DRILL PULD T M/U BHA#16,2 1/2 GS Spear, Hip Tripper,Accelorator, 3 weight bars, coiltrack 03:06 04:06 1.00 74 74 PROD2 DRILL PULD T Complete Injector maintenance, Make up coil to coil trak, surface test tool,tag up and set counters,Adjust gooseneck counter Page 13 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:06 06:30 2.40 75 7,218 PROD2 DRILL TRIP T RIH,pumping, EDC open. 06:30 07:45 1.25 7,218 7,218 PROD2 DRILL CIRC T Getting 9.8 drilling mud to the bit, continue circulating well from 12.5 to 9.8 drilling mud. 07:45 13:00 5.25 7,218 8,072 PROD2 DRILL FISH T RIH Pu Wt 30k. Latch fish @ 8072'. Get Hipp tripper dialed in. 1.4 WOB .96 BPM @ 3860 PSI.See hammer working on display.Work hammer down for 1.25 hrs.Work hammer up for about an hour.Alternate back and forth a couple times. Pump 20 bbl lube pill.Sqeeze in the choke to try to get the lubes across the fish. Work down/up again, no movement. Pump off fish. PUH to the window. 13:00 16:30 3.50 8,072 7,220 PROD2 DRILL CIRC T Open EDC, had to wait for spacer& mud to be waited up.Get 12.5 KWF above us-Trip out laying 12.5 KWF. 16:30 18:00 1.50 7,220 0 PROD2 DRILL TRIP T Trip out 18:00 21:00 3.00 0 68 PROD2 DRILL PULD T Crew change,At Surface, Flow check well, PJSM, Pull BHA#16 Hip triper,M/U and run BHA#17 Fishing string with up/down jars 21:00 22:30 1.50 68 7,160 PROD2 DRILL TRIP T Trip in hole, EDC Open 22:30 00:00 1.50 7,160 8,050 PROD2 DRILL TRIP T Stop and shut EDC, PUW=31K, Continue in hole,to TOF,Work on injector hydraulics to obtain traction pressure 12/04/2011 Latch fish, unable to jar down,Jar up 21 hits, POOH with fish,WOW Phase 3 00:00 00:30 0.50 8,050 8,050 PROD2 DRILL FISH T Working with hydraulics to get traction pressure up 00:30 02:06 1.60 8,050 8,040 PROD2 DRILL FISH T Start jarring,Attempting to get jars to fire going down for 6 cycles. No hits, Jar up 21 times then pulled free. Discussed risks of running back in hole. POOH without trying to set back down 02:06 04:18 2.20 8,040 86 PROD2 DRILL TRIP T Trip out fill accross top with 12.5 PPG 04:18 04:48 0.50 86 0 PROD2 DRILL PULD T At surface, No Flow check, PJSM Lay down fishing BHA 04:48 07:00 2.21 0 0 PROD2 DRILL PULD T Lay down recovered fish, Left bottom of orienter,2 3/8 extreme motor and bi center bit in hole. Get crews changed out, Phase 2 weather. 07:00 21:00 14.00 0 0 PROD2 DRILL CTOP T Stand by for weather, Phase 3 21:00 21:30 0.50 0 0 PROD2 DRILL SFTY T PT Meeting,formulate plan forward 21:30 23:30 2.00 0 0 PROD2 DRILL RGRP T Repair leaking hose fitting feeding B5 on stack/Prep billet to run 23:30 23:59 0.49 0 PROD2 DRILL SFTY P PJSM,M/U Billet BHA 12/05/2011 RIH with Anchored Billet, Set down @ 7343, Pick up,orient,set down 2'lower, POOH Run FCO BHA, POOH for Billet Page 14 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:30 1.50 0 72 PROD2 DRILL PULD T Continue making up billet BHA, Make up to coil track,Make up injector,tag up and set counters 01:30 03:30 2.00 72 7,135 PROD2 DRILL TRIP T RIH, EDC open 03:30 03:36 0.10 7,135 7,174 PROD2 DRILL DLOG T Log tie in for+20'correction, PUW=32K,Close EDC 03:36 04:00 0.40 7,174 7,343 PROD2 DRILL TRIP T RIH to set Billet, Set down at 7343', Pick up @ 32K, Orient 90 degrees to move slips, RBIH and set down @ 7345.Overpull to 35K, PUH to above window 04:00 05:30 1.50 7,343 102 PROD2 DRILL TRIP T Consult with town, POOH for clean out BHA 05:30 06:30 1.00 102 102 PROD2 DRILL TRIP T Suspend ops for PHASE 3 06:30 10:15 3.75 0 0 PROD2 DRILL PULD T Access now phase 2, Lay down anchored billet.Change out crew on their way from camp. Do change out, do handover with crew in the dog house, PJSM on picking up BHA. Pick-up BHA#19 10:15 13:00 2.75 62 7,214 PROD2 DRILL TRIP T RIH,send down spacer,tie in for a+ 21'correction. Stop @ 7214' 13:00 14:30 1.50 7,214 7,214 PROD2 DRILL CIRC T 7214',continue circulating 9.8 Flo Pro,recovering 12.5 KWF. 14:30 17:54 3.40 7,214 62 PROD2 DRILL FCO T RIH @ min rate to 7900',no problem. Kick up rate to 1.25 BPM, POOH @ 22 FPM,clean open hole up into the window, chase to surface.Get a good slug of formate to surface and light crude. 17:54 18:54 1.00 62 62 PROD2 DRILL FCO T Crew Change,valve check list, PJSM to clear choke lines. Heavy mung/ aluminum shavings in choke.Get squared away before PUD BHA#19 18:54 20:24 1.50 62 0 PROD2 DRILL PULD T PJSM, PUD BHA#19, FCO BHA 20:24 22:24 2.00 0 73 PROD2 DRILL PULD T PJSM, PD BHA#20 Anchored Aluminum billet 22:24 00:00 1.60 73 6,750 PROD2 DRILL TRIP T Trip in hole BHA#20- Midnight depth 6750 12/06/2011 RIH with anchored billet to setting depth. Set anchor @ 7861.95',single slip 180 TF. POOH.TOB 7850'. Deploy drilling BHA.(.8 AKO, Hycalog Bi-Center).Tag TOB 7850.5',sidetrack for AL1 lateral with a 140 LOHS TF.Mulitple stalls from 7851.1',adjust TF 110 LOHS to 7852.8'. adjust TF back to 140 LOHS by 7853.1'cont. milling. Clean drift through sidetrack,drill ahead AL1 Lateral performing wiper trips every 150'. 00:00 00:12 0.20 6,750 7,140 PROD2 DRILL TRIP T Continue in hole 00:12 00:18 0.10 7,140 7,175 PROD2 DRILL DLOG T Tie in to K1 for+20', PUW=27K, Close EDC 00:18 00:54 0.60 7,175 7,862 PROD2 DRILL TRIP T RIH to Billet set depth @ 7861.95, orient to 180 degrees. Pumps on and see tool shift @ 4200 PSI,Set down 4K Top Of Billet=7850' 00:54 02:54 2.00 7,862 100 PROD2 DRILL TRIP T POOH after billet set 02:54 03:12 0.30 100 0 PROD2 DRILL SFTY T At surface, PJSM, PUD BHA#20 Billet running tools Page 15 of 21 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 03:12 05:54 2.70 0 0 PROD2 DRILL PULD T Undeploy BHA#20, Deploy BHA# 21 05:54 06:12 0.30 0 0 PROD2 DRILL SFTY T Crew changeout 06:12 06:30 0.30 0 0 PROD2 STK PULD T finish deploy BHA 06:30 08:12 1.70 0 7,140 PROD2 STK TRIP T RIH 08:12 08:24 0.20 7,140 7,179 PROD2 STK DLOG T Tie into RA, +20' 08:24 08:48 0.40 7,179 7,851 PROD2 STK TRIP T Continue RIH to billet 08:48 11:24 2.60 7,851 7,852 PROD2 STK KOST T Tag billet,start time milling at 7850.5, 1.4 BPM,3500 CTP,4035 BHP, 18K RIW,220(140 LOHS)TF Stalled at 7851.1 restart 11:24 14:24 3.00 7,852 7,852 PROD2 STK KOST T Stalled after stacking some weight. 7 Stalls at this depth. 14:24 16:24 2.00 7,852 7,880 PROD2 STK KOST T 250(110 LOHS)TF allowed continued time miling,adjusted TF back from 7852.8'to 220 by 7853.1. Continue milling and drilling,dry drift accross billet clean 16:24 17:54 1.50 7,880 8,010 PROD2 DRILL DRLG T Drilling ahead, 1.4 BPM,3500 CTP, 4050 BHP, 17:54 18:54 1.00 8,010 8,010 PROD2 DRILL WPRT T Wiper trip back to window,30K PUW 18:54 20:24 1.50 8,010 8,160 PROD2 DRILL DRLG T Drill ahead, 1.4 BPM,3770 CTP on bottom,4088 BHP, 15K CTW, 1-1.5K WOB 20:24 21:54 1.50 8,160 8,160 PROD2 DRILL WPRT T Wiper trip back to window 7270',30K PUW 21:54 23:15 1.35 8,160 8,310 PROD2 DRILL DRLG T Drill Ahead, 1.4 BPM, 3871 CTP on bottom,4106 BHP, 13K CTW, 1-2K WOB 23:15 00:00 0.75 8,310 8,310 PROD2 DRILL WPRT T Wiper trip back to window, 30K PUW. Log RA marker 7266-7283',-2' correction 12/07/2011 Drill AL1 lateral performing wiper trips back to window every 150'drilled, lowering pump rates in the higher CT fatigue area.3K overpulls on wiper trips at 9093'. 00:00 00:48 0.80 8,310 8,310 PROD2 DRILL WPRT T RBIH to drill 00:48 02:12 1.40 8,310 8,460 PROD2 DRILL DRLG T Drill Ahead 1.4 BPM,3915 CTP on bottom,3554 CTP off bottom,4112 BHP, 12K CTW, 1-1.5K DHWOB 02:12 03:42 1.50 8,460 8,460 PROD2 DRILL WPRT T Wiper trip back to window 7285',30K PUW 03:42 05:12 1.50 8,460 8,610 PROD2 DRILL DRLG T Drill Ahead 1.4 BPM,3854 CTP on bottom,3554 CTP off bottom,4108 BHP, 10K CTW, 1-2K DHWOB 05:12 06:54 1.70 8,610 8,610 PROD2 DRILL WPRT T Wiper trip to window,30K PUW 06:54 08:12 1.30 8,610 8,760 PROD2 DRILL DRLG T Continue drilling, 1.4 BPM,3550 CTP,4100 BHP, 14K RIW 08:12 09:24 1.20 8,760 7,260 PROD2 DRILL WPRT T Wiper to window, 31K PUW,slight over pull and motor work at 8510' 09:24 09:42 0.30 7,260 7,290 PROD2 DRILL DLOG T Tie in to RA,-3' 09:42 10:36 0.90 7,290 8,760 PROD2 DRILL WPRT T Wiper back in hole, 17K RIW. Start mud swap while RIH Page 16 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:36 11:36 1.00 8,760 8,860 PROD2 DRILL DRLG T Continue drilling, 1.4 BPM,3500 CTP,4120 BHP, 14K RIW 11:36 12:06 0.50 8,860 8,910 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM,3500 CTP,4120 BHP, 14K RIW 12:06 14:12 2.10 8,910 8,910 PROD2 DRILL WPRT P Wiper to window,32K PUW 14:12 15:36 1.40 8,910 9,060 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM,3500 CTP,4120 BHP, 14K RIW 15:36 17:51 2.25 9,060 9,060 PROD2 DRILL WPRT P Wiper to the window,33K PUW 17:51 19:36 1.75 9,060 9,210 PROD2 DRILL DRLG P Drill Ahead 1.4 BPM,3873 CTP on bottom, 3526 CTP off bottom,4162 BHP, 10K CTW, 1-2K DHWOB 19:36 22:21 2.75 9,210 9,210 PROD2 DRILL WPRT P Wiper trip back to window, 32K PUW. 3K overpull at 9093'. Lower pump rates thru high CT fatigue areas. Log RA marker for depth correlation.-3'correction. RBIH had 500lbs set down at 9093' on DHWOB,3K CT surface wt. 22:21 00:00 1.65 9,210 9,360 PROD2 DRILL DRLG P Drill Ahead 1.4 BPM,3760 CTP on bottom,3426 CTP off bottom,4188 BHP,7-8K CTW, 1-2K DHWOB 12/08/2011 Drill AU lateral performing wiper trips every 150'drilled, lowering pump rates thru higher CT fatigue areas. Overpull/Setdowns at 9093'.Over pull 1k thru billet at 7850'.As precautionary,shut pumps down while pulling thru billet during wiper trips. 00:00 02:45 2.75 9,360 9,360 PROD2 DRILL WPRT P Wiper trip to window 33K PUW. 3K overpull at 9093'-9086'. Lower pump rates.75 BPM while cycling CT through high fatigue area. 7700-7635'. (bit depth) Lower pump rate to minimum rate at 9093'.Still see 500Ibs set down on DHWOB. 02:45 05:06 2.35 9,360 9,510 PROD2 DRILL DRLG P Drill Ahead 1.4 BPM,3730 CTP on bottom,3366 CTP off bottom,4202 BHP, 10K CTW, 1-2K DHWOB 05:06 06:54 1.80 9,510 7,260 PROD2 DRILL WPRT P Wiper trip back to window,-1K overpull on WOB at the billet at 7851' 06:54 07:12 0.30 7,260 7,290 PROD2 DRILL DLOG P Tie in to RA,-2' 07:12 08:36 1.40 7,290 9,510 PROD2 DRILL WPRT P Wiper back in hole,dry drift bilet down and up were clean. 08:36 10:24 1.80 9,510 9,660 PROD2 DRILL DRLG P Resume drilling, 1.4 BPM,3550 CTP,4200 BHP, 9K RIW 10:24 13:42 3.30 9,660 9,660 PROD2 DRILL WPRT P Wiper to window,32K PUW,offline with pump while pulling past billet at 7851', no overpull. 13:42 16:06 2.40 9,660 9,810 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM, 3500 CTP,4200 BHP, 11K RIW 16:06 19:21 3.25 9,810 9,810 PROD2 DRILL WPRT P Wiper to window,32K PUW,off-line with pump while pulling past billet at 7851', 19:21 21:21 2.00 9,810 9,960 PROD2 DRILL DRLG P Drill Ahead 1.4 BPM,3880 CTP on bottom,3466 CTP off bottom,4297 BHP, 10K CTW, 1-2K DHWOB Page 17 of 21 Time Logs Date From To Dur S.Death E.Depth Phase Code Subcode T Comment 21:21 23:06 1.75 9,960 9,960 PROD2 DRILL WPRT P Wiper trip to window, 32K PUW 23:06 00:00 0.90 9,960 9,960 PROD2 DRILL WPRT P RBIH at 7875'(jog) 100'. POOH cont wiper trip PUH thru billet w/o pumps. Did not see billet.Cont wiper trip. Log RA marker for depth correlation. -5'correction. 12/09/2011 Drill AL1 lateral performing wiper trips every 150'drilled. Lower pump rates thru high CT fatigued areas. Perform 100'jog below billet(7850'). PUH thru billet w/o pumps, not seeing any weight bobbles. Perform mud swap at 10125'. 00:00 01:30 1.50 9,960 9,960 PROD2 DRILL WPRT P RBIH,500lbs set down on DHWOB at 9093'and 9730' 01:30 03:00 1.50 9,960 10,052 PROD2 DRILL DRLG P Drill Ahead 1.4 BPM,3774 CTP,7K CTW, 1-2K WOB,4280 BHP 03:00 07:00 4.00 10,052 10,052 PROD2 DRILL WPRT P PUH,34K Swab leaking on mud pump 2. Pump 1 air locked. Cont to PUH repairing pump. 07:00 07:54 0.90 10,052 10,125 PROD2 DRILL DRLG P Drill Ahead 1.4 BPM,3774 CTP,7K CTW, 1-2K WOB,4280 BHP 07:54 11:42 3.80 10,125 10,125 PROD2 DRILL WPRT P Wiper to window,32K PUW 11:42 16:00 4.30 10,125 10,290 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM,3500 CTP,4270 BHP. Start new mud down coil. 16:00 20:15 4.25 10,290 10,290 PROD2 DRILL WPRT P Wiper to the window,32K PUW. Log RA marker for depth correction.-7' correction 20:15 22:15 2.00 10,290 10,440 PROD2 DRILL DRLG P Drill Ahead, 1.4 BPM,3700 CTP, 4293 BHP, 1-2K WOB,220 MP choke 22:15 00:00 1.75 10,440 10,440 PROD2 DRILL WPRT P Wiper trip to window,32K PUW. 12/10/2011 Drill AL1 Lateral to TD 10810' 00:00 02:15 2.25 10,440 10,440 PROD2 DRILL WPRT P Cont Wiper trip 02:15 02:30 0.25 10,440 10,456 PROD2 DRILL DRLG P Drill Ahead 1.4 BPM,3519 CTP,8K CTW,220 MP choke 02:30 02:45 0.25 10,456 10,456 PROD2 DRILL WPRT P PU orient TF for end stop placement, Unable to RIH stacking. PUH/RIH 30 FPM in order to pipe to slide 02:45 04:36 1.85 10,456 10,567 PROD2 DRILL DRLG P Drill Ahead 1.4 BPM,3750 CTP,5K CTW,200 MP choke 04:36 08:48 4.20 10,567 10,567 PROD2 DRILL WPRT P Wiper to window, 33K PUW 08:48 12:36 3.80 10,567 10,603 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM,3500 CTP,4330 BHP, 10K RIW. In Ankerite... 12:36 15:30 2.90 10,603 10,715 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM,3500 CTP,4330 BHP, 10K RIW. Through Ankerite,0 to-5K surface weight for 1-2K WOB Pumped low/high vis sweeps Page 18 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 20:15 4.75 10,715 10,715 PROD2 DRILL WPRT P Wiper trip to window,36K PUW. Perform 100'jog below billet, PUH thru billet w/o pumps. Lower pump rates cycling CT thru high fatigue area. Log RA marker for depth correlation. -6'correction 20:15 22:15 2.00 10,715 10,800 PROD2 DRILL DRLG P Drill ahead 1.5 BPM, 3830 CTP, 4363 BHP,4.5K CTW, 1-2K DHWOB. 22:15 00:00 1.75 10,800 8,100 PROD2 DRILL WPRT P TD AL1 lateral at 10810'. Pump 10brls low/high sweeps POOH to swab valves 12/11/2011 Perform wiper trip to swab valves, RBIH to 10811'. Lay in liner running pill(9.8ppg FP)to window, KWF (12.5ppg K-formate)to surface. PU/MU/RIH AL1 liner(67 slotted jnts). Release liner on bottom. BOL 10817', TOL 8612'. POOH 00:00 02:30 2.50 8,100 0 PROD2 DRILL WPRT P Cont.wiper trip to swab valves 02:30 05:00 2.50 0 7,140 PROD2 DRILL WPRT P RBIH,large amounts of cuttings all the way to surface and RBIH to 5000'. 05:00 05:15 0.25 7,140 7,140 PROD2 DRILL DLOG P Tie in depth to K1.-11'correction 05:15 07:06 1.85 7,140 10,811 PROD2 DRILL WPRT P Cont RIH 07:06 11:06 4.00 10,811 0 PROD2 DRILL DISP P Tag TD at 10811', lay in 9.8 ppg liner running pill in open hole, 12.5 ppg KWF from window to surface 11:06 11:30 0.40 0 0 PROD2 DRILL SFTY P Check well for flow, PJSM for lay down drilling BHA 11:30 12:18 0.80 0 0 PROD2 DRILL PULD P Lay down drilling BHA 12:18 12:42 0.40 0 0 COMPZ CASING SFTY P PJSM for liner operations 12:42 16:12 3.50 0 2,204 COMPZ CASING PUTB P RU floor for liner operations. PU 67 joints slotted liner for lower section of AU liner. Kick while tripping drill after joint#5. 16:12 17:12 1.00 2,248 2,248 COMPZ CASING PUTB P MU coiltrack tools and injector 17:12 18:27 1.25 2,248 7,123 COMPZ CASING RUNL P RIH 18:27 19:48 1.35 7,123 10,814 COMPZ CASING RUNL P Tie into first EOP flag.+25' correction. Record up in down weights.33K up, 17K down.RIH to TD 19:48 20:48 1.00 10,814 7,135 COMPZ CASING RUNL P Depth-1.5'passing second EOP flag.Tag bottom 10814.3'CTES counter.(BHI counter quit working at 10811'due to software issue, problem corrected,adjusted BHI depth 10826'). Release liner at max pump rate 4350 psi CTP. Liner released 33K PUW. DHWOB 0. Line up to pump across top in order keep liner running pill displaced in OH. Remove liner length from bit depth. POOH to K1 for tie in. Page 19 of 21 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 20:48 21:03 0.25 7,135 7,135 COMPZ CASING RUNL P Log K1 for depth correclation.-9' correction. 21:03 23:03 2.00 7,135 0 COMPZ CASING RUNL P POOH 23:03 23:18 0.25 0 0 COMPZ CASING SFTY P At surface, Monitor well for flow, PJSM 23:18 00:00 0.70 0 0 COMPZ CASING PUTB P LD BHA#22 12/12/2011 PU AL1 upper liner.On Joint 17 well started flowing. PU 2 3/8"safety joint with TIW valve.shut in well with both 2 3/8"P/S rams. Bullhead 90brls 12.5ppg(P.Formate)down annulus.Confirm well dead.Cont. PU/MU/RIH AL1 upper liner. Release upper liner BOL 8612'.TOL 7238'.Swap well to seawater,freeze protect well. Undeploy BHA 23. Set BPV. Blow down rig and CT,prepare to move rim. 00:00 00:15 0.25 0 0 COMPZ CASING PUTB Prep floor to PU liner 00:15 01:00 0.75 0 0 COMPZ CASING PUTB P PU 17jnts AL1 liner 01:00 01:15 0.25 0 0 COMPZ CASING OWFF T Fluid level rising, Monitor well 01:15 02:45 1.50 0 0 COMPZ CASING OWFF T Well flowing,pick up safety joint, spaceout across both 2 3/8"P/S rams and shut in well.Monitor well for psi against MP choke. 1 hour shut in-48psi 02:45 04:00 1.25 0 0 COMPZ CASING CIRC T PJSM,WHP 67psi/rising slowly. bullhead 90bbrls KWF down Kill line. 04:00 04:45 0.75 0 0 COMPZ CASING OWFF T Offline with pumps. Monitor well for flow. No flow. 04:45 05:00 0.25 0 0 COMPZ CASING SFTY T PJSM,to pu liner 05:00 08:06 3.10 0 1,418 COMPZ CASING PUTB P PU AL1 upper liner and coiltrack tools 08:06 09:30 1.40 1,418 7,118 COMPZ CASING RUNL P RIH with liner 09:30 10:00 0.50 7,118 8,615 COMPZ CASING RUNL P Correct to flag-21',33K PUW, 16K RIW. Contiinue RIH 10:00 10:18 0.30 8,615 7,140 COMPZ CASING RUNL P Tag lower liner at 8613',relaease liner,open EDC,start SW down coil. 10:18 10:36 0.30 7,140 7,200 COMPZ CASING DLOG P Tie in to foramation,-2', Corrected liner top at 7238' 10:36 14:12 3.60 7,200 0 DEMOB WELLPF DISP P Swap well over to SW, POOH. FP with 25 BBIs diesel 14:12 14:30 0.30 0 0 DEMOB WELLPF SFTY P PJSM for undeploy 14:30 16:18 1.80 0 0 DEMOB WELLPF PULD P Undeploy BHA 16:18 16:48 0.50 0 0 DEMOB WHDBO SFTY P PJSM for BPV 16:48 20:00 3.20 0 0 DEMOB WHDBO NUND P Set BPV 20:00 20:15 0.25 0 0 DEMOB WHDBO SFTY P PJSM 20:15 00:00 3.75 0 0 DEMOB WHDBO NUND P Flush rig with inhibitor, blow down rig and CT with N2 12/13/2011 ND BOP's,Move rig 00:00 00:45 0.75 0 0 DEMOB WHDBO CTOP P RU to unstab CT, RD tiger tank hardline from rig 00:45 01:00 0.25 0 0 DEMOB WHDBO SFTY P PJSM 01:00 02:45 1.75 0 0 DEMOB WHDBO CTOP P Unstab CT from inj. head,secure CT to drum out of horseshead Page 20 of 21 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 02:45 03:00 0.25 0 0 DEMOB WHDBO NUND P PJSM 03:00 06:00 3.00 0 0 DEMOB WHDBO NUND P ND stack, interconnect, RDMO Rig released at 0600 Page 21 of 21 . jT Regg, James B (DOA) 2-11- 13¢ From: Winfree, Michael Alex(Jr.) [Michael.A.Winfree©conocophillips.com] i�'�� I( Sent: Monday, December 12, 2011 2:29 PM Kerr To: Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay Cc: Gantt, Lamar L; Nabors CDR2 Company Man Subject: 2K-28 CTD (PTD 211-134) Functioned BOPE to Prevent Flow of Fluids from the Well Guy, Per AOGCC Industry Guidance Bulletin No.10-003:Reporting BOPE Use to Prevent the Flow of Fluids from a Well Date and time BOPE Used: 12/12/2011 at 1:15 AM Well: 2K-28AL1 Location: 2K-Pad PTD Number: 211-134 ✓ Rig Name: Nabors CDR-2 Operator Contact: Mike A. Winfree 907-265-6820 Operations Summary: After picking up 17 of 41 joints on the second segment of liner, the driller noted the displacement was off. Shut down and monitored the well. Observed slight rise in fluid level. Made up the safety joint, spaced out across BOP stack and shut in the well. Saw well head pressure increase to 48 psi in 1 hour. Made a decision to bullhead KWF down the wellbore. Pumped 90 bbls 12.5 KWF, shut down and observed well. Well was static with no flow observed for 45 minutes. Once well was dead, resumed running in the hole with 2-3/8"slotted liner completion. BOPE used: 2-3/8" Pipe/Slip Rams ✓ Reason for BOPE Use: Slight flow observed after noting displacement was off while running liner Last BOPE Test: Full BOPE test completed 11/28/2011 ✓ Actions Taken/To Be Taken: The liner is currently set on depth, with the well displaced from KWF to seawater and freeze protected to-2,000' MD. The well will be secured and the rig prepared to move to 2K-08. A full BOPE test is planned after rigging up on the next well. Please let me know if you need additional information regarding this operation. -Mike Mike A. Winfree Drilling Engineer 907.265.6820 Direct 907.242.0246 Cell 1 sl:ity.: 1 riT �+ 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 Lamar Gantt CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K-28AL1 ConocoPhillips Alaska, Inc. Permit No: 211-134 Surface Location: 3' FNL, 94' FEL, SEC. 11, T1ON, R8E, UM Bottomhole Location: 420' FNL, 2028' FEL, SEC. 14, T1ON, R8E, UM Dear Mr. Gantt: Enclosed is the approved application for permit to redrill the above referenced service well. The permit is for a new wellbore segment of existing well KRU 2K-28A, Permit No 211- 133, API 50-103-20385-01. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or 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 revo•. Lon or suspension of the permit. ,re i r, K. Norm- • : ioner DATED this 7day of November, 2011. cc: Department of Fish 8a Game, Habitat Section w/o end. (via e-mail) Department of Environmental Conservation w/o end. (via e-mail) STATE OF ALASKA RECE1VErg A, .(A OIL AND GAS CONSERVATION COMI ;ION ICT 9 7 2011 PERMIT TO DRILL 20 AAC 25.005 ►lSkit SII & Gas CanCans_Commission L 1 a.Type of Work: lb.Proposed Well Class: Development-Oil ElService- Winj E - Single Zone Q , 1 c.Specify ifs II i7 ,o sed for: Re Drill ❑ Redrill EStratigraphic Test ❑ Development-Gas El Service-Supply El Multiple Zone El Coalbed Gas ' as f4ydrates ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 1 2.Operator Name: 5. Bond: Q Blanket ❑ Single Well ❑ 11.Well Name and Number: 595 ConocoPhillips Alaska,Inc. Bond No. 59-52-180 . 2K-28AL1 - 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage AK 99510-0360 MD: 10,900 . TVD: 6210 Kuparuk River Field 4a. Location of Well overnmental Section): 7.Property Designation(Lease Number): Ji Kuparuk River Oil Pool . Surface: 3 SL(G,94'FE Sec 10N,RO8E,UM ADL 25588 ALK 2674 k .__S--(,,..0...›(-24)/0./O•// 7v•io %I Top of Productive Horizon/-1"A"ki f— 8.Land Use Permit: .Approximate Spud Date: 2.3i/b12.36.rFNLy2g Sec 11,T10N,RO8E,UM 2674,2679 11/1/2011 Total Depth: -e- in'ie~i�/ 9.Acres in Property: 14.Distance to Nearest Property: 420'FNL4.6.20r L,Sec 14,T10N,RO8E,UM '' 2560 9,800'to KPA Boundary -zli AP eo,,t,•// 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above I 154 feet 15.Distance to Nearest Well Open Surface x- 498,310 y- 5,938,300 . Zone-4 GL Elevation above I 40 feet to Same Pool: 2K-09, 1,600' 16.Deviated wells: Kickoff depth: 7,380 feet . 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) - Maximum Hole Angle: 90 degrees Downhole: 4025 - Surface: 3962 - - -- 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8 4.7 ppf L-80 STL 3,660 7230 6061 10890 6208 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 6800 6550 6377 6265 Casing Length Size Cement Volume MD TVD Conductor/Structural 16 Pre-Installed 220 220 St uctural 19 0 Surface 3,242 7-5/8 290 sx AS III,200 sx LiteCrete 3272 2956 Production 7104 5-1/2 215 sx GasBLOK 7129 6128 Production 407 3-1/2 included above 7536 4980 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): (7222-7228)(7268-7284)(7300-7320) (6204-6209)(6243-6256)(6269-6286) 20. Attachments: Property Plat ❑ BOP Sketch❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date 8/6/2011 22. I hereby certify that the foregoing is true and correct. Contact Mike A.Winfree Printed Name Lamar Gantt Title CTD Engineering Supervisor 1 Signature � � 4Phone 263-4021 Date 8/6FPOt'I- (0/7/n Commission Use Only Permit to Drill ,( ( /3 VAPI Number: //�.� ,,-'70L-/1'/��ermit Approval See cover letter for other Number: ( 50-/Z)� -Z-&jC S 0-)` --Date: AVA 1 requirements. Conditions of approval: If box is checked,� well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: r12/Other: .,t 4600 pSc 13d/ *--57.5 /�S� 1-- Samples req'd: Yes El [v] No r Mud log req'd: Yes ❑ Flo [2/ i°-2.500 /Os Z. Lm AnrIA4 -1---;g4"F'C -.,.) HzS measures: Yes[2/No❑ Directional svy req'd: Yes j No ❑ - u(f:..... 0/0.4.....A-0-0, ;►. 4-cc04 '/ A/o Z M Cr- re3 ...Lre.9 %� APPROVED BY THE COMMISSION DATE: //' ?"'/( O / ,COMMISSIONER 7t-- ,. /( ,�_t( ic 0/ 1 AI Form 10-401(Revised 7/2009) This permit i Ii or123o4rt k`frpn1tiie date of approval(20 AAC 25.005(g)) Submit in Duplicate Davies, Stephen F (DOA) From: Winfree, Michael Alex (Jr.) [Michael.A.Winfree@conocophillips.com] Sent: Monday, October 10, 2011 3:58 PM To: Davies, Stephen F (DOA) Subject: 2K-28 CTD APD Coordinate Revision (Original PTD#201-154) Mr. Davies, Per our conversation regarding the surface coordinates for well 2K-28. The coordinates from the original PTD are correct with the surface location in Section 11. I recalculated the surface coordinates and matched the original permit as well. The Application for the Permit to Drill 2K-28A and 2K-28AL1 should read: Surface Coordinates for Both Laterals: r Legal Description --- — 1 Township: 1010117."3. N Range: 1008 E Meridian: 0 Section:li i FNL 13.2507134 FEL 194.167277 6111 . lt Top of Productive Horizon For 2K-28A a : tr-1zh Legal Description— __ _ . —__ _ ,'t /0 aff Township: ra— joi N •, Range: 008 E 1 Meridian: N Section: -n FNL 12310.6875 FET—E 12655.0915 Top of Productive Horizon for 2K-28AL1 Lateral: -Legal Description _ Township: 1010 IFE Range: 008 ICE I Meridian: Section.ii FNL 12346.1940 FWL 12560.0337 Total Depth for 2K-28A Lateral is Correct Total Depth for 2K-28AL1 Lateral: 1 --Legal Description— -- Township: 010 IFE Range: 008 E + Meridian: IT. Section:114 FNL + 420.85446 FFCE 12028.2990 After further investigation, I found my error was inputting the site location coordinates rather than the surface coordinates into the conversion program. After reviewing the remaining coordinates I found, and fixed, some cut and paste errors. The correct coordinates are listed above. Please let me know if you need additional information regarding the 2K-28 CTD Application for a Permit to Drill. Thank you, -Mike Mike A. Winfree Drilling Engineer 907.266.6820 Direct 907.242 0246 Cell 2 RECEIVED' k CTO 7 ZOli ConocoPhillips Alaska Alaska Oil & Cons.C0 P.O. BOX 100360 i'�PICn06 rmission ANCHORAGE,ALASKA 99510-0360 October 6, 2011 Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Permit to Drill applications for two coiled tubing drilling (CTD) laterals out of Kuparuk well 2K-28 (PTD#201-154) using the Nabors CDR2-AC coiled tubing drilling rig. The objective is to drill two injection A-sand laterals: 2K-28A, and 2K-28AL1. Work is scheduled to begin in November 2011. A sundry has been submitted and is pending approval for 2K-28 pre-rig well work. Attached to this application are the following documents that explain the proposed job operations: — Permit to Drill Application Forms for 2K-28A and 2K-28AL1 — Proposed & Current Wellbore Schematic — Summary of Operations — Directional Plans If you have any questions or require additional information regarding the 2K-28A and 2K-28AL1 Application for Permit to Drill, please call 907-265-6820. Sincerel Mike A. W free ConocoPhi ..s Alaska CTD Drilling ngineer Proposed 2K-28 CTD Laterals 3-1t Cameo DS nipple @497'RKB(2875"min ID) 3.12'9.341 L-80 EUEBrd Tubing to surface 5-112"15.5#L- 3-12'Camco KBO 2-9 gas lift mandrel @7014'RKB BO X0 to 3.12" @ 7129'RKB 3.12'Cameo DS landing nipple @7063 RI®(2.817 min ID) Baker 3-1/7 GBH-22 seal assembly 1§7108'RKB(3"ID) Liner top Baker 80.40 seal receptacle @ 7109 RKB(4"ID seal bore) 5-12'x3-12'crossover @ 7129'RKB C4-s and pert 7222-7228'MD KOP @7240 MD 2K-28 AL1 2K-28 S wp03) 10900'TD 'A-sand perfs 7268'-7384'MD 7300'-7320'MD IOP @7380 MD 2K-28 A 2K-28 WNwp06) i s 10200'TO :Kz= -it zs; 3-12"9.3#L-80 shoe @7536'RKB —rue Y ORIGINAL „, KUP 2K-28 ConocoPhillips 2 a�'w Well[Attributes Max Angle&MD TO • AIBSka,Inc. Wellbore API/UWI Field Name Well Status Incl(') MD(ftKB) Act Btm(ftKB) cancd'hPLps i, 501032038500 KUPARUK RIVER UNIT INJ 36.93 3,495.41 7,543.0 ” Comment- H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date ... wwcor•g:-2K-ze4rirNil7:a:x,aM SSSV:NIPPLE Last WO: 34.59 8/26/2001 Schemalio-Acdml _. Annotation . Depth(ftKB) End Date Annotation - Last Mod._End Date Last Tag:SM 7,330.0 422011 Rev Reason:TAG Imosbor 4/32011 Casing'Stnngs.n i.a. , .., s, , .., Casing Description String 0... String ID...Top(ftKB) Set Depth(L..Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 75/8 6.875 29.9 3,272.0 2,955.8 29.70 L-80 BTCM ,.. _ Casing Description String 0... String 1D...Top(ftKB) Set Depth(L..Set Depth(TVD)...String Wt...String...String Top Thrd HANDER,25 - PRODUCTION 512 4.950 25.0 7,536.3 6,470.0 15.50 L-80 LTCM 5.5"x3.5" Tubing Strings -` ' Tubing Description String 0... (String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...•String Wt...String...String Top Thrd TUBING 31/2 2.992 25.0 7,109.5 6,109.5 9.30 L-80 EUE-Srd Completion Details Top Depth (TVD) Top Incl Nome-. Top(ftKB) (ftKB) (°) Item Description Comment ID(in) 25.0 25.0 -0.15 HANGER FMC GEN V TUBING HANGER 3.500 497.3 497.0 4.20 NIPPLE CAMCO DS NIPPLE 2.875 r. 7,063.2 6,072.0 34.68 NIPPLE CAMCO DO NIPPLE 2.812 7,107.7 6,107.9 32.92 LOCATOR BAKER NO GO SUB 3.000 7,108.5 6,108.61 32.92 SEE !BAKER 80-40 GBH-22 Seal Assembly 3.000 CONDUCTOR,_ 30'220 s' Perforations&Slots Shot Top(TVD) Btm(TVD) Dens NIPPLE,497 y;: Top(ftKB) Btm(5KB) (ORB) (ORB) Zone Date (oh-. Type Comment 7,222.0 7,228.0 6,203.9 6,208.9 C-4,2K-28 4/19/2004 6.0 APERF 2.5"HSD,60 deg ph,random orient 7,268.0 7,284.0 6,242.6 6,258.0 A-5,2K-28 4/19/2004 6.0 APERF 2.5"HSD,60 deg ph,random orient 7,300.0 7,320.0 6,270.8 6,287.0 A-4,2K-28 12/16/2001 6.0 IPERF 2.5"HSD,60 deg phase Notes:General& Safety End Date Annotation 11/5/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SURFACE. . 343,272 GAS LIFT, 7,014 E NIPPLE,7.063 ■® LOCATOR, !'. ' 7,105 t +'.'k'.. i SBE.7,109 APERF, — 7,222-7,228 �a 7,2 APERF, i Mandrel Details•:', `Zi' '.:A'.:, a, ''d: kr-,.„*:,,,:,.. ),'",; ,:,',,,:::,:-,-:,----- 4V-, .. Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run gi, .--' Ste Top(RKB) (ftKB) I9 Make Model ON Sere Type Type lin) (pal) Run Date Com... 1 7,013.6 6,031.1 34.46 CAMCO KBG 2-9 1 GAS LIFT DMY BTM 0.000 0.012/72001 (PERF, 7,300-7,310 . PRODUCTION 2S7,Si6� ORIGINAL TD.7,593 KRU 2K-28A and 2K-28AL1 — Coiled Tubing Drilling Summary of Operations: Well 2K-28 is a Kuparuk A/C-sand injection well equipped with 3%2"tubing and 5-1/2"x 3-1/2"tapered production casing.Two proposed A-sand CTD laterals will increase reservoir exposure and support existing producer 2K-11 and the future CTD laterals 2K-22A and 2K-22AL1. The existing A-Sand perfs will be isolated below a CIBP and the C sand perfs will be squeezed with cement prior to drilling. After setting a CIBP to isolate the A sand perfs, a mechanical whipstock will be placed in the 3-1/2"tubing at the planned kick off point. With the whipstock in place,the C sand perfs will be isolated with a cement sqeeze. The 2K-28A sidetrack will exit the 3-1/2"casing at 7,240' MD and will target the A4 sand north of the existing well with a 2,960' lateral. The hole will be completed with a 2%" slotted liner from the TD of 10,200' MD with an anchored aluminum billet at 7,380' MD. The 2K-28AL1 lateral will kick off from the aluminum billet at 7,380' MD and will target the A4 sand south of the existing well with a 3,520' lateral. The hole will be completed with a 2%" slotted liner from the TD of 10,900' MD with the final liner top located just inside the 31/2"casing at 7,230' MD. • CTD Drill and Complete 2K-28 Laterals Pre-CTD Work(Sundry Pending AOGCC Approval) The pre-rig operations are only listed here for reference 1. Positive pressure and drawdown tests on master valve& swab valve 2. RU e-line. Set CIBP above A sand perfs,drift then run and set whipstock. Obtain static BHP on C-sand,RD e-line. 3. Rig up Little Red Services and perform injectivity test into C sand perfs 4. RU service coil and pump 15.8 ppg cement for hesitation squeeze into the C sand perfs. 5. After squeeze, clean out to top of whipstock at 7,240' MD 6. RDMO service coil 7. Prep site for Nabors CDR2-AC, including setting BPV Sundry Work Ends Here New PTD work begins here Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 2K-28A Sidetrack(A4 sand,north) a. Mill 2.80"window with high-side orientation at 7,240' MD. b. Drill 2.70"x 3"bi-center lateral to TD of 10,200' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 7,380' MD 3. 2K-28AL1 Lateral(A4 sand, south) a. Kick off of the aluminum billet at 7,380'MD b. Drill 2.70"x 3"bi-center lateral to TD of 10,900' MD c. Run 2%" slotted liner from TD up to 7,230' MD, 10' inside the 31/2"casing 4_ Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP 3. Put well on production ORIGiN, L KRU 2K-28A and 2K-28AL1 — Coiled Tubing Drilling Mud Program: • Will use chloride-based Biozan brine or used drilling mud(9.8 ppg)for milling operations, and chloride- based Flo-Pro mud(10.0 ppg)for drilling operations. We will have to kill the well with weighted brine in order to deploy 2%"slotted liner in the two laterals. Disposal: • This well will not be used for annular injection • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind&Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 2K-28A: 2%", 4.7#,L-80, ST-L slotted/solid liner from 7,380' MD to 10,190' MD • 2K-28A-L1: 2%",4.7#,L-80, ST-L slotted/solid liner from 7,230' MD to 10,890' MD Existing Casing/Liner Information String Size Weight Grade Burst Collapse Surface 7-5/8" 29.7 ppf L-80 6890 psi 4790 psi Production 5-1/2" 15.5 ppf L-80 7000 psi 4990 psi Production 3-1/2" 9.3 ppf L-80 4980 psi 4320 psi Logging • MWD directional,resistivity, and gamma ray will be run over the entire open hole section. • Reservoir Pressure • The most recent static BHP survey in well 2K-27 was taken August 18`h, 2011. The A/C-sand reservoir pressure was measured at 4,025 psi at 7,252' MD,6,240' TVD,which is 12.4 ppg EMW. Well Control: • Two well bore volumes(-190 bbl)of KWF will be available to the rig during drilling operations. The kill • weight fluid may or may not be stored onsite,but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is on file for operations with 2"coil tubing. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4500 psi. Maximum potential surface pressure in 2K-28 is 3,962 psi assuming a gas gradient to surface and maximum potential formation pressure. Maximum potential formation pressure is based on a pressure measurement of 4,025 psi at 6,240' TVD taken August 18th 2011, corresponding to 12.4 ppg EMW formation pressure. The BHP will be taken again by e-line after the A sand is isolated by a CIBP and the whipstock is set. In this configuaration,the pressure will be C sand only. • The annular preventer will be tested to 250 psi and 2500 psi. KRU 2K-28A and 2K-28AL1 — Coiled Tubing Drilling Directional: • See attached directional plans: 1. 2K-28Awp06 2. 2K-28A-Llwp03 • • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. . • 2K-28 CTD laterals A and A-L1 are 7,750' and 9,800' respectively to KPA boundary • Hazards • Shale stability is the most significant problem expected. It will be mitigated by directional planning to minimize exposure to the worst shales and by applying MPD pressure to maintain hole stability. • There has not been gas injection in the vicinity of 2K-28 location in 15+years, so it is unlikely that an • influx will yield significant quantities of gas. • Well 2K-28 is located in the middle of the well row on 2K pad and 24' south of the offset well 2K-12 and 65'North of well 2K-13 surface locations. The closest well with measured H2S is 2K-11 which is 50' to the North and measured 25 ppm on 1/10/2010. The maximum H2S level on the pad is 220 ppm from well 2K-08 (11/05/05)The original 2K-08 well was P&A'd . All H2S monitoring equipment will be ✓" operational. Managed Pressure Drilling Managed pressure drilling(MPD)techniques will be employed to provide constant bottom hole pressure by • using 10 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be used to reduce pressure fluctuations to help with hole stability. A hydraulic choke for regulating surface pressure is installed between the BOPE choke manifold and the mud pits, and is independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the 2%"BHA will be accomplished utilizing the 2%"pipe rams and slip rams. The annular preventer will act as a secondary isolation during deployment and not as a stripper. Well 2K-28 will have to be killed prior to deploying slotted liner. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Expected reservoir pressure is 4,025 psi at 6,240' TVD, or 12.4 ppg EMW. • Expected annular friction losses while circulating: 1,090 psi(assuming annular friction of 100 psi/1000 ft due to the 3%"tubing) • Planned mud density of 10.0 ppg equates to 3,245 psi hydrostatic bottom hole pressure at 6,240' TVD. • While circulating 10 ppg mud, bottom hole circulating pressure is estimated to be 4,335 psi or 13.3 ppg • EMW without holding any additional surface pressure. This is sufficient to overbalance expected formation pressure in 2K-28. If increased formation pressure is encountered,mud weight or choke pressure will be increased to maintain overbalance. Additional choke pressure or increased mud weight may also be employed for improved borehole stability,but not necessarily for well control. • When circulation is stopped,-1,090 psi of surface pressure would have to be applied to maintain the same borehole pressure as during drilling operations. ORIGINAL I 1 KRU 2K-28A and 2K-28AL1 — Coiled Tubing Drilling Quarter-Mile Injection Review The following wells lay within one-quarter mile of the proposed 2K-28 CTD laterals in zone. 2K-14(Producer) Currently online producing 115 bopd with gas lift. � ' ► I Cl N L ConocoPhiflips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2K Pad 2K-28 2K-28AL1 Plan: 2K-28AL1_wp03 Standard Planning Report 04 October, 2011 EMI BAKER HUGHES ORIGINAL I.= ConocoPhillips or its affiliates FG- ConocoPhillips Planning Report BAKR E HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-28 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-28@ @ 148.65ft(2K-28@) Site: Kuparuk 2K Pad North Reference: True Well: 2K-28 Survey Calculation Method: Minimum Curvature Wellbore: 2K-28AL1 Design: 2K-28AL1_wp03 Project Kuparuk River Unit 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 Kuparuk 2K Pad Site Position: Northing: 5,938,600.18ft Latitude: 70°14'36.519 N From: Map Easting: 498,310.17ft Longitude: 150°0'49.133 W 'Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -0.01 ° Well 2K-28 Well Position +N/-S 0.00 ft Northing: 5,938,300.61 ft Latitude: 70°14'33.573 N +El-W 0.00 ft Easting: 498,310.32 ft Longitude: 150°0'49.127 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore 2K-28AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2011 11/11/2011 16.37 79.80 57,352 Design 2K-28AL1_wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,380.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) -118.50 0.00 0.00 190.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (0) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) Target 7,380.00 87.57 245.08 6,142.67 -2,342.48 -2,624.13 0.00 0.00 0.00 0.00 7,450.00 87.62 234.57 6,145.61 -2,377.59 -2,684.50 15.00 0.06 -15.01 270.00 7,540.00 90.00 221.28 6,147.49 -2,437.75 -2,751.13 15.00 2.65 -14.77 280.00 7,740.00 90.00 191.28 6,147.48 -2,615.04 -2,838.67 15.00 0.00 -15.00 270.00 8,040.00 90.00 179.28 6,147.47 -2,913.22 -2,866.22 4.00 0.00 -4.00 270.00 8,240.00 88.86 171.36 6,149.45 -3,112.38 -2,849.91 4.00 -0.57 -3.96 261.80 8,440.00 88.88 163.36 6,153.40 -3,307.34 -2,806.18 4.00 0.01 -4.00 270.00 9,140.00 89.01 191.36 6,166.60 -3,999.53 -2,774.26 4.00 0.02 4.00 90.00 9,340.00 90.00 199.30 6,168.33 -4,192.25 -2,827.10 4.00 0.50 3.97 82.90 9,540.00 90.63 207.28 6,167.22 -4,375.81 -2,906.10 4.00 0.31 3.99 85.50 10,090.00 90.58 185.27 6,161.34 -4,900.50 -3,059.29 4.00 -0.01 -4.00 270.00 10,290.00 90.02 177.29 6,160.29 -5,100.28 -3,063.77 4.00 -0.28 -3.99 266.00 10,900.00 80.73 199.96 6,210.06 -5,696.93 -3,153.46 4.00 -1.52 3.72 113.00 10/4/2011 1:32:23PM Page 2 COMPASS 2003.16 Build 69 ORtGN/ L 1•' ConocoPhillips or its affiliates Irr' ConocoPhilhps Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-28 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-28@ @ 148.65ft(2K-28@) Site: Kuparuk 2K Pad North Reference: True Well: 2K-28 Survey Calculation Method: Minimum Curvature Wellbore: 2K-28AL1 Design: 2 K-28AL 1_wp03 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +EI-W Section Rate Azimuth Northing Easting (ft) (0) (0) (ft) (ft) (ft) (ft) (°/100ft) (0) (ft) (ft) 7,380.00 87.57 245.08 6,142.67 -2,342.48 -2,624.13 2,762.57 0.00 0.00 5,935,958.95 495,685.93 TIP/KOP • 7,400.00 87.58 242.08 6,143.51 -2,351.37 -2,642.02 2,774.43 15.00 -90.00 5,935,950.06 495,668.04 7,450.00 87.62 234.57 6,145.61 -2,377.59 -2,684.50 2,807.63 15.00 -89.87 5,935,923.86 495,625.55 2 7,500.00 88.93 227.18 6,147.12 -2,409.10 -2,723.25 2,845.39 15.00 -80.00 5,935,892.36 495,586.81 7,540.00 90.00 221.28 6,147.49 -2,437.75 -2,751.13 2,878.45 15.00 -79.78 5,935,863.72 495,558.92 3 7,600.00 90.00 212.28 6,147.49 -2,485.76 -2,787.02 2,931.96 15.00 -90.00 5,935,815.72 495,523.02 7,700.00 90.00 197.28 6,147.49 -2,576.29 -2,828.81 3,028.37 15.00 -90.00 5,935,725.21 495,481.22 7,740.00 90.00 191.28 6,147.48 -2,615.04 -2,838.67 3,068.24 15.00 -90.00 5,935,686.47 495,471.35 4 7,800.00 90.00 188.88 6,147.48 -2,674.11 -2,849.17 3,128.24 4.00 -90.00 5,935,627.40 495,460.84 7,900.00 90.00 184.88 6,147.48 -2,773.37 -2,861.14 3,228.07 4.00 -90.00 5,935,528.16 495,448.84 8,000.00 90.00 180.88 6,147.47 -2,873.22 -2,866.16 3,327.28 4.00 -90.00 5,935,428.31 495,443.80 8,040.00 90.00 179.28 6,147.47 -2,913.22 -2,866.22 3,366.68 4.00 -90.00 5,935,388.32 495,443.74 Ribsteer 8,100.00 89.66 176.90 6,147.65 -2,973.19 -2,864.22 3,425.38 4.00 -98.20 5,935,328.36 495,445.72 8,200.00 89.09 172.94 6,148.74 -3,072.77 -2,855.37 3,521.91 4.00 -98.19 5,935,228.79 495,454.55 8,240.00 88.86 171.36 6,149.45 -3,112.38 -2,849.91 3,559.98 4.00 -98.15 5,935,189.17 495,460.00 6 8,300.00 88.87 168.96 6,150.64 -3,171.49 -2,839.66 3,616.40 4.00 -90.00 5,935,130.08 495,470.24 8,400.00 88.87 164.96 6,152.62 -3,268.87 -2,817.10 3,708.39 4.00 -89.95 5,935,032.70 495,492.77 8,440.00 88.88 163.36 6,153.40 -3,307.34 -2,806.18 3,744.38 4.00 -89.87 5,934,994.23 495,503.68 7 8,500.00 88.88 165.76 6,154.58 -3,365.16 -2,790.21 3,798.55 4.00 90.00 5,934,936.41 495,519.64 8,600.00 88.88 169.76 6,156.54 -3,462.85 -2,769.01 3,891.07 4.00 89.95 5,934,838.73 495,540.81 8,700.00 88.89 173.76 6,158.48 -3,561.77 -2,754.69 3,986.01 4.00 89.87 5,934,739.81 495,555.11 8,800.00 88.91 177.76 6,160.39 -3,661.46 -2,747.29 4,082.90 4.00 89.80 5,934,640.13 495,562.48 8,900.00 88.93 181.76 6,162.27 -3,761.42 -2,746.88 4,181.27 4.00 89.72 5,934,540.18 495,562.88 9,000.00 88.96 185.76 6,164.11 -3,861.17 -2,753.43 4,280.64 4.00 89.65 5,934,440.44 495,556.30 9,100.00 88.99 189.76 6,165.90 -3,960.22 -2,766.93 4,380.53 4.00 89.57 5,934,341.41 495,542.78 9,140.00 89.01 191.36 6,166.60 -3,999.53 -2,774.26 4,420.52 4.00 89.50 5,934,302.10 495,535.44 8 9,200.00 89.30 193.74 6,167.48 -4,058.09 -2,787.30 4,480.45 4.00 82.90 5,934,243.55 495,522.39 9,300.00 89.80 197.71 6,168.26 -4,154.32 -2,814.40 4,579.92 4.00 82.86 5,934,147.33 495,495.27 9,340.00 90.00 199.30 6,168.33 -4,192.25 -2,827.10 4,619.48 4.00 82.83 5,934,109.41 495,482.56 9 9,400.00 90.19 201.69 6,168.22 -4,248.45 -2,848.11 4,678.47 4.00 85.50 5,934,053.22 495,461.55 9,500.00 90.50 205.68 6,167.62 -4,340.01 -2,888.27 4,775.61 4.00 85.50 5,933,961.69 495,421.37 9,540.00 90.63 207.28 6,167.22 -4,375.81 -2,906.10 4,813.97 4.00 85.53 5,933,925.89 495,403.53 10 9,600.00 90.63 204.88 6,166.57 -4,429.69 -2,932.47 4,871.61 4.00 -90.00 5,933,872.02 495,377.15 9,700.00 90.62 200.88 6,165.47 -4,521.80 -2,971.34 4,969.07 4.00 -90.03 5,933,779.92 495,338.27 9,800.00 90.62 196.88 6,164.39 -4,616.40 -3,003.68 5,067.85 4.00 -90.07 5,933,685.34 495,305.91 9,900.00 90.61 192.87 6,163.32 -4,713.02 -3,029.34 5,167.46 4.00 -90.11 5,933,588.74 495,280.22 10,000.00 90.60 188.87 6,162.27 -4,811.20 -3,048.20 5,267.43 4.00 -90.16 5,933,490.57 495,261.34 10,090.00 90.58 185.27 6,161.34 -4,900.50 -3,059.29 5,357.29 4.00 -90.20 5,933,401.29 495,250.24 11 10,100.00 90.55 184.88 6,161.24 -4,910.46 -3,060.17 5,367.25 4.00 -94.00 5,933,391.33 495,249.35 10,200.00 90.27 180.89 6,160.52 -5,010.31 -3,065.19 5,466.46 4.00 -94.00 5,933,291.49 495,244.31 i 10,290.00 90.02 177.29 6,160.29 -5,100.28 -3,063.77 5,554.82 4.00 -94.03 5,933,201.52 495,245.72 10/4/2011 1:32:23PM Page 3 n ( h COMPASS 2003.16 Build 69 nr. 1 ► ^fir ! N (1 i v.,. ConocoPhillips or its affiliates Ira' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-28 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-28@ @ 148.65ft(2K-28@) Site: Kuparuk 2K Pad North Reference: True Well: 2K-28 Survey Calculation Method: Minimum Curvature Wellbore: 2K-28AL1 Design: 2K-28AL1_wp03 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (0) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 12 10,300.00 89.86 177.66 6,160.30 -5,110.27 -3,063.33 5,564.58 4.00 113.00 5,933,191.53 495,246.16 10,400.00 88.30 181.35 6,161.90 -5,210.24 -3,062.46 5,662.87 4.00 113.00 5,933,091.58 495,247.00 10,500.00 86.75 185.03 6,166.21 -5,309.97 -3,068.02 5,762.05 4.00 112.94 5,932,991.86 495,241.42 10,600.00 85.21 188.74 6,173.23 -5,408.98 -3,079.97 5,861.64 4.00 112.78 5,932,892.86 495,229.45 10,700.00 83.69 192.45 6,182.91 -5,506.80 -3,098.26 5,961.14 4.00 112.52 5,932,795.06 495,211.14 10,800.00 82.19 196.19 6,195.21 -5,602.94 -3,122.80 6,060.08 4.00 112.16 5,932,698.93 495,186.58 10,900.00 80.73 199.96 6,210.06 -5,696.93 -3,153.46 6,157.97 4.00 111.70 5,932,604.96 495,155.89 TD Targets Target Name -hit/miss target Dip Angle Dip Dir. ND +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 2K-28AL1_Fault 1 0.00 0.00 6,168.00 -4,086.64 -3,219.64 5,934,215.10 495,090.08 70° 13'53.374 N 150°2'22.677 W -plan misses target center by 404.96ft at 9378.53ft MD(6168.28 TVD,-4228.44 N,-2840.32 E) -Polygon Point 1 6,168.00 -4,086.64 -3,219.64 5,934,215.10 495,090.08 Point 2 6,168.00 -4,201.54 -2,830.57 5,934,100.12 495,479.09 Point 3 6,168.00 -4,466.36 -2,079.42 5,933,835.16 496,230.11 I Point 4 6,168.00 -4,201.54 -2,830.57 5,934,100.12 495,479.09 2K-28AL1_T4 0.00 0.00 6,162.00 -5,209.70 -3,063.38 5,933,092.12 495,246.08 70° 13'42.329 N 150°2'18.123 W -plan hits target center -Point 2K-28AL1_Polygon 0.00 0.00 0.00 -2,119.44 -2,956.03 5,936,182.04 495,354.11 70° 14'12.722 N 150°2'15.040 W -plan misses target center by 6155.67ft at 7380.00ft MD(6142.67 TVD,-2342.48 N,-2624.13 E) -Polygon Point 1 0.00 -2,119.44 -2,956.03 5,936,182.04 495,354.11 Point 2 0.00 -4,168.67 -3,054.48 5,934,133.04 495,255.21 Point 3 0.00 -5,870.96 -3,500.05 5,932,431.02 494,809.30 Point 4 0.00 -6,052.86 -3,036.96 5,932,249.04 495,272.31 Point 5 0.00 -4,301.56 -2,608.40 5,934,000.06 495,701.22 Point 6 0.00 -2,235.30 -2,409.94 5,936,066.07 495,900.12 Point 7 0.00 -2,119.44 -2,956.03 5,936,182.04 495,354.11 2K-28AL1T1 0.00 0.00 6,147.00 -2,408.41 -2,723.94 5,935,893.05 495,586.11 70°14'9.881 N 150°2'8.292 W -plan hits target center -Point 2K-28AL1_T2 0.00 0.00 6,149.00 -3,072.49 -2,855.81 5,935,229.07 495,454.10 70°14'3.349 N 150°2'12.117 W -plan hits target center -Point 2K-28AL1_T5 0.00 0.00 6,210.00 -5,696.75 -3,154.29 5,932,605.14 495,155.07 70°13'37.539 N 150°2'20.759 W -plan hits target center -Point 2K-28AL1_T3 0.00 0.00 6,168.00 -4,201.57 -2,830.57 5,934,100.09 495,479.09 70°13'52.245 N 150°2'11.371 W -plan hits target center -Point 10/4/2011 1:32:23PMPage 4 COMPASS 2003.16 Build 69 OR ! GINAL ti•' ConocoPhillips or its affiliates tri' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-28 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-28@ @ 148.65ft(2K-28@) Site: Kuparuk 2K Pad North Reference: True Well: 2K-28 Survey Calculation Method: Minimum Curvature Wellbore: 2K-28AL1 Design: 2 K-28AL 1_wp03 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 3,282.03 2,815.20 9 5/8" 9-5/8 12-1/4 7,240.00 6,070.39 7" 7 8-1/2 10,900.00 6,210.06 2-3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 7,380.00 6,142.67 -2,342.48 -2,624.13 TIP/KOP 7,450.00 6,145.61 -2,377.59 -2,684.50 2 7,540.00 6,147.49 -2,437.75 -2,751.13 3 7,740.00 6,147.48 -2,615.04 -2,838.67 4 8,040.00 6,147.47 -2,913.22 -2,866.22 Ribsteer 8,240.00 6,149.45 -3,112.38 -2,849.91 6 8,440.00 6,153.40 -3,307.34 -2,806.18 7 9,140.00 6,166.60 -3,999.53 -2,774.26 8 9,340.00 6,168.33 -4,192.25 -2,827.10 9 9,540.00 6,167.22 -4,375.81 -2,906.10 10 10,090.00 6,161.34 -4,900.50 -3,059.29 11 10,290.00 6,160.29 -5,100.28 -3,063.77 12 10,900.00 6,210.06 -5,696.93 -3,153.46 TD • 10/4/2011 1:32:23PM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2K Pad 2K-28 2K-28AL1 2K-28AL1_wp03 Travelling Cylinder Report 06 October, 2011 r'r�■ BAKER HUGHES 1.., ConocoPhillips or its affiliates pr- ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-28 Project: Kuparuk River Unit ND Reference: 2K-28@ @ 148.65ft(2K-28@) Reference Site: Kuparuk 2K Pad MD Reference: 2K-28@ @ 148.65ft(2K-28@) Site Error: 0.00ft North Reference: True Reference Well: 2K-28 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-28AL1 Database: EDM Alaska Prod v16 Reference Design: 2K-28AL1_wp03 Offset ND Reference: Offset Datum Reference 2K-28AL1_wp03 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 7,380.00 to 10,900.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,286.99ft Error Surface: Elliptical Conic Survey Tool Program Date 10/4/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description 130.00 582.10 2K-28 Gyro(2K-28) CB-GYRO-SS Camera based gyro single shot 665.41 7,187.69 2K-28 MWD(2K-28) MWD MWD-Standard 7,187.69 7,380.00 2K-28A_wp06(2K-28A) MWD MWD-Standard 7,380.00 10,900.00 2K-28AL1_wp03(2K-28AL1) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 3,282.03 2,963.85 9 5/8" 9-5/8 12-1/4 7,240.00 6,219.04 7" 7 8-1/2 10,900.00 6,358.71 2-3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 2K Pad 2K-04-2K-04-2K-04 Out of range 2K-08-2K-08-2K-08 Out of range 2K-08-2K-08A-2K-08A Out of range 2K-08-2K-08APB1 -2K-08APB1 Out of range 2K-08-2K-08APB2-2K-08APB2 Out of range 2K-08-2K-08APB3-2K-08APB3 Out of range 2K-13-2K-13-2K-13 Out of range 2K-13-2K-13A-2K-13A Out of range 2K-13-2K-13AL1 -2K-13AL1 Out of range 2K-13-2K-13AL2-2K-13AL2 Out of range 2K-14-2K-14-2K-14 Out of range 2K-16-2K-16-2K-16 Out of range 2K-17-2K-17-2K-17 Out of range 2K-18-2K-18-2K-18 Out of range 2K-19-2K-19-2K-19 Out of range 2K-19-2K-19A-2K-19A Out of range 2K-19-2K-19AL1 -2K-19AL1 Out of range 2K-20-2K-20-2K-20 Out of range 2K-21 -2K-21 -2K-21 10,893.19 9,100.00 965.58 358.18 711.11 Pass-Major Risk 2K-21 -2K-21A-2K-21A 10,893.19 9,100.00 965.58 358.18 711.11 Pass-Major Risk 2K-27-2K-27-2K-27 Out of range 2K-28-2K-28-2K-28 7,381.24 7,450.00 106.41 119.19 73.84 Pass-Major Risk 2K-28-2K-28A-2K-28A_wp06 7,399.88 7,400.00 1.68 1.52 0.29 Pass-Major Risk CC-Min centre to center distance or coverggnt point,SF,-min separation factor,ES-min ellipse separation 10/6/2011 8:22:25AMPage 2 of 7 COMPASS 2003.16 Build 69 t,,.. i N i • ConocoPhillips or its affiliates //.fit ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-28 Project: Kuparuk River Unit ND Reference: 2K-28@ @ 148.65ft(2K-28@) Reference Site: Kuparuk 2K Pad MD Reference: 2K-28@ @ 148.65ft(2K-28@) Site Error: 0.00ft North Reference: True Reference Well: 2K-28 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-28AL1 Database: EDM Alaska Prod v16 Reference Design: 2K-28AL1_wp03 Offset ND Reference: Offset Datum Offset Design Kuparuk 2K Pad- 2K 21 2K 21 2K 21 Offset Site Error: 0.00 ft Survey Program: 200-GYD-CT-CMS Rule Assigned:Major Risk Offset Well Error: 0.00ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +Nf-S +E/-w Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (ft) (ft) (ft) (ft) 10,032.63 6,310.58 7,975.00 5,051 40 69.30 36.43 -164.53 -4,807.45 -3,225.05 0.22 1,276.71 297.65 1,155.09 Pass-Major Risk 10,049.08 6,310.41 8,000.00 5,064.24 69.48 36.58 -164.65 -4,824.68 -3,237.83 0.22 1,265.30 297.30 1,142.15 Pass-Major Risk 10,065.34 6,310.24 8,025.00 5,077.05 69.65 36.73 -164.73 -4,841.95 -3,250.58 0.22 1,254.07 296.93 1,129.32 Pass-Major Risk 10,081.42 6,310.08 8,050.00 5,089.86 69.83 36.88 -164.80 -4,859.27 -3,263.26 0.22 1,242.99 296.53 1,116.56 Pass-Major Risk 10,097.01 6,309.92 8,075.00 5,102.67 70.00 37.03 -164.82 -4,876.64 -3,275.87 0.22 1,232.06 296.13 1,103.90 Pass-Major Risk 10,112.05 6,309.78 8,100.00 5,115.49 70.15 37.18 -164.81 -4,894.07 -3,288.41 0.22 1,221.31 295.73 1,091.38 Pass-Major Risk 10,126.94 6,309.65 8,125.00 5,128.30 70.31 37.33 -164.77 -4,911.51 -3,300.91 0.22 1,210.74 295.32 1,078.96 Pass-Major Risk 10,141.65 6,309.53 8,150.00 5,141.14 70.47 37.48 -164.71 -4,928.96 -3,313.40 0.22 1,200.35 294.89 1,066.67 Pass-Major Risk 10,156.18 6,309.42 8,175.00 5,153.98 70.62 37.63 -164.62 -4,946.40 -3,325.88 0.22 1,190.17 294.44 1,054.50 Pass-Major Risk 10,170.54 6,309.33 8,200.00 5,166.84 70.77 37.79 -164.50 -4,963.84 -3,338.35 0.22 1,180.19 293.97 1,042.47 Pass-Major Risk 10,184.71 6,309.25 8,225.00 5,179.75 70.93 37.94 -164.35 -4,981.28 -3,350.78 0.22 1,170.39 293.49 1,030.56 Pass-Major Risk 10,200.00 6,309.17 8,250.00 5,192.73 71.09 38.09 -164.23 -4,998.71 -3,363.13 0.22 1,160.73 292.91 1,018.74 Pass-Major Risk 10,212.53 6,309.11 8,275.00 5,205.80 71.22 38.24 -163.99 -5,016.13 -3,375.41 0.22 1,151.22 292.49 1,007.00 Pass-Major Risk 10,226.17 6,309.06 8,300.00 5,218.96 71.36 38.39 -163.77 -5,033.54 -3,387.61 0.22 1,141.87 291.97 995.37 Pass-Major Risk 10,239.64 6,309.02 8,325.00 5,232.16 71.50 38.54 -163.52 -5,050.94 -3,399.76 0.22 1,132.72 291.45 983.88 Pass-Major Risk 10,252.93 6,308.98 8,350.00 5,245.41 71.64 38.69 -163.25 -5,068.33 -3,411.90 0.22 1,123.81 290.91 972.58 Pass-Major Risk 10,266.05 6,308.96 8,375.00 5,258.68 71.77 38.84 -162.95 -5,085.71 -3,424.01 0.22 1,115.14 290.36 961.47 Pass-Major Risk 10,279.00 6,308.94 8,400.00 5,271.98 71.91 38.99 -162.62 -5,103.08 -3,436.10 0.22 1,106.74 289.80 950.58 Pass-Major Risk 10,292.29 6,308.94 8,425.00 5,285.32 72.04 39.14 -162.11 -5,120.45 -3,448.17 0.22 1,098.60 289.64 939.85 Pass-Major Risk 10,308.74 6,308.98 8,450.00 5,298.70 72.20 39.29 -160.64 -5,137.82 -3,460.19 0.22 1,090.70 292.04 928.99 Pass-Major Risk 10,325.58 6,309.10 8,475.00 5,312.10 72.37 39.44 -159.15 -5,155.19 -3,472.16 0.22 1,083.00 294.44 918.27 Pass-Major Risk 10,342.82 6,309.30 8,500.00 5,325.55 72.53 39.59 -157.65 -5,172.57 -3,484.09 0.22 1,075.51 296.88 907.69 Pass-Major Risk 10,360.46 6,309.59 8,525.00 5,339.00 72.70 39.74 -156.14 -5,189.95 -3,495.99 0.22 1,068.24 299.34 897.26 Pass-Major Risk 10,378.51 6,309.97 8,550.00 5,352.47 72.88 39.89 -154.62 -5,207.34 -3,507.88 0.22 1,061.20 301.83 886.99 Pass-Major Risk 10,396.99 6,310.46 8,575.00 5,365.93 73.06 40.04 -153.09 -5,224.74 -3,519.75 0.22 1,054.40 304.34 876.90 Pass-Major Risk 10,415.89 6,311.05 8,600.00 5,379.40 73.25 40.19 -151.55 -5,242.14 -3,531.62 0.22 1,047.81 306.87 866.96 Pass-Major Risk 10,435.21 6,311.76 8,625.00 5,392.83 73.44 40.34 -149.99 -5,259.54 -3,543.54 0.22 1,041.51 309.41 857.24 Pass-Major Risk 10,454.95 6,312.58 8,650.00 5,406.19 73.64 40.49 -148.43 -5,276.90 -3,555.58 0.22 1,035.55 311.97 847.79 Pass-Major Risk 10,475.12 6,313.54 8,675.00 5,419.47 73.85 40.64 -146.86 -5,294.24 -3,567.75 0.22 1,029.93 314.55 838.61 Pass-Major Risk 10,495.71 6,314.62 8,700.00 5,432.67 74.06 40.79 -145.27 -5,311.55 -3,580.03 0.22 1,024.63 317.13 829.71 Pass-Major Risk 10,516.76 6,315.85 8,725.00 5,445.82 74.27 40.94 -143.68 -5,328.83 -3,592.42 0.22 1,019.64 319.72 821.04 Pass-Major Risk 10,538.25 6,317.23 8,750.00 5,458.93 74.50 41.09 -142.08 -5,346.09 -3,604.89 0.22 1,014.91 322.32 812.60 Pass-Major Risk 10,560.20 6,318.77 8,775.00 5,472.00 74.73 41.24 -140.47 5,363.32 -3,617.43 0.22 1,010.44 324.92 804.37 Pass-Major Risk 10,582.62 6,320.47 8,800.00 5,485.03 74.97 41.40 -138.86 -5,380.52 -3,630.06 0.22 1,006.21 327.52 796.35 Pass-Major Risk 10,605.55 6,322.35 8,825.00 5,498.02 75.21 41.55 -137.25 -5,397.72 -3,642.72 0.22 1,002.19 330.12 788.51 Pass-Major Risk 10,629.02 6,324.42 8,850.00 5,510.97 75.46 41.70 -135.63 -5,414.97 -3,655.37 0.22 998.34 332.71 780.85 Pass-Major Risk 10,653.04 6,326.69 8,875.00 5,523.87 75.72 41.85 -134.02 -5,432.25 -3,668.00 0.22 994.65 335.30 773.34 Pass-Major Risk 10,677.60 6,329.16 8,900.00 5,536.73 75.99 42.01 -132.41 -5,449.58 -3,680.62 0.22 991.10 337.88 765.97 Pass-Major Risk 10,702.71 6,331.86 8,925.00 5,549.57 76.26 42.16 -130.81 -5,466.94 -3,693.23 0.22 987.67 340.45 758.74 Pass-Major Risk 10,728.35 6,334.78 8,950.00 5,562.37 76.55 42.31 -129.21 -5,484.33 -3,705.82 0.22 984.32 342.98 751.61 Pass-Major Risk 10,754.52 6,337.94 8,975.00 5,575.16 76.84 42.47 -127.61 -5,501.75 -3,718.40 0.22 981.05 345.49 744.59 Pass-Major Risk 10,781.22 6,341.35 9,000.00 5,587.92 77.13 42.62 -126.02 -5,519.19 -3,730.96 0.22 977.83 347.96 737.66 Pass-Major Risk 10,808.44 6,345.01 9,025.00 5,600.65 77.44 42.78 -124.45 -5,536.66 -3,743.52 0.22 974.67 350.39 730.84 Pass-Major Risk 10,836.19 6,348.94 9,050.00 5,613.31 77.75 42.93 -122.88 -5,554.16 -3,756.11 0.22 971.59 353.02 724.15 Pass-Major Risk 10,864.44 6,353.14 9,075.00 5,625.91 78.07 43.09 -121.32 -5,571.68 -3,768.73 0.22 968.56 355.63 717.57 Pass-Major Risk 10,893.19 6,357.62 9,100.00 5,638.45 78.40 43.24 -119.77 -5,589.23 -3,781.37 0.22 965.58 358.18 711.11 Pass-Major Risk,CC,ES, CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/6/2011 8.22.25AM $of�7� COMPASS 2003.16 Build 69 r":21 ConocoPhillips or its affiliates II%- ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-28 Project: Kuparuk River Unit TVD Reference: 2K-28@ @ 148.65ft(2K-28@) Reference Site: Kuparuk 2K Pad MD Reference: 2K-28@ @ 148.65ft(2K-28@) Site Error: 0.00ft North Reference: True Reference Well: 2K-28 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-28AL1 Database: EDM Alaska Prod v16 Reference Design: 2K-28AL1_wp03 Offset TVD Reference: Offset Datum Offset Design Kuparuk 2K Pad- 2K-21 -2K-21A-2K-21A Offset Site Error: 0.00 ft Survey Program: 200-GYD-CT-CMS,10420-GYD-CT-CMS Rule Assigned:Major Risk Offset Well Error: 0.00ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E1-W Hole Size Centre Distance Deviation Ift) (ft) (ft) Ift) (ft) Ift) r) (ft) (ft) (ft) Iff) Ift) Ift) 10,032.63 6,310.58 7,975.00 5,051 40 69.30 36.43 -164.53 -4,807.45 -3,225.05 0.22 1,276.71 297.65 1,155.09 Pass-Major Risk 10,049.08 6,310.41 8,000.00 5,064.24 69.48 36.58 -164.65 -4,824.68 -3,237.83 0.22 1,265.30 297.30 1,142.15 Pass-Major Risk 10,065.34 6,310.24 8,025.00 5,077.05 69.65 36.73 -164.73 -4,841.95 -3,250.58 0.22 1,254.07 296.93 1,129.32 Pass-Major Risk 10,081.42 6,310.08 8,050.00 5,089.86 69.83 36.88 -164.80 -4,859.27 -3,263.26 0.22 1,242.99 296.53 1,116.56 Pass-Major Risk 10,097.01 6,309.92 8,075.00 5,102.67 70.00 37.03 -164.82 -4,876.64 -3,275.87 0.22 1,232.06 296.13 1,103.90 Pass-Major Risk 10,112.05 6,309.78 8,100.00 5,115.49 70.15 37.18 -164.81 -4,894.07 -3,288.41 0.22 1,221.31 295.73 1,091.38 Pass-Major Risk 10,126.94 6,309.65 8,125.00 5,128.30 70.31 37.33 -164.77 -4,911.51 -3,300.91 0.22 1,210.74 295.32 1,078.96 Pass-Major Risk 10,141.65 6,309.53 8,150.00 5,141.14 70.47 37.48 -164.71 -4,928.96 -3,313.40 0.22 1,200.35 294.89 1,066.67 Pass-Major Risk 10,156.18 6,309.42 8,175.00 5,153.98 70.62 37.63 -164.62 -4,946.40 -3,325.88 0.22 1,190.17 294.44 1,054.50 Pass-Major Risk 10,170.54 6,309.33 8,200.00 5,166.84 70.77 37.79 -164.50 -4,963.84 -3,338.35 0.22 1,180.19 293.97 1,042.47 Pass-Major Risk 10,184.71 6,309.25 8,225.00 5,179.75 70.93 37.94 -164.35 -4,981.28 -3,350.78 0.22 1,170.39 293.49 1,030.56 Pass-Major Risk 10,200.00 6,309.17 8,250.00 5,192.73 71.09 38.09 -164.23 -4,998.71 -3,363.13 0.22 1,160.73 292.91 1,018.74 Pass-Major Risk 10,212.53 6,309.11 8,275.00 5,205.80 71.22 38.24 -163.99 -5,016.13 -3,375.41 0.22 1,151.22 292.49 1,007.00 Pass-Major Risk 10,226.17 6,309.06 8,300.00 5,218.96 71.36 38.39 -163.77 -5,033.54 -3,387.61 0.22 1,141.87 291.97 995.37 Pass-Major Risk 10,239.64 6,309.02 8,325.00 5,232.16 71.50 38.54 -163.52 -5,050.94 -3,399.76 0.22 1,132.72 291.45 983.88 Pass-Major Risk 10,252.93 6,308.98 8,350.00 5,245.41 71.64 38.69 -163.25 -5,068.33 -3,411.90 0.22 1,123.81 290.91 972.58 Pass-Major Risk 10,266.05 6,308.96 8,375.00 5,258.68 71.77 38.84 -162.95 -5,085.71 -3,424.01 0.22 1,115.14 290.36 961.47 Pass-Major Risk 10,279.00 6,308.94 8,400.00 5,271.98 71.91 38.99 -162.62 -5,103.08 -3,436.10 0.22 1,106.74 289.80 950.58 Pass-Major Risk 10,292.29 6,308.94 8,425.00 5,285.32 72.04 39.14 -162.11 -5,120.45 -3,448.17 0.22 1,098.60 289.64 939.85 Pass-Major Risk 10,308.74 6,308.98 8,450.00 5,298.70 72.20 39.29 -160.64 -5,137.82 -3,460.19 0.22 1,090.70 292.04 928.99 Pass-Major Risk 10,325.58 6,309.10 8,475.00 5,312.10 72.37 39.44 -159.15 -5,155.19 -3,472.16 0.22 1,083.00 294.44 918.27 Pass-Major Risk 10,342.82 6,309.30 8,500.00 5,325.55 72.53 39.59 -157.65 -5,172.57 -3,484.09 0.22 1,075.51 296.88 907.69 Pass-Major Risk 10,360.46 6,309.59 8,525.00 5,339.00 72.70 39.74 -156.14 -5,189.95 -3,495.99 0.22 1,068.24 299.34 897.26 Pass-Major Risk 10,378.51 6,309.97 8,550.00 5,352.47 72.88 39.89 -154.62 -5,207.34 -3,507.88 0.22 1,061.20 301.83 886.99 Pass-Major Risk 10,396.99 6,310.46 8,575.00 5,365.93 73.06 40.04 -153.09 -5,224.74 -3,519.75 0.22 1,054.40 304.34 876.90 Pass-Major Risk 10,415.89 6,311.05 8,600.00 5,379.40 73.25 40.19 -151.55 -5,242.14 -3,531.62 0.22 1,047.81 306.87 866.96 Pass-Major Risk 10,435.21 6,311.76 8,625.00 5,392.83 73.44 40.34 -149.99 -5,259.54 -3,543.54 0.22 1,041.51 309.41 857.24 Pass-Major Risk 10,454.95 6,312.58 8,650.00 5,406.19 73.64 40.49 -148.43 -5,276.90 -3,555.58 0.22 1,035.55 311.97 847.79 Pass-Major Risk 10,475.12 6,313.54 8,675.00 5,419.47 73.85 40.64 -146.86 -5,294.24 -3,567.75 0.22 1,029.93 314.55 838.61 Pass-Major Risk 10,495.71 6,314.62 8,700.00 5,432.67 74.06 40.79 -145.27 -5,311.55 -3,580.03 0.22 1,024.63 317.13 829.71 Pass-Major Risk 10,516.76 6,315.85 8,725.00 5,445.82 74.27 40.94 -143.68 -5,328.83 -3,592.42 0.22 1,019.64 319.72 821.04 Pass-Major Risk 10,538.25 6,317.23 8,750.00 5,458.93 74.50 41.09 -142.08 -5,346.09 -3,604.89 0.22 1,014.91 322.32 812.60 Pass-Major Risk 10,560.20 6,318.77 8,775.00 5,472.00 74.73 41.24 -140.47 -5,363.32 -3,617.43 0.22 1,010.44 324.92 804.37 Pass-Major Risk 10,582.62 6,320.47 8,800.00 5,485.03 74.97 41.40 -138.86 -5,380.52 -3,630.06 0.22 1,006.21 327.52 796.35 Pass-Major Risk 10,605.55 6,322.35 8,825.00 5,498.02 75.21 41.55 -137.25 -5,397.72 -3,642.72 0.22 1,002.19 330.12 788.51 Pass-Major Risk 10,629.02 6,324.42 8,850.00 5,510.97 75.46 41.70 -135.63 -5,414.97 -3,655.37 0.22 998.34 332.71 780.85 Pass-Major Risk 10,653.04 6,326.69 8,875.00 5,523.87 75.72 41.85 -134.02 -5,432.25 -3,668.00 0.22 994.65 335.30 773.34 Pass-Major Risk 10,677.60 6,329.16 8,900.00 5,536.73 75.99 42.01 -132.41 -5,449.58 -3,680.62 0.22 991.10 337.88 765.97 Pass-Major Risk 10,702.71 6,331.86 8,925.00 5,549.57 76.26 42.16 -130.81 -5,466.94 -3,693.23 0.22 987.67 340.45 758.74 Pass-Major Risk 10,728.35 6,334.78 8,950.00 5,562.37 76.55 42.31 -129.21 -5,484.33 -3,705.82 0.22 984.32 342.98 751.61 Pass-Major Risk 10,754.52 6,337.94 8,975.00 5,575.16 76.84 42.47 -127.61 -5,501.75 -3,718.40 0.22 981.05 345.49 744.59 Pass-Major Risk 10,781.22 6,341.35 9,000.00 5,587.92 77.13 42.62 -126.02 -5,519.19 -3,730.96 0.22 977.83 347.96 737.66 Pass-Major Risk 10,808.44 6,345.01 9,025.00 5,600.65 77.44 42.78 -124.45 -5,536.66 -3,743.52 0.22 974.67 350.39 730.84 Pass-Major Risk 10,836.19 6,348.94 9,050.00 5,613.31 77.75 42.93 -122.88 -5,554.16 -3,756.11 0.22 971.59 353.02 724.15 Pass-Major Risk 10,864.44 6,353.14 9,075.00 5,625.91 78.07 43.09 -121.32 5,571.68 -3,768.73 0.22 968.56 355.63 717.57 Pass-Major Risk 10,893.19 6,357.62 9,100.00 5,638.45 78.40 43.24 -119.77 -5,589.23 -3,781.37 0.22 965.58 358.18 711.11 Pass-Major Risk,CC,ES,E CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/6/2011 8:22:25AM Page 4 of 7 A COMPASS 2003.16 Build 69 y ConocoPhillips or its affiliates II it ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-28 Project: Kuparuk River Unit TVD Reference: 2K-28@ @ 148.65ft(2K-28@) Reference Site: Kuparuk 2K Pad MD Reference: 2K-28@ @ 148.65ft(2K-28@) Site Error: 0.00ft North Reference: True Reference Well: 2K-28 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-28AL1 Database: EDM Alaska Prod v16 Reference Design: 2K-28AL1_wp03 Offset TVD Reference: Offset Datum Offset Design Kuparuk 2K Pad- 2K-28-2K-28-2K-28 Offset Site Error: 0.00 ft Survey Program: 130-CB-GYRO-SS,665-MWD Rule Assigned:Major Risk Offset Well Error: 0.00 ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (ft) (ft) (ft) (ft) 7,381.24 6,291.37 7,450.00 6,395.86 45.12 1.79 75.53 -2,358.93 -2,612.91 0.22 106.41 119.19 73.84 Pass-Major Risk,CC,ES,5. 7,395.36 6,291.97 7,475.00 6,417.27 45.26 1.95 73.29 -2,367.51 -2,622.54 0.22 127.56 121.32 94.72 Pass-Major Risk 7,409.64 6,292.57 7,500.00 6,438.73 45.40 2.12 70.89 -2,376.04 -2,632.11 0.22 148.67 123.31 115.77 Pass-Major Risk 7,424.14 6,293.18 7,525.00 6,460.20 45.54 2.28 68.37 -2,384.57 -2,641.68 0.22 169.70 125.17 136.86 Pass-Major Risk 7,434.70 6,293.63 7,543.00 6,475.65 45.65 2.40 66.50 -2,390.71 -2,648.57 0.22 184.79 126.41 152.07 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/6/2011 8:22:25AM Page 5of 7 COMPASS 2003.16 Build 69 .-. ConocoPhillips or its affiliates Irgi' ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-28 Project: Kuparuk River Unit ND Reference: 2K-28@ @ 148.65ft(2K-28@) Reference Site: Kuparuk 2K Pad MD Reference: 2K-28@ @ 148.65ft(2K-28@) Site Error: 0.00ft North Reference: True Reference Well: 2K-28 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-28AL1 Database: EDM Alaska Prod v16 Reference Design: 2K-28AL1_wp03 Offset ND Reference: Offset Datum Offset Design Kuparuk 2K Pad- 2K-28-2K-28A-2K-28A_wp06 Offset Site Error: 0.00ft Survey Program: 130-CB-GYRO-SS,665-MWD,7188-MWD Rule Assigned:Major Risk Offset Well Error: 0.00ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +EI-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) lft) (ft) (°) (ft) (ft) (ft) (ft) (ft) (ft) 7,380.00 6,291.32 7,875.00 6,284.91 0.00 1.99 -25.92 -1,994.80 -2,793.73 0.22 386.90 3.44 383.49 Pass-Major Risk 7,390.67 6,291.77 7,850.00 6,285.08 0.11 1.95 -27.57 -2,019.50 -2,797.56 0.22 366.35 4.10 362.27 Pass-Major Risk 7,399.88 6,292.16 7,400.00 6,291.38 0.21 0.21 -55.58 -2,350.01 -2,642.64 0.22 1.68 1.52 0.29 Pass-Major Risk,CC,ES,S 7,400.00 6,292.16 7,800.00 6,285.27 0.21 1.94 -29.22 -2,069.10 -2,803.83 0.22 325.43 5.01 320.43 Pass-Major Risk 7,400.00 6,292.16 7,825.00 6,285.18 0.21 1.94 -29.06 -2,044.27 -2,800.96 0.22 345.87 4.68 341.19 Pass-Major Risk 7,413.46 6,292.73 7,775.00 6,285.36 0.34 1.94 -31.33 -2,093.99 -2,806.16 0.22 304.81 5.54 299.28 Pass-Major Risk 7,423.34 6,293.15 7,425.00 6,291.01 0.45 0.48 -44.88 -2,355.33 -2,667.02 0.22 9.20 3.04 6.24 Pass-Major Risk 7,425.00 6,293.22 7,725.00 6,285.54 0.46 1.96 -33.42 -2,143.90 -2,809.19 0.22 263.78 6.17 257.62 Pass-Major Risk 7,425.00 6,293.22 7,750.00 6,285.45 0.46 1.94 -33.19 -2,118.93 -2,807.94 0.22 284.30 6.00 278.30 Pass-Major Risk 7,438.28 6,293.78 7,700.00 6,285.63 0.60 1.97 -35.59 -2,168.89 -2,809.88 0.22 243.16 6.60 236.57 Pass-Major Risk 7,443.66 6,294.00 7,450.00 6,290.32 0.65 0.74 -43.93 -2,355.80 -2,691.97 0.22 22.44 4.43 18.07 Pass-Major Risk 7,450.00 6,294.26 7,675.00 6,285.72 0.72 1.97 -37.58 -2,193.89 -2,810.04 0.22 222.66 6.92 215.75 Pass-Major Risk 7,456.33 6,294.52 7,650.00 6,285.81 0.78 1.97 -38.84 -2,218.88 -2,809.64 022 202.14 7.13 195.02 Pass-Major Risk 7,459.71 6,294.65 7,475.00 6,289.33 0.82 1.00 -44.44 -2,351.40 -2,716.52 022 40.39 5.59 34.85 Pass-Major Risk 7,465.73 6,294.86 7,625.00 6,285.90 0.88 1.96 -40.59 -2,243.84 -2,808.36 0.22 181.48 7.43 174.07 Pass-Major Risk 7,471.02 6,295.04 7,500.00 6,288.16 0.93 1.24 -44.93 -2,342.31 -2,739.73 0.22 61.82 6.50 55.38 Pass-Major Risk 7,475.00 6,295.16 7,600.00 6,286.00 0.98 1.90 -42.40 -2,268.22 -2,803.00 022 159.09 7.67 151.45 Pass-Major Risk 7,477.61 6,295.24 7,525.00 6,287.20 1.00 1.46 -44.91 -2,328.85 -2,760.73 0.22 85.50 7.13 78.41 Pass-Major Risk 7,478.22 6,295.26 7,575.00 6,286.12 1.01 1.80 -43.48 -2,291.08 -2,792.98 022 135.09 7.66 127.46 Pass-Major Risk 7,479.83 6,295.30 7,550.00 6,286.51 1.03 1.65 -44.42 -2,311.55 -2,778.71 022 110.26 7.51 102.79 Pass-Major Risk CC- Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/6/2011 8:22:25AM Pa 6 f COMPASS 2003.16 Build 69 N,, ConocoPhillips or its affiliates Ir/lI ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-28 Project: Kuparuk River Unit ND Reference: 2K-28@ @ 148.65ft(2K-28@) Reference Site: Kuparuk 2K Pad MD Reference: 2K-28@ @ 148.65ft(2K-28@) Site Error: 000f North Reference: True Reference Well: 2K-28 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-28AL1 Database: EDM Alaska Prod v16 Reference Design: 2K-28AL1_wp03 Offset ND Reference: Offset Datum Reference Depths are relative to 2K-28@ @ 148.65ft(2K-28@) Coordinates are relative to:2K-28 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927,Alaska Zone 4 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:-0.02° Ladder Plot I 1 I I I 1400 ' I I 1 I I I I I 1 I I I I I I I I I I I I I I I J J __ __J J J __J_ _ _ I I I I I I I I I I I I I I I I I I I I I I I C 1050 - - I I I I I I 42 I I I I I I I I I 1 I I 0 I I I I I I CL _--_J__ __ _ J J J J J .. _ CI I I I I I I (/) I I I I I I I I I I I I I I I I I I m 700 U I I I I I I I I I I I I 2 I I I I I I I I I I I I e _ _ --J_ J J _ _ __J J J _ _ C I I I I I 1 w I I 1 I I I V I I I I I I I I I I I I 350 _ I I I 1 I I I I I I I I I I I I I I I I 1 I I J J J r J I I I I I I I I I 1 I I I I I 1 I 1 I I 1 0 i 0 2000 4000 6000 8000 10000 12000 M easured Depth LEGEND 2K-21.2K-21,2K-21 V2 -El- 2K-28.2K2e,2K-28 6 , 2 K-21.2K-21A,2 K-21 AVO ---- 2K-211.2K2eA,2K-28A wpOOVD CC-Min centre to center distance or covergent point,SF-,In sea�r�s tign factor,ES-min ellipse separation 10/6/2011 8:22:25AM Page 7 o7i ik k ! g COMPASS 2003.16 Build 69 w. t . E ...it I Ir rage i or z 1 Schwartz, Guy L (DOA) From: Winfree, Michael Alex (Jr.) [Michael.A.Winfree@conocophillips.com] Sent: Wednesday, November 09, 2011 8:23 AM To: Schwartz, Guy L (DOA) Cc: Gantt, Lamar L; Kanady, Randall B Subject: 2K-28 CTD 10-401 Response to Request for more Information Guy, Per the AOGCC's request, please find the information below regarding the Application for the Permit to Drill 2K-28A and 2K-28AL1: Slotted Liner Running Procedure • A SSSV is not present in the 2K-28 well, so the well will be displaced to a completion fluid that maintains overbalance on the formation prior to running the liner. • Confirm appropriate liner sized rams are in place in the BOP stack. • The pipe rams must be capable of sealing on the OD of the blank joint. • Have a TIW valve made up to a Range 2 length joint(safety joint)of blank liner ready for well control during running of the slotted liner • Monitor well bore fluid level and keep hole full at all times while making up liner. • RIH with 2%"slotted liner assembly to TD using 2" coil. • Release from liner running tools and pull out of the hole. Pressure Deploy BHA The double swab valves, double deployment rams, double ball valves and one set of double check valves in the BHA, and a slick line lubricator are used to deploy/undeploy the BHA under pressure. The Managed Pressure Drilling technique is used to maintain an overbalance on the formation, pumping below the swab valve, during the deployment procedure. The pressure control equipment listed ensures there are always two barriers to reservoir pressure during the BHA deploy/undeploy process. When the lubricator is installed and the BHA is spaced out above the tree, the double swab valves are closed and provide isolation to reservoir pressure. When the BHA is spaced out for access to the double ball valves, the set of double check valves and the double ball valves in the bottom hole assembly are preventing wellbore pressure communication up the BHA. The double deployment rams and lubricator are annular barriers to reservoir pressure with the BHA in this position. The lubricator can be removed once pressure is bled off above the deployment rams. Two barriers are still maintained with the double deployment rams on the annulus and the double check valves and double ball valves in the BHA. With the coil made up to the BHA, the double ball valves open in the BHA, and the riser installed, the BHA can continue to be safely run in the hole. Permit Application Clarification for Mud Weight In the permit application under the "Mud Program"and "Managed Pressure Drilling"sections, it states we intend to use a 10.0 ppg mud system for CT drilling operations on 2K-28. The mud weight in this section should be listed as a range between a 9.5 ppg and 10.5 ppg chloride based Flo-Pro mud system since the density of the fluid we choose to drill with depends on reservoir pressure and acceptable choke pressures for MPD operations. 11/9/2011 Page 2 of 2 Please let me know if you need additional information to process the 10-401 form for 2K-28A and 2K-28AL1. Thank you, -Mike Mike A. Winfree 0 265 6E20 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, November 03, 2011 1:51 PM To: Kanady, Randall B Cc: Gantt, Lamar L; Winfree, Michael Alex (Jr.) Subject: CTD PTD Randy, I am reviewing the regulation requirements and cross-referencing what is submitted in the CTD permit applications. Everything that is required by 20 AAC 25.005 seems to be in order. It still comes down to the procedural steps provided being detailed enough to allow me to ascertain that the equipment and processes are in place to safely drill and complete the well. Two items needed area a detailed procedure for running the slotted liners and more information on deploying the BHA tools under pressure.As we talked about in the meeting, if you were a new operator on the slope I would want to see your contingencies and SOP for both of these operations. A detailed bullet paragraph for both of these operations would be a great start. They could be added to the well control section of the application. You could reference the slotted liner paragraph in the procedure step itself. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 11/9/2011 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 l</C PTD# 2-7/ / Development Service Exploratory Strati ra hic Test Non-Conventional Well / FIELD•- /� ,� POOL: l L Brie y _ t l 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 2 C, �K' C �/ / (If last two digits in Permit No. API number are 2/(/- API No. 50-/()')- Z&)` - 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 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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