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212-062
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3H-11A KUPARUK RIV UNIT 3H-11A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 3H-11A 50-103-20091-01-00 212-062-0 W SPT 5873 2120620 1500 2825 2825 2825 2825 263 350 353 351 4YRTST P Austin McLeod 6/1/2025 MITIA. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3H-11A Inspection Date: Tubing OA Packer Depth 800 2010 1960 1945IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250602191240 BBL Pumped:1.2 BBL Returned:1.2 Thursday, July 24, 2025 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday,June 15,2017 '' / P.I.Supervisor /��- ( �17 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3H-11A FROM: Chuck Scheve KUPARUK RIV UNIT 3H-11A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry d NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3H-11AAPI Well Number 50-103-20091-01-00 Inspector Name: Chuck Scheve Permit Number: 212-062-0 Inspection Date: 6/4/2017 Insp Num: mitCS170605170705 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3H-11A 1Type Inj W 'TVD 5873 Tubing' 2852 2852 2852 . 2852 - PTD 2120620 Type Test SPT Test psi 1500 - IA 750 1990 - 1935 - 1930 - BBL Pumped: 1 ' BBL Returned: 0.9 OA 196 295 , 295 292 - Interval 4YRTST P/F P ✓ — Notes: SCANNED AUG 3 0 201 Thursday,June 15,2017 Page 1 of 1 r O `� 9 o N O O r. 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U a m a y y 2 1 o U U Q Z U I z Q u1 Z 7 1 ^ y u) 5VcL/V1 IC Ce a 2 a it 1 J '5 TO m 0 it i a w J o p j a N c 3 Ce O m y W z • H a.) J CO m a V U O E 3 E Z o ui o 0) o rn Q w J a c J a co v E w I CL O 6 2 0 0 M co O o O N_ a O E Q aU) N U C-=-1 v z J a e a } E N Q c E o O rE U °^ M E N w C >N (0 0• c13 C G • I` p N E CO re o of' E yr ! IHI o 2 0 1/ co z I T.) N • co o Lr) Z N N N r- 1 co,.. > (rco Vl ii p„, i_ O .,:, HN r N N o CL _ CO a> CO W m 6 ce H ca U O m w el o o a o p a � m U J d d a o a w E a O O G1 Q E 5 E E E MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg k) DATE: Wednesday,June 12,2013 \e`/ qP.I.Supervisor 1 ,f,3 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3H-I 1A FROM: John Crisp KUPARUK RIV UNIT 3H-IIA Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry j(, — NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3H-11A API Well Number 50-103-20091-01-00 Inspector Name: John Crisp Permit Number: 212-062-0 Inspection Date: 6/9/2013 Insp Num: mrtJCrl30610084150 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1 3H-11A - TType Inj '1 W 'FTVD 5873 IA r960 T 2960 2903 1 2888 2120620 li SPT 1500 1 330 I- 1 PTD Type Testi Test psi OA � 182 343 338 1 ;-- 22 - 2234 2234 2234 Interval j4�TST �P/F P Tubin-g2234 --- -' — — Notes: 1 9 bbls pumped for test, Wednesday,June 12,2013 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 1b.Well Class 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑� WDSPL ❑ Other ❑ No.of Completions: Service 2 Stratigraphic Test❑ 2 Operator Name' 5 Date Comp.,Susp, 12.Permit to Drill Number ConocoPhillips Alaska, Inc. or Aband.: October 7,2012 212-062/ - 3 Address' 6 Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 September 19,2012 50-103-20091-01 4a Location of Well(Governmental Section): 7.Date TD Reached 14.Well Name and Number: Surface: 1232'FNL,281'FWL,Sec. 12,T12N,R8E,UM October 3,2012 3H-11A Top of Productive Horizon 8. KB(ft above MSL): 69.6'RKB • 15.Field/Pool(s)- 290'FNL, 1962'FEL,Sec. 12,T12N, R8E,UM GL(ft above MSL): 38.7'AMSL • Kuparuk River Field • Total Depth 9 Plug Back Depth(MD+TVD)' 125'FNL, 1839'FEL,Sec. 12,T12N, R8E, UM 7322'MD/6220'TVD Kupuruk River Oil Pool . 4b.Location of Well(State Base Plane Coordinates,NAD 27)' 10.Total Depth(MD+TVD)' 16.Property Designation Surface: x-498655 y- 6000425 Zone-4 7375'MD/6258'TVD ADL 25531 ' TPI: x-501691 y- 6001367 Zone-4 11.SSSV Depth(MD+ND) 17.Land Use Permit: Total Depth: x-501814 y- 6001533 Zone-4 1978'MD/1839'TVD 2657 18.Directional Survey: Yes 0 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) 2701'MD/2401'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071) 22 Re-dnll/Lateral Top Window MD/TVD GR/Res 2701'MD/2401'TVD 23 CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT PER FT GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 36' 115' 36' 115' 24" 215 sx AS I 10.75" 45 5# J-55 35' 3637' 35' 3088' 13.5" 1200 sx AS III,600 sx Class G,130 sx AS I 7" 26# L-80 28' 6907' 28' 5929' 8.75" 239 sx Class G,116 sx LiteCRETE 4.5" 12.6# L-80 6813' 7375' 5863' 6258' 6.125" 89 sx Class G 24 Open to production or injection'? Yes ❑ No ❑✓ If Yes,list each 25 TUBING RECORD Interval open(MD+TVD of Top&Bottom,Perforation Size and Number) SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 6863' 6813'MD/5863'TVD none ,, �, _•, 26 ACID,FRACTURE,CEMENT SQUEEZE,ETC it 4:;°. .•h' 't..,.Z , , e.,..,4Was hydraulic fracturing used during completion? Yes No 0 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED OGCC 27 PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc) waiting on post-rig well work Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press 24-Hour Rate-> 28 CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑✓ Sidewall Cores Acquired? Yes ❑, No ❑ If Yes to either question,list formations and intervals cored(MD+ND of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed) Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. SEE ATTACHED SUMMARY • RBDMS JUN 11 2013 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original onlytiu\73 29 GEOLOGIC MARKERS(List all formations and ma. ,encountered) 30 FORMATION TESTS NAME MD TVD Well tested? Yes Q✓ No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results Attach separate sheets to this form,if Permafrost-Bottom 1721 1633' needed,and submit detailed test information per 20 AAC 25.071 Top Kuparuk River 7005' 5997' Kuparuk A 7085' 6054' Kuparuk A2 7124' 6081' Kuparuk A3 7095' 6061' N/A Formation at total depth: Kuparuk A2 31. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Haibin Guo @ 265-1487 Email Haibin.Guoeconocoohillips.com Printed Name G.L.Allvord Title Alaska Drilling Manager r Signature ACCV- Phone 265-6120 Date b(q(.r; INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain) Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25 071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071 Form 10-407 Revised 10/2012 G.L.Alvord R . Alaska Drilling Manager EC "°°° Drilling&Wells JUN 0 n 2013 P.0. Box 100360 Anchorage,AK 99510-0360 ConocoPhiilips AOGCC Phone: 907-265-6120 June 3, 2013 AOGCC Commissioner 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Subject: Revised Completion Report for 3H-11A Dear Commissioner: Attached for your review is the revised completion report for 3H-11A. Included in this package is the summary of sidewall cores that you requested. We did not do conventional cores in this well. We have also updated the geologic markers as requested. We will not include the daily operations summary or the directional survey with this submittal because we have already sent these documents. If you have any questions, please feel free to call me at anytime. Sincerely, 4.L. 4 G. L. 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E 4r v. m et a a x-1 -7 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION R PORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ WAG ❑ WDSPL ❑ Other ❑ No of Completions: Service C7 Stratigraphic Test❑ 2.Operator Name: 5 Date Comp.,Susp, 12.Permit to Drill Number: ConocoPhillips Alaska,Inc. orAband.: October 7,2012 212-062/ 3.Address: 6 Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 September 19,2012 50-103-20091-01 4a.Location of Well(Governmental Section): 7 Date TD Reached: 14.Well Name and Number: Surface: 1232'FNL,281'FWL,Sec. 12,T12N,R8E,UM October 3,2012 3H-11A Top of Productive Horizon: 8.KB(ft above MSL): , 69.6'RKB 15.Field/Pool(s): 290'FNL, 1962'FEL,Sec. 12,T12N,R8E,UM GL(ft above MSL): 38.7'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+ND): 125'FNL, 1839'FEL,Sec. 12,T12N,R8E,UM 7322'MD/6220'TVD Kupuruk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+ND): 16.Property Designation: Surface: x-498655 y- 6000425 Zone-4 7375'MD/6258'TVD ADL 25531 TPI: x-501691 y- 6001367 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-501814 y- 6001533 Zone-4 1978'MD/1839'TVD 2657 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) 2701'MD/2401'ND 21.Logs Obtained(List all logs here and submit electronic a d printed'nformation per 20 MC 25.071). 22.Re-dnII/Lateral Top Window MD/TVD V GR/Res 03 I f 106 f.2O)2, Ial a 2701'MD/2401'TVD 23. /CASING,LINER AND CEMENTING RECORD - SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT -- -- - - CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 36' _ 115' 36' 115' 24" 215 sx AS I 10.75" 45.5# J-55 _ 35' 3637' 35' 3088' 13.5" 1200 sx AS III,600 sx Class G,130 sx AS I 7" 26# L-80 28' _ 6907' 28' 5929' 8.75" 239 sx Class G,116 sx LiteCRETE 4.5" 12.6# L-80 6813' 7375' 5863' 6258' 6.125" 89 sx Class G 24.Open to production or injection? Yes ❑ No ❑✓ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/IVD) 3.5" 6863' 6813'MD/5863'ND none 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes❑ No❑✓ DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 11. RECEIVED N0v072012 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc) AOGCC waiting on post-rig well work Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes Q No ❑ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25 071. TO BE SENT ON A SUBSEQUENT REPORT . t4,- .�-vi, NOVOv -- _..04 Form 10-407 Revised 10/2012 ( CONTINUED ON REVERSE Submit original only CbW 4/�r/zoo, G 29. GEOLOGIC MARKERS(List all formations and ma. encountered): 30 FORMATION TESTS NAME MD II TVD Well tested? ❑ Yes E✓ 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 1721 1633' needed,and submit detailed test information per 20 AAC 25.071. Top Kuparuk River 7005' 5997' Kuparuk A 7085' 6054' N/A Formation at total depth: Kuparuk A2 31. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Haibin Guo @ 265-1487 Email: Haibin.Guo@conocophillips.com Printed Name G.L.Alvord Title: Alaska Drilling Manager Signature A-Lak_ Phone 265-6120 Date irl•(20/1_ • INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 3H-11A Slot Recovery Final Schematic Haibin Guo, updated 10-22 2012 16"conductor set at 115' ': Schlumberger TRMAXX-CMT-5-SR @ 1,978'MD/1,827'TVD • 3-'/2"9.3#,L-80,EUE Tubing GLM# TVD ft MD ft Valve Type 1 2,520 2,867 Dummy 2 3,685 4,256 Dummy 3 4,635 5,303 Dummy : : iBliiiii, 10'3/4"Whipstock Top @2,701'MD::: H11111111111. 4 5,315 5,978 Dummy 5 5,700 6,593 SOV(annulus to tubing shear) Note: 5 ea Camco 3-1/2"x 1-1/2" MMG 7"cemented stub @2,751'MD 10-3/4"J-55,45.5#surface casing @ 3,637'MD. TOC of 2nd stage @+/-3,000'MD • Bottom of Cement @ 4,250'MD . Tabasco sand @3,772'—3,875'MD , i, 1 •• HES Stage collar+/-3,983'MD .. Set cement in 7"casing from 4,365' i 5,600'MD TOC @+/-5,800'MD 3-'/2"tubing Cut @+/-5,600' TOC in 7"&3-'/2"tubing @+/- 5,800' -' ��•:, 3 '/2" HES"X"selective nipple w/2.813" ID @ 6,776'MD /5,837'TVD Cement Retainer+/-7,164'MD : ::•:::::•:. Baker ZXP liner top Packer@ 6,813' �� MD/5,864'TVD ::)\-`` •7"26#L80 BTCM casing set(topset) . \\ @ 6,907'MD/5,929'TVD -1/2" 12.6#L80 IBTM Liner set �::::::::� @ 7,375'MD/6,258'TVD b KUP 3H-11A • ConocoPhillips l$ Well Attributes Max Angle&MD TD . Wellbore API/UWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ftKB) caned:Pi501032009101 KUPARUKRIVERUNIT SVC 46.18 7,165.15 7,375.0 "" Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date -- -SSSV:TRDP 245 11/26/2009 Last WO: 10/6/2012 42.01 12/28/1987 Well Contig-3H-11A,1 024/2 01 2 11:39:34 AM -- Schemalic-Acwai Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:WORKOVER/SIDETRACK'A'REVIEW osborl 10/24/2012 `- Casing Strings HANGER.26 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)... String Wt...String...String Top Thrd r CONDUCTOR 16 15.062 35.5 115.0 115.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd SURFACE 103/4 9.950 35.2 3,637.1 3,178.4 45.50 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd I WINDOWA 103/4 8.000 2,701.0 2,721.0 2,415.7 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 27.9 6,907.2 5,929.0 26.00 L-80 BTC CONDUCTOR, POST S/T 35-115 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)... String Wt...String...String Top Thrd LINER 41/2 3.930 6,813.0 7,375.0 12.60 L-80 IBT-M SAFETY VLV, it Io.l .. 1 978 Liner DDetails Top Depth 3 (TVD) Top Incl Nomi... I Top(ftKB) (ftKB) (°) Item Description Comment ID(in) WHIPSTOCK 6,813.0 5,863.1 45.40 PACKER BAKER ZXP LINER TOP PACKER 4.410 2.701 6,831.5 5,876.2 45.58 HANGER BAKER KSI HYDRAULIC FLEX LOCK HANGER 4.470 W NDOW A. 2,701-2'721 6,842.1 5,883.6 45.69 SBE 80-40 SEAL BORE EXTENSION 4.000 Tubing Strings GAS LIFT. " Tubing Description 'String0... StringID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd 2.867 I I I I 9.30 I L-80 EUE8RDMOD TUBING WO 3 1/2 2.992 26.0 6,863.0 5,898.4 Completion Details __' Top Depth I )TVD) Top not Nomi... Top(ftKB) (ftKB) (") Item Description Comment ID(in) F6 26.0 26.0 -0.01 HANGER FMC TUBING HANGER 3.950 1,978.3 1,839.0 37.57 SAFETY VLV CAMCO TRMAX(-CMT-SR-5 SAFETY VALVE w/2.813"PROFILE 2.812 SURFACE, j 6,776.3 5,837.4 45.03 NIPPLE HES XNIPPLE 2.813 33.3,637 6,825.1 5,871.7 45.52 LOCATOR BAKER 80-40 GBH-22 LOCATOR SUB 3.000 (. I 6,826.4 5,872.6 45.53 SEAL ASSY BAKER SEAL ASSEMBLY w/20'STROKE AND 1/2 MULESHOE('6' 2.990 OFF LOCATOR) Other In Hole Wireline retrievable plugs,valves,pumps,fish,etc.) (�j Top Depth L I (TVD) Top Incl GAS LIFT, 1 Top(ftKB) (RKB) (1 _ Description Comment Run Date ID(in) 4.256 1 2,701.0 2,400.8 41.44 WHIPSTOCK WHIPSTOCK SET FOR SIDETRACK A 9/17/2012 Notes:General&Safety End Date Annotation 7/24/2001 NOTE:ESP WORKOVER ...,, - 8/17/2012 NOTE:WELL WORKOVER/SIDETRACK'A'-Original Prod Csg cut/pulled @ 2451' IIII II III GAS AFT. EIP fi 593 IN ■ ■@'. NIPPLE.6,776- m= ■ a ' 1 I LOCATOR, 6,825 t-1 SEAL ASSY, 6.826 • Mandrel Details Top Depth Top Port I (TVD) Incl OD Valve Latch Sine TRO Run Stn Top(ftKB) (SKS) F) Make Model (in) Sem Type Type On) (psi) Run Date Com... 1 2,867.4 2,524.0 41.74 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/6/2012 PRODUCTION p 4,255.9 3,723.1 26.79 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/6/2012 POST S/T, 28-0,907 3 5,302.7 4,651.9 26.44 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/6/2012 4 5,978.4 5,243.4 32.82 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/6/2012 5 6,593.4 5,707.5 45.04 CAMCO MMG 1 1/2 GAS LIFT SOV REK 0.000 0.0 10/6/2012 • I I LINER. 6.813-7,375 TD(3H-1 IA), 7,375 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,April 17,2013 Jim Regg P.I.Supervisor \ 4 76(/3 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3H-11A FROM: Jeff Jones KUPARUK RIV UNIT 3H-I IA Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprvs J�'- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3H-IIA API Well Number 50-103-20091-01-00 Inspector Name: Jeff Jones Permit Number: 212-062-0 Inspection Date: 4/5/2013 Insp Num: mitJJ130416141705 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well i f OA 2 206 0Type Inj � Test psi 5873 i 1207 352 - 3 62900 I 0 308 �- --- -- s ITVD1500 IA I II 038 PTD T e Test6 Interval INITAL IP/F P - Tubing zlss 2186 2186 2187 Notes: 1 5 BBLS diesel pumped. I well inspected,no exceptions noted. Wednesday,April 17,2013 Page 1 of 1 Page 1 of 2 Guo, Haibin From: Schwartz, Guy L (DOA) [guy.schwartz@alaska.gov] Sent: Friday, November 02, 2012 2:47 PM To: Guo, Haibin Cc: Jolley, Liz C; Wallace, Chris D (DOA) Subject: [EXTERNAL]RE: 3H-11A 7" casing Tally correction. Permit number: 212062 Haibin, Thank you for being forthwith and letting us know of the casing tally error. The error is relatively minor and does not affect the casing integrity and zonal control as required under UIC rules. As long as the casing tests and liner lap passes an MIT—IA no further action will be needed. The Commission will grant a variance to the 100' lap requirement. BTW.. If you have run a gamma ray log over the casing and liner (with CBL)you might be able to detect the depth of the 7"shoe by looking for a change in the GR attenuation. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Guo, Haibin [mailto:Haibin.Guo@conocophillips.com] Sent: Friday, November 02, 2012 11:58 AM To: Schwartz, Guy L (DOA) Cc: Jolley, Liz C Subject: 3H-11A 7" casing Tally correction. Permit number: 212062 Guy, Well 3H-11A is a Rotary Sidetrack CTD Setup well for two CTD laterals in A2 and A3 sands. Using Nordic 3,well 3H-11A was sidetracked from the 10-3/4"surface casing at 2701'MD. The 8-3/4"hole was drilled and 7"casing run to top setting the Kuparuk sand due to pressure risks. The 6-1/8"production hole was drilled through the Kuparuk sands and a 4-1/2"liner run to TD. The liner was pressure tested and a CBL was run in the 4-1/2"liner indicating good cement bond. To meet the regulation requirements 20 AAC 25.030.D6,"a minimum of 100 feet overlap between the outer and inner strings is required"and the area injection order for Kuparuk,"the packer should be set within 200'above top of pay zone",the design planned for 106'liner overlap. The plan include the 7"casing and the top of liner packer hanger set at 197'above Kuparuk C sand. Recently,an error was found in the casing tally and was corrected. The correct tally indicates the 7"casing shoe is located at 6907'MD. Based on the corrected tally,the liner overlap is 94'and liner top packer is 199'above Kuparuk C described below. Components Depth (top) 4-1/2" Liner packer top 6813' MD 7"casing shoe (bottom) 6907' MD Top of Kuparuk C sand 7012' MD CTD KOPs 7031'-7080' MD. A diagram is attached for your reference. If you have any questions or require further information,please let me know. Sincerely, 11/5/2012 Page 2 of 2 ` i I I 1 I Haibin Guo Drilling Engineer ConocoPhillips Alaska Office: 907.265.1487 Cell: 907.297.9113 11/5/2012 ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3H Pad 3H-11A 501032009101 Sperry Drilling Definitive Survey Report 03 October, 2012 ANL .111 MINK AMIE HALLIBURTON I Sperry Drilling ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 3H-11 Project: Kuparuk River Unit TVD Reference: 3H-11A @ 69.60ft(Nordic 3(38.7+30.9)) Site: Kuparuk 3H Pad MD Reference; 3H-11A @ 69.60ft(Nordic 3(38.7+30.9)) Well: 3H-11 North Reference: True Wellbore: 3H-11A Survey Calculation Method: Minimum Curvature Design: 3H-11A Database: CPAI EDM Production 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 Well 3H-11 Well Position +N/-S 0.00 ft Northing: 6,000,425.37 ft Latitude: 70°24'44.626 N +E/-W 0.00 ft Easting: 498,655.44 ft Longitude: 150°0'39.418 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 38.70ft Wellbore 3H-11A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 9/20/2012 20.25 80.98 57,629 Design 3H-11A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 2,693.60 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 30.90 0.00 0.00 83.00 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 93.60 2,693.60 3H-11 (3H-11) GCT-MS Schlumberger GCT multishot 1/12/2001 12:C 2,701.00 4,196.46 3H-11A(3H-11A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/19/2012 12:C 4,196.46 6,921.01 3H-11A(3H-11A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/19/2012 12:C 6,921.01 7,336.91 3H-11A(3H-11A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/19/2012 12:C Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (1 (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 30.90 0.00 0.00 30.90 -38.70 0.00 0.00 6,000,425.37 498,655.44 0.00 0.00 UNDEFINED 93.60 0.13 118.43 93.60 24.00 -0.03 0.06 6,000,425.34 498,655.50 0.21 0.06 GCT-MS(1) 193.60 0.20 120.83 193.60 124.00 -0.18 0.31 6,000,425.19 498,655.75 0.07 0.29 GCT-MS(1) 293.60 0.25 129.72 293.60 224.00 -0.41 0.63 6,000,424.96 498,656.07 0.06 0.58 GCT-MS(1) 393.60 0.92 114.42 393.59 323.99 -0.88 1.53 6,000,424.49 498,656.97 0.68 1.41 GCT-MS(1) 493.60 4.47 96.45 493.47 423.87 -1.65 6.13 6,000,423.72 498,661.57 3.61 5.89 GCT-MS(1) 593.60 8.52 94.78 592.81 523.21 -2.70 17.39 6,000,422.66 498,672.83 4.05 16.93 GCT-MS(1) 693.60 13.45 92.37 690.94 621.34 -3.80 36.41 6,000,421.56 498,691.84 4.95 35.67 GCT-MS(1) 793.60 16.08 92.53 787.63 718.03 -4.89 61.87 6,000,420.47 498,717.30 2.63 60.81 GCT-MS(1) 893.60 17.72 93.21 883.31 813.71 -6.36 90.90 6,000,419.00 498,746.33 1.65 89.45 GCT-MS(1) 993.60 18.95 93.71 978.23 908.63 -8.26 122.30 6,000,417.09 498,777.72 1.24 120.38 GCT-MS(1) 10/3/2012 9:16:41AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 3H-11 Project: Kuparuk River Unit TVD Reference: 3H-11A @ 69.60ft(Nordic 3(38.7+30.9)) Site: Kuparuk 3H Pad MD Reference: 3H-11A @ 69.60ft(Nordic 3(38.7+30.9)) Well: 3H-11 North Reference: True Wellbore: 3H-11A Survey Calculation Method: Minimum Curvature Design: 3H-11A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (ft) r) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,093.60 20.95 94.33 1,072.23 1,002.63 -10.66 156.33 6,000,414.68 498,811.75 2.01 153.87 GCT-MS(1) 1,193.60 22.55 94.57 1,165.10 1,095.50 -13.54 193.27 6,000,411.80 498,848.69 1.60 190.18 GCT-MS(1) 1,293.60 24.17 94.75 1,256.90 1,187.30 -16.76 232.79 6,000,408.57 498,888.20 1.62 229.01 GCT-MS(1) 1,393.60 25.22 94.21 1,347.76 1,278.16 -20.02 274.44 6,000,405.30 498,929.85 1.07 269.96 GCT-MS(1) 1,493.60 26.88 94.11 1,437.60 1,368.00 -23.21 318.24 6,000,402.11 498,973.64 1.66 313.04 GCT-MS(1) 1,593.60 30.95 95.34 1,525.11 1,455.51 -27.22 366.41 6,000,398.09 499,021.81 4.11 360.36 GCT-MS(1) 1,693.60 34.25 95.22 1,609.35 1,539.75 -32.18 420.05 6,000,393.12 499,075.44 3.30 413.00 GCT-MS(1) 1,793.60 36.03 95.02 1,691.12 1,621.52 -37.31 477.38 6,000,387.98 499,132.76 1.78 469.27 GCT-MS(1) 1,893.60 36.90 96.01 1,771.54 1,701.94 -43.03 536.53 6,000,382.25 499,191.91 1.05 527.29 GCT-MS(1) 1,993.60 37.65 96.10 1,851.11 1,781.51 -49.42 596.76 6,000,375.85 499,252.13 0.75 586.29 GCT-MS(1) 2,093.60 38.20 96.37 1,929.99 1,860.39 -56.09 657.86 6,000,369.17 499,313.22 0.57 646.12 GCT-MS(1) 2,193.60 38.20 96.68 2,008.58 1,938.98 -63.12 719.30 6,000,362.13 499,374.65 0.19 706.24 GCT-MS(1) 2,293.60 38.17 97.56 2,087.18 2,017.58 -70.78 780.64 6,000,354.46 499,435.99 0.54 766.20 GCT-MS(1) 2,393.60 38.83 98.28 2,165.44 2,095.84 -79.36 842.30 6,000,345.86 499,497.64 0.80 826.35 GCT-MS(1) 2,493.60 39.40 98.72 2,243.03 2,173.43 -88.69 904.69 6,000,336.53 499,560.02 0.63 887.14 GCT-MS(1) 2,593.60 40.45 99.26 2,319.72 2,250.12 -98.72 968.08 6,000,326.49 499,623.40 1.11 948.83 GCT-MS(1) 2,693.60 41.40 99.64 2,395.27 2,325.67 -109.48 1,032.70 6,000,315.72 499,688.01 0.98 1,011.66 GCT-MS(1) 2,701.00 41.44 99.67 2,400.82 2,331.22 -110.30 1,037.52 6,000,314.90 499,692.84 0.60 1,016.35 MWD+IFR-AK-CAZ-SC(2) 2,773.20 42.96 93.30 2,454.33 2,384.73 -115.73 1,085.66 6,000,309.46 499,740.97 6.29 1,063.46 MWD+IFR-AK-CAZ-SC(2) 2,818.69 42.35 89.28 2,487.79 2,418.19 -116.43 1,116.46 6,000,308.75 499,771.77 6.14 1,093.95 MWD+IFR-AK-CAZ-SC(2) 2,868.39 41.70 84.93 2,524.72 2,455.12 -114.76 1,149.68 6,000,310.42 499,804.98 6.00 1,127.12 MWD+IFR-AK-CAZ-SC(2) 2,916.17 39.78 86.02 2,560.92 2,491.32 -112.29 1,180.76 6,000,312.88 499,836.06 4.29 1,158.27 MWD+IFR-AK-CAZ-SC(2) 2,962.34 39.31 83.88 2,596.53 2,526.93 -109.71 1,210.04 6,000,315.45 499,865.34 3.12 1,187.65 MWD+IFR-AK-CAZ-SC(2) 3,058.36 34.96 83.54 2,673.06 2,603.46 -103.37 1,267.64 6,000,321.78 499,922.94 4.54 1,245.59 MWD+IFR-AK-CAZ-SC(2) 3,153.39 31.60 84.20 2,752.49 2,682.89 -97.79 1,319.48 6,000,327.36 499,974.77 3.56 1,297.73 MWD+IFR-AK-CAZ-SC(2) 3,247.67 29.38 81.30 2,833.73 2,764.13 -91.79 1,366.92 6,000,333.34 500,022.21 2.82 1,345.55 MWD+IFR-AK-CAZ-SC(2) 3,342.08 28.08 74.82 2,916.54 2,846.94 -82.47 1,411.27 6,000,342.66 500,066.56 3.57 1,390.70 MWD+IFR-AK-CAZ-SC(2) 3,438.49 27.11 71.95 3,001.99 2,932.39 -69.72 1,454.06 6,000,355.40 500,109.34 1.71 1,434.72 MWD+IFR-AK-CAZ-SC(2) 3,533.60 27.59 70.98 3,086.46 3,016.86 -55.83 1,495.49 6,000,369.28 500,150.77 0.69 1,477.54 MWD+IFR-AK-CAZ-SC(2) 3,628.08 27.13 70.10 3,170.38 3,100.78 -41.36 1,536.43 6,000,383.73 500,191.71 0.65 1,519.93 MWD+IFR-AK-CAZ-SC(2) 3,721.84 28.25 69.21 3,253.40 3,183.80 -26.21 1,577.27 6,000,398.88 500,232.55 1.27 1,562.32 MWD+IFR-AK-CAZ-SC(2) 3,816.98 29.56 70.57 3,336.68 3,267.08 -10.41 1,620.46 6,000,414.67 500,275.73 1.54 1,607.11 MWD+IFR-AK-CAZ-SC(2) 3,911.96 28.83 70.51 3,419.60 3,350.00 5.02 1,664.14 6,000,430.09 500,319.41 0.77 1,652.35 MWD+IFR-AK-CAZ-SC(2) 4,006.72 28.47 70.58 3,502.75 3,433.15 20.16 1,706.98 6,000,445.22 500,362.25 0.38 1,696.71 MWD+IFR-AK-CAZ-SC(2) 4,102.09 27.98 70.78 3,586.78 3,517.18 35.08 1,749.54 6,000,460.13 500,404.81 0.52 1,740.78 MWD+IFR-AK-CAZ-SC(2) 4,196.46 27.36 69.91 3,670.36 3,600.76 49.82 1,790.81 6,000,474.86 500,446.08 0.78 1,783.53 MWD+IFR-AK-CAZ-SC(2) 4,291.75 26.92 69.93 3,755.16 3,685.56 64.74 1,831.64 6,000,489.77 500,486.91 0.46 1,825.88 MWD+IFR-AK-CAZ-SC(3) 4,386.39 27.26 68.84 3,839.42 3,769.82 79.92 1,871.97 6,000,504.94 500,527.24 0.64 1,867.76 MWD+IFR-AK-CAZ-SC(3) 4,481.32 26.93 67.85 3,923.93 3,854.33 95.87 1,912.16 6,000,520.88 500,567.43 0.59 1,909.59 MWD+IFR-AK-CAZ-SC(3) 4,576.19 27.68 68.32 4,008.23 3,938.63 112.11 1,952.53 6,000,537.12 500,607.80 0.82 1,951.64 MWD+IFR-AK-CAZ-SC(3) 10/3/2012 9:16:41AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 3H-11 Project: Kuparuk River Unit TVD Reference: 3H-11A @ 69.60ft(Nordic 3(38.7+30.9)) Site: Kuparuk 3H Pad MD Reference: 3H-11A @ 69.60ft(Nordic 3(38.7+30.9)) Well: 3H-11 North Reference: True Wellbore: 3H-11A Survey Calculation Method: Minimum Curvature Design: 3H-11A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,670.61 27.43 69.28 4,091.94 4,022.34 127.90 1,993.26 6,000,552.90 500,648.52 0.54 1,993.99 MWD+IFR-AK-CAZ-SC(3) 4,765.63 26.88 69.03 4,176.48 4,106.88 143.34 2,033.78 6,000,568.33 500,689.05 0.59 2,036.09 MWD+IFR-AK-CAZ-SC(3) 4,860.55 28.33 70.46 4,260.60 4,191.00 158.55 2,075.05 6,000,583.53 500,730.31 1.68 2,078.90 MWD+IFR-AK-CAZ-SC(3) 4,955.55 28.02 70.15 4,344.34 4,274.74 173.67 2,117.28 6,000,598.64 500,772.54 0.36 2,122.66 MWD+IFR-AK-CAZ-SC(3) 5,050.44 27.87 69.63 4,428.17 4,358.57 188.95 2,159.04 6,000,613.92 500,814.29 0.30 2,165.97 MWD+IFR-AK-CAZ-SC(3) 5,144.93 27.57 68.98 4,511.81 4,442.21 204.48 2,200.15 6,000,629.44 500,855.41 0.45 2,208.67 MWD+IFR-AK-CAZ-SC(3) 5,239.82 27.25 69.73 4,596.05 4,526.45 219.89 2,241.03 6,000,644.83 500,896.28 0.50 2,251.12 MWD+IFR-AK-CAZ-SC(3) 5,335.73 26.84 69.52 4,681.47 4,611.87 235.07 2,281.91 6,000,660.01 500,937.16 0.44 2,293.55 MWD+IFR-AK-CAZ-SC(3) 5,430.16 27.98 69.85 4,765.30 4,695.70 250.16 2,322.68 6,000,675.09 500,977.93 1.22 2,335.85 MWD+IFR-AK-CAZ-SC(3) 5,525.51 27.67 69.67 4,849.62 4,780.02 265.56 2,364.44 6,000,690.47 501,019.69 0.34 2,379.17 MWD+IFR-AK-CAZ-SC(3) 5,619.13 27.30 69.16 4,932.68 4,863.08 280.75 2,404.88 6,000,705.66 501,060.13 0.47 2,421.17 MWD+IFR-AK-CAZ-SC(3) 5,713.65 29.34 64.82 5,015.89 4,946.29 298.31 2,446.11 6,000,723.21 501,101.36 3.07 2,464.23 MWD+IFR-AK-CAZ-SC(3) 5,808.27 30.09 64.54 5,098.07 5,028.47 318.37 2,488.50 6,000,743.26 501,143.75 0.81 2,508.75 MWD+IFR-AK-CAZ-SC(3) 5,902.68 31.26 58.90 5,179.28 5,109.68 341.21 2,530.86 6,000,766.09 501,186.10 3.29 2,553.57 MWD+IFR-AK-CAZ-SC(3) 5,997.49 33.21 55.32 5,259.48 5,189.88 368.69 2,573.28 6,000,793.56 501,228.53 2.88 2,599.03 MWD+IFR-AK-CAZ-SC(3) 6,092.70 36.30 50.98 5,337.71 5,268.11 401.28 2,616.63 6,000,826.14 501,271.88 4.16 2,646.03 MWD+IFR-AK-CAZ-SC(3) 6,186.94 39.51 45.49 5,412.08 5,342.48 439.88 2,659.71 6,000,864.73 501,314.96 4.94 2,693.49 MWD+IFR-AK-CAZ-SC(3) 6,283.03 41.49 38.49 5,485.18 5,415.58 486.25 2,701.34 6,000,911.09 501,356.60 5.16 2,740.47 MWD+IFR-AK-CAZ-SC(3) 6,329.34 41.85 36.23 5,519.78 5,450.18 510.72 2,720.02 6,000,935.55 501,375.28 3.34 2,761.99 MWD+IFR-AK-CAZ-SC(3) 6,376.86 43.22 36.10 5,554.79 5,485.19 536.66 2,738.98 6,000,961.48 501,394.24 2.89 2,783.96 MWD+IFR-AK-CAZ-SC(3) 6,472.63 46.08 36.70 5,622.92 5,553.32 590.82 2,778.92 6,001,015.63 501,434.19 3.02 2,830.21 MWD+IFR-AK-CAZ-SC(3) 6,567.53 45.24 35.88 5,689.24 5,619.64 645.53 2,819.09 6,001,070.32 501,474.37 1.08 2,876.75 MWD+IFR-AK-CAZ-SC(3) 6,662.40 44.52 35.31 5,756.47 5,686.87 699.96 2,858.06 6,001,124.74 501,513.34 0.87 2,922.06 MWD+IFR-AK-CAZ-SC(3) 6,757.65 44.84 36.11 5,824.19 5,754.59 754.34 2,897.15 6,001,179.11 501,552.44 0.68 2,967.49 MWD+IFR-AK-CAZ-SC(3) 6,852.04 45.79 36.75 5,890.57 5,820.97 808.33 2,937.01 6,001,233.09 501,592.30 1.12 3,013.63 MWD+IFR-AK-CAZ-SC(3) 6,921.01 45.79 36.34 5,938.66 5,869.06 848.05 2,966.44 6,001,272.80 501,621.74 0.43 3,047.68 MWD+IFR-AK-CAZ-SC(3) 6,977.78 45.56 36.39 5,978.33 5,908.73 880.75 2,990.52 6,001,305.49 501,645.82 0.41 3,075.57 MWD+IFR-AK-CAZ-SC(4) 7,071.86 44.98 36.23 6,044.54 5,974.94 934.61 3,030.10 6,001,359.34 501,685.41 0.63 3,121.42 MWD+IFR-AK-CAZ-SC(4) 7,165.15 46.18 36.54 6,109.83 6,040.23 988.25 3,069.63 6,001,412.97 501,724.94 1.31 3,167.18 MWD+IFR-AK-CAZ-SC(4) 7,261.13 45.31 36.52 6,176.81 6,107.21 1,043.49 3,110.55 6,001,468.19 501,765.87 0.91 3,214.53 MWD+IFR-AK-CAZ-SC(4) 7,336.91 44.39 36.42 6,230.54 6,160.94 1,086.46 3,142.32 6,001,511.16 501,797.64 1.22 3,251.30 MWD+IFR-AK-CAZ-SC(4) 7,375.00 44.39 36.42 6,257.75 6,188.15 1,107.91 3,158.13 6,001,532.60 501,813.46 0.00 3,269.61 PROJECTED to TD 10/3/2012 9:16:41AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips Time Log & Summary WeiWiew Web Reporting Report Well Name: 3H-11 Rig Name: NORDIC 3 Job Type: DRILLING SIDETRACK Rig Accept: 8/26/2012 10:00:00 AM Rig Release: 10/8/2012 4:00:00 AM Time Logs Date From To Dur S.Depth B.Depth Phase Code Subcode T Comment 08/11/2012 24 hr Summary Breaking down 11"5M BOPE stack on 2T-Pad.Move Camp to 1Q-Pad. Begin Rig move to 3H-Pad from 2T-Pad moving on mats do to soggy roads. As of Midnight we were 9/10's of a mile from 2A-Pad moving on mats. 09:00 11:00 2.00 MIRU MOVE MOB P Breaking down 11"5M BOP Stack and racking on skid. Rig Camp on 1Q-pad at 02:30 am. 11:00 00:00 13.00 MIRU MOVE MOB P PJSM- Rig move over mats. Begin Rig move to 3H-pad shuffling mats to 9/10th of mile from 2A Pad as of Midnight 08/12/2012 Continue to move towards Spine road=1.8 miles on mats. 00:00 05:00 5.00 MIRU MOVE MOB P Continue to move towards 2A-Pad- made 2/10 of mile shuffling mats with 4 loaders-7/10 of mile shy of arriving at 2A-Pad. 05:00 18:00 13.00 MIRU MOVE MOB P Rig stopped on south side of 2A pad to check rig tires and torque,also allow mats to be moved around and placed on access road from 2A pad to Spine Rd.at 4 corners approximately 7/10 of a mile. 18:00 00:00 6.00 MIRU MOVE MOB P Continue to move rig on mats from 2A-pad to 1/10 mile from Four Corners as of midnight 08/13/2012 Continue to move on mats to four corners. Stage all mats ahead of rig and place over culverts and pipe line crossings. Cover all known soft spots in spine road. Moved to CPF-2 as of midnight. 00:00 03:30 3.50 MIRU MOVE MOB P Exceptional rig move-Finish moving rig to 4 corners on mats and set down,to wait for mats to be loaded and trucked ahead of rig. 03:30 08:00 4.50 MIRU MOVE MOB T Wait for KDTH to Truck mats ahead of rig and cover pipeline crossings and culverts. Stay set down and allow CPF 2 and other field change outs. 08:00 09:30 1.50 MIRU MOVE MOB P Normal rig move-Move Nordic 3 w/ mats over culverts and on low spots from 4 corners to 2B Pad 09:30 12:00 2.50 MIRU MOVE MOB P Wait for KDTH to Truck mats ahead of rig and cover pipeline crossings and culverts. 12:00 17:00 5.00 MIRU MOVE MOB P Exceptional rig move-Move on mats from 2B Pad to 2G Pad and set down. Page 1 of 43 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 17:00 19:00 2.00 MIRU MOVE MOB T Wait for KDTH to Truck mats ahead of rig and cover pipeline crossings and culverts. Stay set down and allow CPF 2 and other field change outs. 19:00 20:30 1.50 MIRU MOVE MOB P Exceptional rig move-Move on mats from 2G Pad to 2F Pad and attempt with no mats-road gave way-repair road w/gravel. move mats ahead of rig. 20:30 21:30 1.00 MIRU MOVE MOB P Normal rig move-Move Nordic 3 w/ mats over culverts and on low spots from 2F to CPF 2 21:30 00:00 2.50 MIRU MOVE MOB P Wait for KDTH to Truck mats ahead of rig and cover pipeline crossings and culverts. 08/14/2012 Move rig towards 2C-Pad from CPF-2-found soft spot in road-shore up and attempt to get on mats.-Call out Peak cats to assist in rig move. 00:00 01:00 1.00 MIRU MOVE MOB P Road rig from CPF-2 towards 2C cut across and found soft spot in road. 01:00 05:00 4.00 MIRU MOVE MOB T Place dunnage under move system and lay mats in front of rig. Attempt to climb up on mats.. no luck..increase dunnage under move system. Call Peak for Dozers. 05:00 07:30 2.50 MIRU MOVE MOB T PJSM w/Peak and Nordic 3 crews. Hook up to 2 Dozers and ease Nordic Rig 3 back up on mats. Release Peak Dozers.Spot mats. 07:30 15:00 7.50 MIRU MOVE MOB P Move rig towards 2C on mats to between 2C acess roads to allow for CPF-2 crewchange out and move mats around rig. 15:00 21:00 6.00 MIRU MOVE MOB P Coninue to move rig towards 2X pad access road on mats due to poor road conditions,once past 2C access road run on Spine road bearfoot to 2X pad access road and set down as of 16:30 hrs for CPF-2 change out and move mats ahead of rig 21:00 22:00 1.00 MIRU MOVE MOB P PJSM,Move rig off mats for 1 mile- road got soft. 22:00 00:00 2.00 MIRU MOVE MOB P Begin moving rig on mats. 08/15/2012 Continue to move on mats to 2Z access road. 00:00 12:00 12.00 MIRU MOVE MOB P Continue to move rig on mats towards 3H pad, 1 mile shy of reaching 2Z access road 12:00 22:00 10.00 MIRU MOVE MOB P Continue to move rig on mats to 2Z Pad access. 22:00 00:00 2.00 MIRU MOVE MOB P Truck mats ahead of rig while waiting at 2Z-Pad access. 08/16/2012 Continue to move on mats From 2Z access road. Stage all mats ahead of rig and place over culverts and pipe line crossings. Cover all known soft spots in spine road. Move towards 10-Pad Page 2 of 43 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 MIRU MOVE MOB P Continue to Truck mats ahead of rig while waiting at 2Z-Pad access. 02:00 05:00 3.00 MIRU MOVE MOB P Move rig on mats from 2Z-Pad access towards Oliktock"Y"for 1/10 mile 05:00 06:00 1.00 MIRU MOVE MOB P Pull rig off mats and run .5 miles for Oliktok"Y" 06:00 10:00 4.00 MIRU MOVE MOB X Set down at Oliktok"Y"and wait to stage emergency services at CPF3 and stand by for CPAI field change out.Truck mats ahead of rig and place in front of rig. 10:00 10:30 0.50 MIRU MOVE MOB P Move rig on mats thru KCS pad .5 mile. 10:30 16:00 5.50 MIRU MOVE MOB X Set down in front of KDTH and truck mats around rig,stage all mats ahead of rig and place over culverts, soft areas and pipe line crossings. 16:00 17:30 1.50 MIRU MOVE MOB P Move rig off mats 1 mile from KCS pad towards 1Q pad and encountered soft road, move rig up on mats. 17:30 18:30 1.00 MIRU MOVE MOB X Set down to allow CPF-3 field change out,walk around rig. 18:30 00:00 5.50 MIRU MOVE MOB P Continue to move toward 1Q pad on mats over soft area towards 1 Q-pad 08/17/2012 Continue moving from 1Q Pad towards CPF3 00:00 16:00 16.00 MIRU MOVE MOB P Continue to move toward 1Q pad on mats. 16:00 22:30 6.50 MIRU MOVE MOB X Set down at 1Q-pad, allow for field services to stage equipment,traffic to flow thru and CPF-3 crew change outs.Truck mats ahead and place in front of rig. 22:30 00:00 1.50 MIRU MOVE MOB P Move Nordic 3 on mats from 1Q Pad to.25 miles toward CPF3 08/18/2012 00:00 05:00 5.00 MIRU MOVE MOB P Continue to move towards CPF3 on mats from 1Q Pad 05:00 07:00 2.00 MIRU MOVE MOB X Shut down to allow for CPF-3 crew change outs. 07:00 17:00 10.00 MIRU MOVE MOB P Continue to move towards CPF3 on mats. 17:00 19:00 2.00 MIRU MOVE MOB X Shut down to allow for CPF-3 crew change outs. Nordic Rig 3 is approximately 1.6 miles from CPF-3 19:00 00:00 5.00 MIRU MOVE MOB P Continue to move towards CPF3 on mats. 08/19/2012 Continue moving from 1Q Pad towards CPF3. Shuffle all mats ahead of rig -allow Pioneer to time to stage logistics for 5 day road closure during rig move. 00:00 05:30 5.50 MIRU MOVE MOB P Continue to move towards CPF3 on mats. 05:30 07:30 2.00 MIRU MOVE MOB X Shut down to allow for CPF-3 crew change outs. Nordic Rig 3 is 1 mile from CPF-3. Page 3 of 43 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 07:30 17:30 10.00 MIRU MOVE MOB P Continue to move towards CPF3 on mats. 17:30 19:30 2.00 MIRU MOVE MOB X Shut down to allow for CPF-3 crew change outs. Nordic Rig 3 is.5 mile from CPF-3. 19:30 00:00 4.50 MIRU MOVE MOB P Continue to move towards CPF3 on mats. 08/20/2012 Continue moving towards CPF 3,set down and shuffle mats around rig. Allow Pioneer to time to stage logistics for 5 day road closure during rig move. Continue to move towards 3H-Pad from CPF 3. 00:00 02:30 2.50 MIRU MOVE MOB P Continue to move rig to 3 way stop at CPF-3 02:30 03:30 1.00 MIRU MOVE MOB P Move rig to back of pad at CPF-3 and set down. 03:30 12:00 8.50 MIRU MOVE MOB X Truck mats ahead of rig and a lot time for Pioneer receive services. 12:00 22:00 10.00 MIRU MOVE MOB P Move rig on mats for 6/10's of a mile to 3B"Y"and set down. 22:00 23:00 1.00 MIRU MOVE MOB P Shuffle all mats ahead of rig 23:00 00:00 1.00 MIRU MOVE MOB P Move rig on mats for 1 /10's of a mile from 3B"Y"Towards 3 Irene access road 08/21/2012 Continue to move towards 3H-Pad from 3B"Y"access. 00:00 04:00 4.00 MIRU MOVE MOB P Move rig on mats from 3B"Y"to 2/10's of mile past towards 3 H-Pad. 04:00 00:00 20.00 MIRU MOVE MOB P Continue to move towards 3H-Pad from 3B"Y"access. 08/22/2012 00:00 04:00 4.00 MIRU MOVE MOB P Continue to move towards 3H-Pad from 3B"Y"access. Estimated mileage remaining to 3H pad is 3.1 miles,slow and steady. 04:00 00:00 20.00 MIRU MOVE MOB P Continue to move towards 3H-Pad from 3B"Y"access. Double rig mats, 08/23/2012 00:00 04:00 4.00 MIRU MOVE MOB P Continue to move towards 3H-Pad from 3B"Y"access. Estimated mileage remaining to 3H pad is 2.6 miles,slow and steady. 04:00 00:00 20.00 MIRU MOVE MOB P Continue to move towards 3H-Pad from 3B"Y"access. 08/24/2012 00:00 04:00 4.00 MIRU MOVE MOB P Continue to move towards 3H-Pad from 3B"Y"access. Estimated mileage remaining to 3H pad is 2.2 miles,slow and steady. 04:00 00:00 20.00 MIRU MOVE MOB P Continue to move towards 3H-Pad from 3B"Y"access. 08/25/2012 Continue to move towards 3H-Pad Page 4 of 43 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 04:00 4.00 MIRU MOVE MOB P Continue to move towards 3H-Pad from 3B"Y"access. Estimated mileage remaining to 3H pad is 1.1 miles,slow and steady. 04:00 00:00 20.00 MIRU MOVE MOB P Continue to move towards 3H-Pad from 3A-Pad 08/26/2012 Arrive on 3H pad, Spot rig over well, Rig up all auxiliary equipment, Pull BPV and Circulate Well 00:00 04:00 4.00 MIRU MOVE MOB P Continue to move rig to 3H-pad. 04:00 10:00 6.00 MIRU MOVE MOB P Arrive on location,spot rig over well, _start to rig in all auxiliary equipment. 10:00 18:30 8.50 MIRU MOVE RURD P Accept rig @ 10:00 a.m. Start to offload fluids in pits. Continue to RU Auxiliary Equipment, Hardline 18:30 20:00 1.50 MIRU MOVE RURD P PT Surface Lines 3500 psi, OK 20:00 22:00 2.00 MIRU RPCOM PLUG P PJSM, Pull BPV with Lubricator 22:00 00:00 2.00 MIRU RPCOM CIRC P PJSM,Circulate SW down Tbg, Returns to Kill Tank at 5BPM. ICP 580, FCP 670. Initial OA Pressure 300 psi. Pumped 228 bbls and Returned 226 bbls. OA Pressure up following pump pressure. Continues to pressure a little to 750 psi after off on Pumps. Bleed Down IA to 250 psi. 08/27/2012 ND Tree, NU BOPE,Test BOPE, Pull Blanking Plug 00:00 01:00 1.00 MIRU RPCOM CIRC P Bleed Down OA-220 psi, Pump 100 bbls of 8.5 ppg SW at 5 bpm at 660 psi, returns 109 bbls,OA 290 psi 01:00 01:30 0.50 MIRU RPCOM OWFF P Monitor Well,Static 01:30 02:30 1.00 MIRU RPCOM PLUG P Set BPV, RD Hoses, BD Hardline 02:30 04:00 1.50 MIRU RPCOM NUND P ND Tree, Inspect threads, Install Blanking Plug, KO Tree 04:00 10:00 6.00 MIRU RPCOM NUND P NU Class III 11"5M BOPE. Connect Kill and Choke lines. 10:00 23:30 13.50 MIRU RPCOM BOPE P PJSM. Obtain Shell Test On Stack, 250/3500 psi. Start BOP Test 250/3500 psi w/3 1/2"Test Joint. Perform Annular test and Draw down �D test. 24 hr notice was given at 17:00 hrs on 8-25-12 and Test witness waived by Lou Grimaldi at 06:45 on 8-27-12. (Includes 4-1/2 hours of changing out HCR and rebuilding Choke Valve#8: [18:00-22:30]) System pressure=3,100 psi After closure=2000 psi 200 psi build=16 seconds Full system pressure=85 seconds 4 bottles N2=2150 psi Ave psi 23:30 00:00 0.50 MIRU RPCOM PULD P RD Test Joint and Test Hoses. Pull Blanking Plug. Page 5 of 43 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 08/28/2012 2a hr summary Pull BPV, Pull 3-1/2"Tbg from cut at 5600', Finish BOPE Test w/4"Test Joint, Start 7"Casing Scraper Run, Slip&Cut 00:00 01:30 1.50 SLOT RPCOM PULD P Continue Pulling Blanking Plug and BPV and monitor well,Static 01:30 02:30 1.00 5,600 5,570 SLOT RPCOM PULL P PJSM,MU Landing Joint, BOLDS, Pull Hanger 86k# 02:30 03:30 1.00 5,570 5,570 SLOT RPCOM CIRC P Circ 200 bbls 8.5 ppg SW at 5bpm 300 psi,down tubing, up IA to Kill Tank 03:30 04:30 1.00 5,570 5,550 SLOT RPCOM PULL P Lay Down Hanger and Landing Joint. Blow Down Top Drive and prep to pull Tbg 04:30 14:00 9.50 5,550 0 SLOT RPCOM PULL P PJSM, Pulling out of hole with 3-1/2" Tbg. Rack Back 22 Stands(2067-ft) for upcoming cement job.Continue to TOOH with 3.5"De-completion and Kick-out same. 14:00 15:30 1.50 0 0 SLOT RPCOM OWFF P Observe well for flow.Continue to Rack and Tally 4"Drill pipe. Load and Offload Tools,Changout Floor Equipmnet 15:30 19:30 4.00 0 0 SLOT WHDBO PRTS P PJSM.Set Test Plug and Test Upper and Lower pipe Rams and Annuluar w/4"Test Joint 250/3500 psi and chart same. 19:30 20:30 1.00 0 0 SLOT EVALWE PULD P PJSM. Install Wear Ring 20:30 22:00 1.50 0 19 SLOT EVALWE PULD P PJSM.MU 7"Scraper Assembly.6 1/8"Bit,7",26#Scraper, Bit Sub,Oil Jars and Cross-over. 22:00 23:00 1.00 19 950 SLOT EVALWE TRIP P TIH with 7"Scraper Assembly on Drill pipe down to—950'MD 23:00 00:00 1.00 950 950 SLOT RIGMNT SLPC P PJSM.Slip and Cut Drilling Line. (Routine) 08/29/2012 Run 7"Casing Scraper-All Clear, Perform Cement Bond Log CAST-M from 5550'to Surface. Field Pick TOC at 2474'. 00:00 01:00 1.00 950 950 SLOT RPCOM SLPC P Continue Slip and Cut 01:00 07:00 6.00 950 5,602 SLOT RPCOM TRIP P Continue RIH with BHA#1: 7" Casing Scraper down 5,602 DPMD. 07:00 08:00 1.00 5,602 5,602 SLOT RPCOM CIRC P Sit down lightly on Tubing stub at 5,602-DPMD. Up Wt 123k/Dn Wt 95K,Start CBU x2 at 8 bpm,830 psi, FCP 810 psi,Circulated 305 bbls. 08:00 08:15 0.25 5,602 5,602 SLOT RPCOM OWFF P Blow Down Top Drive and Observe well for Flow. 08:15 08:30 0.25 5,602 5,602 SLOT RPCOM SFTY P PJSM. Discuss for hazard for TOOH with Scraper and Drill Pipe. Conducted Kick while tripping drill. 08:30 12:00 3.50 5,602 19 SLOT RPCOM TRIP P TOOH with 7"Scraper Assembly from 5,602 DPMD while maintaining proper hole fill. Up Wt 123k. Call E-Line Crew. 12:00 12:30 0.50 19 0 SLOT RPCOM PULD P Lay down 7"Casing Scraper Assembly. Page 6 of 43 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 13:30 1.00 0 SLOT RPCOM RURD P PJSM. RU Dutch Riser for E-Line Operation. 13:30 14:00 0.50 0 0 SLOT RPCOM SFTY P PJSM. Discuss the Hazard for Rigging up E-line Equipment with HES and Nordic Crew. 14:00 17:30 3.50 0 0 SLOT RPCOM ELOG P MIRU and Rig Up E-line Unit and Load Tools to Rig Floor. RU Tools and PT lubricator to 500 psi. 17:30 22:30 5.00 0 0 SLOT RPCOM FLOG P RIH with CAST logging assembly on E-line and log from 5550'to Surface. 22:30 23:30 1.00 0 0 SLOT RPCOM FLOG P PJSM, RD HES Eline 23:30 00:00 0.50 0 0 SLOT RPCOM PULD P PJSM, RD Dutch Riser and Offload 08/30/2012 Run Baker Retrievamatic Test Packer and test Casing. Set Test packer at 5350'and Test Cement Plug below to 2000 psi-Good Test. Set Test Packer at 4800'and Test 7"Casing integrity above to 2500 psi-Good Test. Lay in Class G Cement Plug from 5600'to 4530'and squeeze-5 bbl into 7"Casing Leak. 00:00 01:30 1.50 0 0 SLOT RPCOM PULD P PJSM,MU BHA#2-"EA" Retrievamatic Test Packer, RIH to 5356',Set Packer COE at 5350'. 116k#up,95k#down. 01:30 04:30 3.00 0 5,356 SLOT RPCOM TRIP P RIH to 5356',Set Packer COE at 5350'. 116k#up,95k#down. 04:30 05:30 1.00 5,356 5,356 SLOT RPCOM PRTS P RU to Test Casing. Test Cement Plug and 7"Casing below Test Packet to 2000 psi and chart.Good test. 05:30 08:30 3.00 5,356 4,806 SLOT RPCOM TRIP P Pull up Hole to 4806',Set Packer COE at 4800'.Test and Chart 7" Casing to 2500 psi for 5 minutes. Perform Injectivitly test, 1/2 bpm, 1230 psi/3/4 bpm, 1210 psi/1 bpm, 1200 psi/1.5 bpm, 1250 psi/ 2 bpm, 1330 psi/2.5 bpm, 1380 psi, 3 bpm, 1440 psi. 08:30 08:45 0.25 4,806 4,806 SLOT RPCOM OWFF P Observe well flow. Blow down Top Drive. 08:45 11:30 2.75 4,806 500 SLOT RPCOM TRIP P TOOH standing back drill pipe, up wt 107k,do wt 88k. 11:30 11:45 0.25 500 500 SLOT RPCOM OWFF P Observe well flow 11:45 12:15 0.50 500 0 SLOT RPCOM TRIP P Continue OOH standing back drill pipe 12:15 13:15 1.00 0 0 SLOT RPCOM EQRP P C/O and Inspect Handling Equipment. 13:15 13:30 0.25 0 0 SLOT RPCOM SFTY P PJSM. Discuss Hazard for Making and Running Cement Assembly. 13:30 14:30 1.00 0 1,034 SLOT RPCOM TRIP P TIH with 3 1/2"Tubing with Mule Shoe on bottom on 4"Drill Pipe down to 5600'MD 14:30 15:15 0.75 1,034 1,034 SLOT RPCOM EQRP P PJSM.C/O Handling Equipment from 3 1/2"to 4"Drill Pipe. 15:15 17:30 2.25 1,034 5,600 SLOT RPCOM TRIP P Continue to RIH with Cement Assembly. 17:30 18:00 0.50 5,600 5,600 SLOT RPCOM PULD P RU Pumping Iron to Cement String. 18:00 18:30 0.50 5,600 5,600 SLOT RPCOM SFTY P Crew Change Out. PJSM with SLB Cement Pumpers and Nordic Crew. Page 7 of 43 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 19:30 1.00 5,600 5,600 SLOT RPCOM CMNT P PT Lines to 3500 psi, Pump 23 bbls of 15.8 ppg Class G Cement as per SLB Cement Program 19:30 20:30 1.00 5,600 4,996 SLOT RPCOM TRIP P POOH to 4996'. Up 105k#, Down 80k# 20:30 21:00 0.50 4,996 4,996 SLOT RPCOM CIRC P Reverse Circulate 76 bbls at 5 bpm. ICP 680, FCP 520 psi 21:00 22:00 1.00 4,996 4,996 SLOT RPCOM CMNT P PJSM with New SLB Crew, Pump 23 bbles of 15.8 ppg Class G Cement as per SLB Cememnt Program 22:00 22:30 0.50 4,996 4,365 SLOT RPCOM TRIP P POOH to 4365'. Up 96k#, Down 80k# 22:30 23:00 0.50 4,365 4,365 SLOT RPCOM CIRC P Reverse Circ 107 bbls at 5 bpm. ICP 650 psi, FCP 440 psi 23:00 00:00 1.00 4,365 4,365 SLOT RPCOM CMNT P Squeeze 5 bbls Cement @ 1500 psi. Blow Down Cwmwnt Lines 08/31/2012 Set Storm Packer in 7"Casing at 488', No Flow Test Performed-OK, ND BOP, Loosen Bolts on Casing Head-no 7"Caing growth, NU BOPs 00:00 00:30 0.50 4,365 4,524 SLOT RPCOM TRIP P RIH to 4524'to Dress off TOC 00:30 02:00 1.50 4,524 4,524 SLOT RPCOM CIRC P Reverse Circ out 90 bbls at 5 bpm 520 psi ICP,420 psi FCP 02:00 03:00 1.00 4,524 4,524 SLOT RPCOM EQRP P Change Out Floor Equipment for 3-1/2"Tubing 03:00 06:00 3.00 4,524 0 SLOT RPCOM TRIP P POOH laying down 1044'of 3-1/2" CMT Cement Stinger and KO Same 06:00 08:30 2.50 0 0 SLOT RPCOM PULD P Unload 3 1/2'TBG from Pipe Shed and Load Baker Tools to Rig Floor. 08:30 10:30 2.00 0 0 SLOT RPCOM EQRP P C/O Floor Equipment. 10:30 12:30 2.00 0 731 SLOT RPCOM TRIP P MU and RIH with 18 Jts of 4"HWDP and 6 Jts of 4 3/4"Drill Collars 12:30 13:15 0.75 731 731 SLOT RPCOM PULD P MU Baker 7"Storm Packer. 13:15 13:45 0.50 731 1,229 SLOT RPCOM TRIP P Continue In Hole with Storm Packer and 4"Drill Pipe and Set Center Element at 488'ft and bottom of Packer assembly 1229-ft 13:45 14:15 0.50 488 0 SLOT RPCOM TRIP P TOOH Standing back Drill Pipe. 14:15 14:30 0.25 0 0 SLOT RPCOM SFTY P PJSM. Discuss Hazard for High Pressure Testing. 14:30 14:45 0.25 0 0 SLOT RPCOM PRTS P Check Pumping Equipment. PT Storm Packer to 1000 psi for 5 minutes. 14:45 15:15 0.50 0 0 SLOT RPEQP1SFTY P PJSM. Discuss Hazard for Nippling Down BOPE.Observe well for flow 15:15 17:30 2.25 0 0 SLOT RPCOM NUND P ND BOPE. 17:30 21:00 3.50 0 0 SLOT RPCOM THGR P PJSM with PESC Hydratight for Casing growth. Loosen Casing Head and no Casing growth. Remove Casing Head Packoff. 21:00 00:00 3.00 0 0 SLOT RPCOM NUND P PJSM, NU BOPE 09/01/2012 Pull Storm Packer from 488',Cut 7"at 2460'with Baker Multi String Casing Cutter,Spear Casing and Pick up 30'and circulate out Arctic Pack from OA, Pull Caing Slips and prepare to pull Casing. 00:00 00:30 0.50 0 0 SLOT RPCOM NUND P Cont NU BOPs Page 8 of 43 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:30 01:45 1.25 0 0 SLOT RPCOM EQRP P PJSM Change Out Lower Pipe Rams 01:45 02:15 0.50 0 0 SLOT RPCOM PULD P PJSM, MU BHA#5 Storm Packer Ret Tool 02:15 03:00 0.75 0 1,229 SLOT RPCOM TRIP P RIH to 488', Release Packer and Monitor Well,Static 03:00 04:00 1.00 1,229 741 SLOT RPCOM TRIP P POOH with Storm Packer 04:00 05:30 1.50 741 0 SLOT RPCOM PULD P Lay Down BHA 05:30 06:00 0.50 0 0 SLOT RPCOM PULD P PJSM, MU BHA#6 Multi String Cutter 06:00 07:00 1.00 0 670 SLOT RPCOM TRIP P TIH with Cutter on Drill Pipe. Reach 670'MD and had gas breaking out of fluid. 07:00 09:30 2.50 670 670 SLOT RPCOM OWFF P Called DSO, Kuparuk Security and Pioneer Base Camp,vent gas out to kill tanks and monitor well. 09:30 10:30 1.00 670 2,500 SLOT RPCOM TRIP P Continue to TIH down to 2,474'MD, Up Wt 75k/Dn Wt 70k. Locate 7" Casing collar at 2,500'MD, PUH and Located 7"Casing Collar at 2,465' MD. 10:30 11:00 0.50 2,451 2,451 SLOT RPCOM CPBO P Check Logs and started cutting 7" CSG at 2,451'MD at 5 bpm,600 psi, Torque at 1850k 11:00 14:00 3.00 2,451 2,451 SLOT RPCOM OWFF P Seen good indication that CSG was cut, had gas break at surface,close annular bag and diverted reuturn to kill tank and allow gas bleed. 14:00 14:15 0.25 2,451 2,451 SLOT RPCOM SFTY P PJSM. Discuss Hazard for TOOH with Cutter. 14:15 16:15 2.00 2,451 0 SLOT RPCOM TRIP P TOOH with Multi-string cutter standing back drill pipe and maintaining proper hole fill. Up Wt 75k 16:15 16:30 0.25 0 0 SLOT RPCOM PULD P Lay Down and Inspect Baker Cutter Assembly. Cutter Blades Look Good. 16:30 16:45 0.25 0 15 SLOT RPCOM PULD P MU 7"Casing Spear Assembly. 16:45 17:15 0.50 15 15 SLOT RPCOM OWFF P Observe Well For Flow. 17:15 17:30 0.25 15 31 SLOT RPCOM PULL P RIH and Spear 7"Casing Stub and Confirm Casing Is free. Pull and Seen Weight Break Over at 100K. 17:30 21:30 4.00 31 31 SLOT RPCOM CIRC P PJSM With LRS and Nordic Rig Crew. PT Lines to 2000 psi. Circ 150 bbls of 70 degF Diesel at 3.5 bpm-250 psi. RD LRS. Chase with 250 bbls 8.5 ppg Sw at 3 bpm at 160 psi. Circ out Arctic Pack to Open Top Tank. Shut Down and Monitor Well for flow-Static. 21:30 22:30 1.00 31 31 SLOT RPCOM NUND P PJSM. ND BOPE 22:30 23:00 0.50 31 31 SLOT RPCOM OTHR P Remove Casing Slips 23:00 00:00 1.00 31 31 SLOT RPCOM NUND P PJSM. NU BOPE. Page 9 of 43 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 09/02/2012 24 hr Summary Pull 7"Casing from 2460',Safety Stand Down,Changeout Lower Pipe Rams 00:00 01:00 1.00 31 31 SLOT RPCOM NUND P Continue NU BOPE and test Breaks with Hydrostatic Pressure-OK 01:00 01:30 0.50 31 31 SLOT RPCOM PULD P PJSM, Lay Down Spear Assembly 01:30 02:00 0.50 31 31 SLOT RPCOM EQRP P Change out Floor Equipment to Pull Casing 02:00 05:00 3.00 31 2,420 SLOT RPCOM PULL P Pull Casing from 2420' 05:00 05:45 0.75 2,420 1,024 SLOT RPCOM PULL P At 1024', RU to Circulate Hole Volume. Pumping SW 3 bpm at 150 psi. Returns up OA to Kill Tank. 05:45 06:00 0.25 1,024 1,024 SLOT RPCOM SFTY P Spill Drill 06:00 11:00 5.00 1,024 0 SLOT RPCOM PULL P Continue Pulling Casing out of the Hole from 1024'laying same. Recover Centralizer on every other joint of casing. 11:00 21:30 10.50 0 0 SLOT RPCOM SFTY P Hold Safety Focus on Rig. 21:30 23:00 1.50 0 0 SLOT RPCOM PULD P PJSM,Offload Casing from Rig, Load Tools 23:00 00:00 1.00 0 0 SLOT RPCOM EQRP P PJSM,Open Lower Pipe Rams and Retreive Casing Centralizer. Change out Lower Rams to 2-7/8"x 5" VBRs. 09/03/2012 Change out Lower Pipe Rams to 2-7/8"x 5"VBRs and Test-Good. Test downhole Cement Plug to 500 psi- Good. Mill cement in 10-3/4"x 7"Annulus from 2462'to 2478'. POOH to test BOPE 00:00 01:00 1.00 0 0 SLOT RPCOM EQRP P Change Out Lower Rams to 2-7/8"x 5"VBRs 01:00 03:00 2.00 0 0 SLOT RPCOM PRTS P PJSM, RU and test BOPE to 250/ 3000 psi 03:00 03:30 0.50 0 0 SLOT RPCOM PRTS P Test Casing and Cement plug 500 psi and chart. Good Test. 03:30 06:30 3.00 0 0 SLOT RPCOM EQRP P Change Out Rig Tongs, Handling Equipment and Load Tools to Rig Floor. 06:30 09:30 3.00 0 176 SLOT RPCOM PULD P PJSM. Pickup and Makup BHA#6.9 5/8"Washover Pipe,Drag Shoe _ Assembly. 09:30 10:00 0.50 176 176 SLOT RPCOM CIRC P Circulate Out Arctic Pack Cap from Wellbore at 4 bpm,60 psi. 10:00 10:30 0.50 176 359 SLOT RPCOM PULD P Continue to MU Drill Collars. 10:30 15:15 4.75 359 2,351 SLOT RPCOM TRIP P Stop at 2,351'MD and Set Parameters. Up Wt 86k/Dn Wt 80k, Circulating at 4 bpm,280 psi, rotarting at 50 rpm,with 1500#of free torque. 15:15 15:45 0.50 2,351 2,351 SLOT RPCOM EQRP P Service Top Drive 15:45 16:00 0.25 2,351 2,442 SLOT RPCOM WASH P Continue in hole at same parameters washing down to the next stand. 16:00 16:15 0.25 2,442 2,450 SLOT RPCOM TRIP P Made next stand and RIH and Located top of 7"Casing stub at 2,450.05'MD while pumping at 2 bpm,60 psi. Page 10 of 43 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 16:15 18:00 1.75 2,450 2,474 SLOT RPCOM WASH P PUH 3 feet, up wt 86k.Start Washing over 7"Casing stub at 4 bpm, 240 psi with 8.5 ppg seawater, rotating at 50 rpm, and torque at 2-3k. Starting seeing cement stringer at 2,463'MD,Continue washing over 7"Casing with same parameters. 18:00 18:30 0.50 2,474 2,474 SLOT RPCOM CIRC P Pump 40 bbl Hi-Vis Biozan sweep at 7bpm at 600 psi. 18:30 19:30 1.00 2,474 2,474 SLOT RPCOM WASH P Continue Milling from 2474'to 2478', WOB 5k, Pumping SW at 6 bpm at 400 psi, Rotating at 70 rpm,torque 2k-4k. Circulate bottoms up. 19:30 21:30 2.00 2,474 2,320 SLOT RPCOM TRIP P POOH from 2478'to 2320',string pulling heavy and packing off, pump 3 more 40 bbl Hi-Vis sweeps attempting to clean hole. 21:30 00:00 2.50 2,320 1,750 SLOT RPCOM TRIP P Attempt to pull out on elevator, pulling heavy. POOH back reaming at 70 rmp,pumping 8 bpm at 400 psi. Up 85k#, Down 80k#. 09/04/2012 Finish POOH with Wash Over Assy,Test BOPE, RIH with Wash Over Assy, Mill cement in 10-3/4"x 7" Annulus from 2,478-ft to 2,485-ft. 00:00 08:00 8.00 1,750 0 SLOT RPCOM TRIP P Continue POOH back reaming at 70 rmp, pumping 8 bpm at 400 psi. RD BHA#6. 9 5/8"Washover Pipe Drag Shoe Assembly. 08:00 09:30 1.50 0 0 SLOT RPCOM PULD P PJSM. Lay Down BHA#6.Seen Minor wear on the tip of the teeth. Clear&Clean Floor. 09:30 09:45 0.25 0 0 SLOT RPCOM CIRC P PJSM. RU BOP Washing Assembly and Clean Stack. 09:45 10:15 0.50 0 0 SLOT RPCOM MPSP P Install Test Plug and Pumping Lines. 10:15 10:30 0.25 0 0 SLOT RPCOM SFTY P Conduct PJSM. Discuss Hazard for Testing BOPE. 10:30 16:30 6.00 0 0 SLOT RPCOM BOPE P Obtain Shell Test On Stack, 250/3000 psi.Start BOP Test 250/3000 psi w/4"Test Joint. Perform Annular test and Draw down test. 24 hr notice was given,witness was waived by Bob Noble at 16:00 on 9/3/2012.verbal extension was granted by John Crisp at 23:26 on 09/03/2012 due to difficulties getting 9-5/8"washover assembly out of 10-3/4"casing,test to be performed after midnight in the morning of 09/04/2012 verified by e-mail confirmation. System pressure=3,100 psi After closure=2000 psi 200 psi build=18 seconds Full system pressure=92 seconds 4 bottles N2=2100 psi. Page 11 of 43 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 18:30 2.00 0 0 SLOT RPCOM PULD P RD Test Joint and Test Hoses. Pull Blanking Plug. Change over floors. 18:30 20:30 2.00 0 133 SLOT RPCOM PULD P PJSM. Pickup and Makup BHA#9.9 5/8"Washover Pipe, Drag Shoe Assembly(dropped one 42.6-ft joint of 9-5/8"washover pipe from assembly) 20:30 22:30 2.00 133 2,437 SLOT RPCOM PULD P Continue to MU Drill Collars and TIH on 4"DP. 22:30 23:00 0.50 2,437 2,478 SLOT RPCOM TRIP P Stop at 2,437-ft and Set Parameters. Up Wt 86k/Dn Wt 80k,Circulating at 5 bpm, 190 psi, rotarting at 40 rpm,with 1500#of free torque.shut down rotation,TIH washing over 7" casing and tag TOC at 2478-ft, PUH 3-ft and set parameters 5 bpm at 220 psi, rotating at 70 rpm and 1500# torque, Up wt 80k, Dn wt 70k. 23:00 00:00 1.00 2,478 2,485 SLOT RPCOM MILL P Continue Milling from 2478-ft,WOB 5 -6k, Pumping SW at 5 bpm at 200 psi, Rotating at 70 rpm,torque 2k-4k. Circulate bottoms up. 09/05/2012 Continue working Wash Over Assy, Mill cement in 10-3/4"x 7"Annulus from 2,485-ft to 2,543-ft.TOOH with Wash Over Asembly. RIH with Multi-string Cutter 00:00 00:30 0.50 2,485 2,485 SLOT RPCOM MILL P Continue Milling from 2485-ft,WOB 5k, Pumping SW at 5 bpm at 200 psi, Rotating at 70 rpm,torque 2k-3k. Circulate bottoms up. 00:30 01:00 0.50 2,485 2,485 SLOT RPCOM CIRC P Pump 20 bbl Hi-Vis Biozan sweep at 8 bpm at 360 psi while reciprocating washover assembly. 01:00 04:00 3.00 2,485 2,495 SLOT RPCOM MILL P Continue Milling from 2485-ft to 2,495-ft,WOB 5k, Pumping SW at 5 bpm at 230 psi, Rotating at 70 rpm, torque 2k-3k. Circulate bottoms up. PUH. 04:00 04:30 0.50 2,495 2,495 SLOT RPCOM CIRC P Pump 20 bbl Hi-Vis Biozan sweep at 8 bpm at 350 psi while reciprocating washover assembly. Set assembly in slips and MU stand of 4"DP to assembly. 04:30 08:30 4.00 2,495 2,516 SLOT RPCOM MILL P Continue Milling from 2495-ft,WOB 5 -6k, Pumping SW at 6 bpm at 210 psi, Rotating at 70 rpm,torque 2k-4k. Circulate bottoms up. 08:30 09:00 0.50 2,516 2,516 SLOT RPCOM CIRC P Pump 20 bbl Hi-Vis Biozan sweep at 6 bpm at 200 psi while reciprocating washover assembly. Page 12 of 43 Time Logs Date From To Dur S.Depth E. Death Phase Code Subcode T Comment 09:00 13:00 4.00 2,516 2,543 SLOT RPCOMIMILL P Continue Milling from 2516-ft,WOB 5 -6k, Pumping SW at 6 bpm at 210 psi, Rotating at 70 rpm,torque 4k-8k.Seen small drilling break, made 3-ft(2534'-2537')top of casing collar.Work passed casing collar with 5500 torque, 80 rpm,3-5k WOB. Reached target depth of 2,543-MD. 93'of swallow with washpipe and shoe. Pumped 2-20 bbls sweeps at 9 bpm, 370 psi until clean. 13:00 13:45 0.75 2,543 2,270 SLOT RPCOM TRIP P POOH rotating and pumping off 7" Casing Stump at 60 RPM,200 psi Up Wt 75k and 2k torque. 13:45 15:30 1.75 2,270 1,670 SLOT RPCOM TRIP P Started dragging 25 to 40 k over while pooh from 2270-ft to 2214-ft. Hung up at 60k over,MUT/D PUH pumping with 350 Rotating Pressure, pressure drop dropped to 80 psi. Continue to POOH pumping every other stand. Still hanging up when not rotating or pumping. 15:30 16:00 0.50 1,670 1,670 SLOT RPCOM CIRC P Hung up at 1,670-ft with 100k over. Pumped and Rotated free.CBU at 9 bpm,210 psi. 16:00 17:30 1.50 1,670 785 SLOT RPCOM TRIP P Continue POOH from 1,670-ft MD, still having to pump and rotate to make any progress. 17:30 18:30 1.00 785 785 SLOT RPCOM CIRC P Monitor well,well out of balance, circulate to balance well 2 bpm,90 psi. 18:30 20:00 1.50 785 317 SLOT RPCOM TRIP P Continue POOH from 785-ft MD,still having to pump and rotate to make any progress. 20:00 21:00 1.00 317 96 SLOT RPCOM PULD P Stand back DC's and lay down and empty approximately 10 lbs metal shavings/cement from tandem boot baskets, lay down Bumper Sub and Jars.Change over floors.GBR ECKLES unable to break 9-5/8" Hydril 511 connection. Bring in Baker HT Tongs for 9-5/8"tools. 21:00 22:00 1.00 96 96 SLOT RPCOM EQRP T Re-assemble Baker HT Tongs to be able to grip 9-5/8"washpipe,tongs segments assembled upside down prior to arrival. 22:00 23:00 1.00 96 0 SLOT RPCOM PULD P Continue to lay down BHA#9 9-5/8" Washpipe/Drag Tooth Shoe assembly. Shoe cutting surface approximately at 10%and needs re-surfacing. Change over floors. 23:00 23:30 0.50 0 99 SLOT RPCOM PULD P PJSM-PU MU BHA#10,3-1/2" Muleshoe, 5-1/2"Multi-string Cutter, 6-1/8"Stableizer,XO Sub, 1 Stand 4"HWDP 23:30 00:00 0.50 99 1,000 SLOT RPCOM TRIP P RIH with BHA#10 on 4"DP to 1000-ft. Page 13 of 43 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 09/06/2012 24 hr Summary Run Multi-string Cutter to top of 7"Casing Stub.Clean Out 7"Casing to 2,509-ft. 00:00 01:00 1.00 1,000 2,451 SLOT RPCOM TRIP P Continue to RIH with BHA#10 on 4" DP from 1000-ft,Tag up at 2,451-ft (Top of 7"Tubing Stub)rotate and make several attempts to enter 7" casing, no luck. 01:00 03:00 2.00 2,451 99 SLOT RPCOM TRIP P PJSM-TOOH with MSC from 2,451-ft,pulled last 3 stands wet. Call out tools. 03:00 03:45 0.75 99 0 SLOT RPCOM PULD P Lay Down BHA#10, MSC blades fully extended out, break down and MSC plugged off with ball of metal shavings, muleshoe on bottom shined up. 03:45 06:00 2.25 0 144 SLOT RPCOM PULD P PJSM-PU MU BHA#11,6-1/8" Tapered Mill, Bit Sub,6-1/8"String Mill,XO,XO,8-1/2"String Mill, Tandem Boot Baskets, Bit Sub, Bumper Sub,Jars,XO, 1 std.6-1/4" DC's,XO XO 06:00 07:45 1.75 144 2,448 SLOT RPCOM TRIP P RIH with BHA#11 on 4"DP to 2,448' MD where fill or debris was tagged. 07:45 08:30 0.75 2,448 2,460 SLOT RPCOM CIRC P Up Wt 80k/Dn Wt 73k.Start Circulating at 5 bpm,90 psi at 50 RPM, 1300#torque.Clean down to 2,460'MD remove debris from 7" Casing. PUH to 2,448'MD and Circulated 20 bbl Hi-Vis Sweep at 11 bpm,350 psi while working pipe at 20 RPM with 950 free torque. 08:30 10:15 1.75 2,460 144 SLOT RPCOM TRIP P PJSM. POOH f/2,448'MD 10:15 12:00 1.75 144 0 SLOT RPCOM PULD P Lay down BHA#11. Inspect assembly and found 25 to 30 Lbs of metal shavings from boot baskets. 12:00 14:15 2.25 0 233 SLOT RPCOM PULD P PJSM. RU BHA#12.6 1/8"Tapered Mill and 6.151string mill with 1 stand of 4"HWDP betweem the Boot Basket. 14:15 15:15 1.00 233 2,451 SLOT RPCOM TRIP P Continue to RIH with C/O assembly on 4"DP down to top 7"Casing Stub at 2,451'MD. 15:15 18:30 3.25 2,451 2,502 SLOT RPCOM CIRC P Tagged debris at 2,478'MD with 5k down weight. Up Wt 80k/Dn Wt 73k, Rotating at 60 RPM with 1400# free torque,start circulating down at 8 bpm, 190 psi, rotating torque 1600#to 1800#. Rotated down to 2,478'MD to 2,505'MD, PUH to top of 7"Stub at same parameters, RIH again and sat down at 2,494'and at 10K down, continue down hole at same parameters to 2,502-ft torqueing up all the way. Noticed 5 bbl pit gain in 30 min. Pick up above 7"casing stub and CBU, Monitor well. Page 14 of 43 Time Logs Date From To Dur S. Depth E.Death Phase Code Subcode T Comment 18:30 20:00 1.50 2,440 2,505 SLOT RPCOM CIRC P Continued back down hole, Up Wt 80k/Dn Wt 75k, Rotating at 60 RPM with 1400#free torque,start circulating down at 6 bpm, 130 psi, rotating torque 1600#to 1800#. Rotated down to 2,502-ft MD,milled down to 2,505-ft MD incountered high torque and stopped making hole. 20:00 20:30 0.50 2,505 2,441 SLOT RPCOM CIRC P Pick up above 7"casing stub and CBU. 20:30 21:30 1.00 2,441 232 SLOT RPCOM TRIP P PJSM-TOOH with milling assembly. 21:30 22:00 0.50 232 0 SLOT RPCOM PULD P Lay down BHA#12,tandem boot baskets empty,tapered mill end completly void of carbide, in 5"to 6" area of taper carbide worn to 50% 22:00 22:30 0.50 0 234 SLOT RPCOM PULD P PJSM. RU BHA#13.6 1/8"Bladed Junk Mill and 6.151string mill with 1 stand of 4"HWDP betweem the Boot Basket. 22:30 00:00 1.50 234 2,503 SLOT RPCOM TRIP P Continue to RIH with C/O assembly on 4"DP down thru top of 7"Casing Stub to 2,466-ft Set parameters, Up Wt 80k/Dn Wt 75k, Rotating at 60 RPM with 1400#free torque,start circulating down at 6 bpm,500 psi, rotating torque 1400#to 1600#. Rotated down to 2,503-ft.and tag up. 09/07/2012 Clean Out 7"Casing to 2,509-ft. Pull 60-ft of 7"Casing. Prep to run Bladed Junk Mill. 00:00 04:00 4.00 2,503 2,509 SLOT RPCOM MILL P Continue with clean out of 7"casing from 2503-ft using same parameters, Up Wt 80k/Dn Wt 75k, Rotating at 60 RPM with 1400#free torque circulating down at 6 bpm,400 psi, rotating torque 1400#to 1600#. Rotated down from 2,503-ft, Clean down to 2,509-ft remove debris from 7"Casing. PUH to 2,448'MD and Circulated 20 bbl Hi-Vis Sweep at 11 bpm, 350 psi while working pipe at 20 RPM with 950 free torque. 04:00 07:00 3.00 2,448 234 SLOT RPCOM TRIP P PJSM. POOH from 2,448-ft.Confer w/town engineer. 07:00 08:30 1.50 234 0 SLOT RPCOM PULD P Lay down BHA#13. Inspect assembly, marks on bottom of mill indicates working on edge of 7" casing. Inspect Tandem boot baskets,clean&clear floor. 08:30 09:00 0.50 0 0 SLOT RPCOM SFTY P PJSM. Discuss the hazard for servicing top drive. 09:00 09:30 0.50 0 0 SLOT RPCOM SVRG P Service&Inspect top drive before RIH and pulling and jarring on 7" Casing. 09:30 09:45 0.25 0 0 SLOT RPCOM SFTY P PJSM. Discuss Hazard for Making Spear Assembly. 09:45 11:00 1.25 0 230 SLOT RPCOM PULD P MU 3 1/2"Bull Nose, ITCO Spear w/ 6.220 Grapple with 8 1/16 Stop Sub. Page 15 of 43 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 12:30 1.50 230 2,411 SLOT RPCOM TRIP P RIH to 2,411'MD, Stop and set parameters,80k up and 77k dn, pumped at 3 bpm,60 psi. 12:30 13:45 1.25 2,411 2,468 SLOT RPCOM FISH P Ran down,set down with stop sub at 2,468'md,spear nose at 2,474'md, picked up and set back down with 20k, picked and seen 2k weight down. Laid down working Joint. 13:45 15:45 2.00 2,468 230 SLOT RPCOM TRIP P PJSM.TOOH to Check and Inspect Spear. Up 83k and down 80k 15:45 16:45 1.00 230 0 SLOT RPCOM PULD P At Surface with BHA#14. Lay down and Inspect. 16:45 18:00 1.25 0 0 SLOT RPCOM PULD P Recovered a section of 7"casing. The first full joint below the orignal cut was spilt and missing about 25% of the material from the low side from the trapper mill and string mill operation. 18:00 19:30 1.50 0 0 SLOT RPCOM PULD P PJSM-RU Casing Equipment to remove fishing spear and lay down casing. Recovered 7"casing; 13.21-ft cut joint, 35.31-ft full joint, 11.80-ft twisted up joint 8-ft up inside full joint,80%of collar from 2,500-ft MD,60.32-ft OAL(see pics in folder) 19:30 20:30 1.00 0 0 SLOT RPCOM OTHR P Confer with town engineer to discuss options. 20:30 00:00 3.50 0 0 SLOT RPCOM OTHR P Prep for Junk Mill run(s)order out tools from Prudhoe,conditon pits to 35 yield point,change over pump liners 4-1/2"to 5-1/2".Clean and clear floors 09/08/2012 Prep to run Bladed Junk Mill.Time mill from 2,517-ft to 2,522-ft. Ran 6-1/8"Casing Swage to 2,538-ft. 00:00 00:30 0.50 0 0 SLOT RPCOM OTHR P Continue to wait on tools from Prudhoe,change over pump liners 4-1/2"to 5-1/2".Clean and clear floors. 00:30 03:00 2.50 0 0 SLOT RPCOM OTHR T Drilling Tool House Truck delivering tools from Prudhoe broke down, continue to clean and organize rig. finish up installing 5-1/2"liners in 2nd pump,seawater Yeild Point to 35 in pits. 03:00 04:00 1.00 0 0 SLOT RPCOM PULD P Bring in Tools. 04:00 04:15 0.25 0 0 SLOT RPCOM SFTY P PJSM. Discuss Hazard for Making Bladed Junk Mill Assembly. 04:15 05:30 1.25 0 232 SLOT RPCOM PULD P PU MU 9.75"Bladed Junk Mill,XO, XO,9.80"OD String Mill, Double Pin Sub,Tandem 8-1/2"Boot Baskets, Bit Sub, Bumper Sub,Jars,XO,2 stds.6-1/4"DC's,XO,XO. 05:30 07:00 1.50 232 2,414 SLOT RPCOM TRIP P RIH with 9-3/4"Bladed Junk MITI Assembly on 4"DP down to 2,414' MD. Up Wt 83k/Dn Wt 80k, Continue down to 2,475'MS. Page 16 of 43 . . .. _. .. .. ................... Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 10:00 3.00 2,414 2,475 SLOT RPCOM CIRC P PJSM.Test Mud Pumps.Condition well w/new pit system,8.5 ppg,90 Vis at 5 bpm,380 psi.All old fluid system taken to the open top tank. Clean Shakers and Inspect magnets. 10:00 12:00 2.00 2,475 2,519 SLOT RPCOM MILL P Continue Down and tagged top of 7" Casing at 2,517'MD, PUH and set parameters, 12 bpm,450 psi,80 RPM,with 2300#Free Torque,85k Rotating Weight,start milling down with 1k WOB with 2600 to 2800 Torque. 12:00 14:30 2.50 2,519 2,521 SLOT RPCOM MILL P Time Mill down to 2,419'MD, apply 4k WOB with 2800#to 3000#Torque at 12 bpm,480 psi,80 RPM 14:30 18:00 3.50 2,521 2,522 SLOT RPCOM MILL P Still Time Milling at 2,521'MD at 12 bpm,460 psi,80 RPM,2800 to 3000 #Torque and 4k WOB. 18:00 18:30 0.50 2,522 2,502 SLOT RPCOM CIRC P Making very little progress at 2,522-ft. PUH and monitor well 30 min. 18:30 19:45 1.25 2,502 232 SLOT RPCOM TRIP P TOOH w/Junk Mill Assembly,82k up/ 79kdo 19:45 21:00 1.25 232 0 SLOT RPCOM PULD P Lay down BHA#15, recovered several chunks of casing and approximtely 15 lbs shavings in Boot baskets, Mill indicates casing stub wobbling possibly spinning.Confer with town engineer. 21:00 21:30 0.50 0 0 SLOT RPCOM OTHR P Clean and Clear floor. Bring in tools. 21:30 21:45 0.25 0 0 SLOT RPCOM SFTY P PJSM. Discuss Hazard for Making up 6-1/8"Casing Swage Assembly. 21:45 22:15 0.50 0 574 SLOT RPCOM PULD P MU BHA#16-Bull nose,6-1/8"OD CSG Swage,XO, Bumper Sub,Jars, XO,6 stds 4"HWDP. 22:15 00:00 1.75 574 2,538 SLOT RPCOM TRIP P RIH w/BHA#16 on 4"DP to 2,525-ft, Up 80k, Dn 75k.bring on pumps 4 bpm at 210 psi,wash down with 6k to 8k SO 2,526-ft to 2,538-ft set down 10k, PU with 1k overpull. 09/09/2012 TOOH with 6-1/8"Casing Swage Assembly and 14.63-ft of 7"Casing.Slip/Cut Drill Line.Time Mill 7"casing with Bladed Junk Mill from 2,537-ft to 2,540-ft.Clean out 7"casing from 2,540-ft to 2,832-ft.TOOH w/Clean Out Assembly. 00:00 02:00 2.00 2,538 26 SLOT RPCOM TRIP P TOOH with BHA#16 from 2,538-ft _standing back DP and HWDP. 02:00 02:30 0.50 26 0 SLOT RPCOM PULD P On surface with 14.63-ft of 7"casing with 80%of collar on bottom, remove fish from tools, lay down BHA#16 02:30 03:30 1.00 0 0 SLOT RPCOM OTHR P Clean and clear floor. Bring in fresh 9-3/4"Bladed Junk Mill. 03:30 03:45 0.25 0 0 SLOT RPCOM SFTY P PJSM. Discuss Hazard for Making Bladed Junk Mill Assembly. Page 17 of 43 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 03:45 05:30 1.75 0 232 SLOT RPCOM PULD P PU MU BHA#17-9.75"Bladed Junk Mill,XO,XO,9.80"OD String Mill, Double Pin Sub,Tandem 8-1/2"Boot Baskets, Bit Sub, Bumper Sub,Jars, XO,2 stds.6-1/4"DC's,XO,XO. 05:30 06:00 0.50 232 232 SLOT RPCOM SVRG P Service Rig, change out pipe handler hose on top drive. 06:00 07:30 1.50 232 2,500 SLOT RPCOM TRIP P RIH with 9-3/4"Bladed Junk MIII Assembly on 4"DP down to 2,500-ft. 07:30 11:00 3.50 2,500 2,500 SLOT RPCOM SLPC P Hang Blocks and Slip/Cut Drill Line. 11:00 12:00 1.00 2,500 2,537 SLOT RPCOM CIRC P Wash down to 2,537-ft, PU 86k, Dn 80k set perameters 8 bpm,350 psi, 80 rpm,2600#free torque. 12:00 14:00 2.00 2,537 2,540 SLOT RPCOM MILL P Mill down from 2,537-ft 12 bpm,490 psi, 80 rpm,WOB 6k with 2.5k to 3.5k torque to 2,540-ft. 14:00 15:00 1.00 2,540 2,538 SLOT RPCOM CIRC P PU and pump 10 bbl sweep 12 bpm, 480 psi. Spot 10 bbl dry job. BDTD 15:00 17:00 2.00 2,538 232 SLOT RPCOM TRIP P PJSM-TOOH from 2,538-ft with BHA #17 17:00 18:30 1.50 232 0 SLOT RPCOM PULD P LD BHA#17,good wear marks on bottom of Junk Mill of 7"casing stub. 18:30 19:00 0.50 0 0 SLOT RPCOM OTHR P Clean and Clear Floors. 19:00 20:15 1.25 0 505 SLOT RPCOM PULD P PJSM-PU MU BHA#18-6-1/8" tappered mill,6.151 string milli,XO, 1 std 4"HWDP,XO,double pin sub, XO,tandem 8-1/2"boot baskets, bit sub, bumper sub,jars,XO,2 stds 6-14"DC's,XO,XO. 20:15 21:00 0.75 505 2,496 SLOT RPCOM TRIP P RIH w/7"casing clean out assembly on 4"DP to 2,496-ft, Up 90k, Dn 80k. 21:00 22:30 1.50 2,496 2,823 SLOT RPCOM WASH P Wash down from 2,496-ft 4 bpm,220 psi, 10 rpm w/15k free torque and encontered debris/junk at 2,550-ft, continue in hole with 2k to 3k SO to 2,823-ft. 22:30 23:00 0.50 2,823 2,823 SLOT RPCOM CIRC P Circulate Bottoms Up. 23:00 00:00 1.00 2,823 978 SLOT RPCOM TRIP P TOOH from 2,823-ft, Up 95k, Dn 80k with BHA#18 to 978-ft 09/10/2012 Pilot Mill 7"Casing from 2,540-ft to 2,584-ft. 00:00 00:30 0.50 978 505 SLOT RPCOM TRIP P Continue TOOH from 978-ft with BHA #18. 00:30 02:00 1.50 505 0 SLOT RPCOM PULD P LD BHA#18 cleanout assembly and inspect 02:00 03:00 1.00 0 0 SLOT RPCOM OTHR P Clean and clear floor.Off load and Bring in tools. 03:00 04:00 1.00 0 195 SLOT RPCOM PULD P PJSM-PU MU BHA#19-8-1/4"Pilot Mill, Bit Sub Bore for Float, lea. 6-1/4"DC,XO,8-1/2"String Mill,XO, 5ea.6-1/4"DC's,XO,XO Page 18 of 43 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 05:15 1.25 195 2,540 SLOT RPCOM TRIP P IRIH with BHA#19 8-1/4"Pilot Mill Assembly on 4"DP,tag up on top of 7"casing stub at 2,540-ft, PU set parameters 12 bpm,420 psi,80 rpm w/2.5k free torque, ROT Up 83k, Dn 78k. 05:15 10:45 5.50 2,540 2,557 SLOT RPCOM MILL P Mill down at 2,540-ft to 2,557-ft-flow line packed off-creating an 8 bbl spill into cellar and secondary containment,this was not an agency reportable spill. 10:45 13:00 2.25 2,557 2,557 SLOT RPCOM OTHR T Clean up 8 bbl viscous sea water spill in secondary containment and dis-lodge metal cuttings packed off in flow line. 13:00 19:00 6.00 2,557 2,573 SLOT RPCOM MILL P Continue to Mill down at 2,557-ft to 2,573-ft w/BHA#19(8-1/4"Pilot Mill Assembly)on 4"DP at 12 bpm, 420 psi,80 rpm w/2.5k free torque, ROT Up 83k, Dn 78k. 19:00 20:00 1.00 2,573 2,573 SLOT RPCOM OTHR P Jetting Flowline not enough, Shut down to clear flowline of metal shavings. 20:00 23:00 3.00 2,573 2,584 SLOT RPCOM MILL P Continue to Mill down at 2,573-ft to 2,584-ft w/BHA#19(8-1/4"Pilot Mill Assembly)on 4"DP at 12 bpm, 430 psi, 80 rpm w/2.5k free torque, ROT Up 83k, Dn 78k.2.5k to 3.5 k Milling TD TQ w/3k to 4k WOB, 3.5k to 4.5k Milling TD TQ w/8k to 10k WOB 23:00 00:00 1.00 2,584 2,584 SLOT RPCOM OTHR P Jetting Flowline not enough, Shut down to clear flowline of metal shavings. 09/11/2012 Pilot Mill 7"Casing from 2,584-ft t 2,589-ft.TOOH w/Pilot Mill Assembly. Preform Weekly BOPE Test. 00:00 01:30 1.50 2,584 2,584 SLOT RPCOM OTHR P Continueing clear flowline of metal shavings.found ball in buterfly valve. established good fluid movement through flowline. 01:30 04:30 3.00 2,584 2,589 SLOT RPCOM MILL P Continue to Mill down at 2,584-ft to 2,589-ft w/BHA#19(8-1/4"Pilot Mill Assembly)on 4"DP at 12 bpm, 430 psi,80 rpm w/2.5k free torque, ROT Up 83k, Dn 78k. 2.5 to 3.5 k Milling TD TQ w/3 to 4k WOB, 3.5 to 4.5k Milling TD TQ w/8 to 10k WOB.Sporatic milling due to flowline packing off so easily. 04:30 05:30 1.00 2,589 2,566 SLOT RPCOM CIRC P PU off 7"CSG stub and Circulate Bottoms up at 12 bpm at 440 psi. _ 05:30 06:30 1.00 2,566 2,566 SLOT RPCOM SVRG P Change out grabber box dies and service Top drive. 06:30 08:00 1.50 2,589 226 SLOT RPCOM TRIP P TOOH to BHA#19 at 226-ft Page 19 of 43 Time Logs Date From To Dur S.Depth E. Death Phase Code Subcode T Comment 08:00 08:30 0.50 226 226 SLOT RPCOM CIRC P MU top drive and circulate while rotating 12 bpmn at 100 psi to clean metal debris by turbulent flow thru BOP stack in preparation for cleaning BOP stack prior to Weekly BOP test. 08:30 09:30 1.00 226 0 SLOT RPCOM PULL P TOOH with BHA#19 standing back DP, DC's and lay down mill assembly. 09:30 10:30 1.00 0 SLOT RPCOM OTHR P Clean and Clear work area of non-needed fishing tools. Load string magnets for washing bop stack w/snozzelator tool. 10:30 13:00 2.50 0 0 SLOT RPCOM CIRC P PU and MU BOP wash tool and wash BOP stack while rotating and reciprocating at 4 bpm at 1,200 psi, cleaning string magnets multiple times. Break down and lay down wash tools. 13:00 13:30 0.50 0 0 SLOT WELCTL PRTS P Close blind rams and pressure test integrity of 10 3/4" and 7"casing against cement plug at 1,500 psi for 15 minutes-good test-75 psi lost then straight line on chart. Bleed off pressure and open Blind rams 13:30 16:30 3.00 0 0 SLOT WELCTL OTHR P Drain BOPE stack,set test plug, open BOP ram doors and inspect for metal shavings from 7"csg milling and wash out cavities 16:30 18:00 1.50 0 0 SLOT WELCTL BOPE P Rig up test equipment.Obtain Shell Test On Stack,250/3000 psi. 900f 18:00 00:00 6.00 0 0 SLOT WELCTL BOPE P Start weekly BOP Test 250/3000 psi w/4"and 3-1/2"Test Joints. Perform Annular test. 24 hr notice was given, witness was waived by Jeff Jones at 17:55 on 9/11/2012. 09/12/2012 Complete Weekly BOPE Test.Continue to Pilot Mill 7"Casing from 2,589-ft to 2,636-ft 00:00 01:00 1.00 0 0 SLOT WELCTL BOPE P Complete BOP Test 250/3000 psi w/ 4"and 3-1/2"Test Joints. Perform Annular test and Draw down test. System pressure=3,100 psi After closure= 1950 psi 200 psi build= 17 seconds Full system pressure=95 seconds 4 bottles N2=2100 psi. 01:00 01:30 0.50 0 0 SLOT WELCTL OTHR P PJSM-Rig down test equipment. Pull Test Plug 01:30 02:30 1.00 0 195 SLOT RPCOM PULD P PJSM-PU MU BHA#20-8-1/4"Pilot Mill(2nd run from BHA#19)Bit Sub Bore for Float, lea. 6-1/4"DC,XO, 8-1/2"String Mill,XO, 5ea. 6-1/4"DC's,XO,XO Page 20 of 43 7 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 03:45 1.25 195 2,586 SLOT RPCOM TRIP P RIH with BHA#20-8-1/4"Pilot Mill Assembly on 4"DP,tag up at 2,586-ft, PU set parameters 12 bpm, 440 psi, 85 rpm w/2.5k free torque, ROT 81k, Up 83k, Dn 78k. 03:45 06:00 2.25 2,589 2,595 SLOT RPCOM MILL P Mill down at 2,589-ft to 2,595-ft w/ BHA#20(8-1/4"Pilot Mills 2nd run) on 4"DP at 12 bpm,420 psi,85 rpm,3 to 4k Milling TD TQ w/7k WOB jetting flowline every 15 minutes. 06:00 18:00 12.00 2,595 2,618 SLOT RPCOM MILL P Mill down from 2,595-ft to 2,618-ft w/ BHA#20(8-1/4"Pilot Mills 2nd run) on 4"DP at 12 bpm,420 psi,85 rpm, 3 to 4k Milling TD TQ w/7k WOB jetting flowline continuously 18:00 00:00 6.00 2,618 2,636 SLOT RPCOM MILL P Mill down from 2,618-ft to 2,636-ft w/ BHA#20(8-1/4"Pilot Mills 2nd run) on 4"DP at 12 bpm,420 psi,85 rpm,3 to 4k Milling TD TQ w/8k WOB jetting flowline continuously 09/13/2012 Continue to Pilot Mill 7"Casing from 2,636-ft to 2,690-ft. 00:00 06:00 6.00 2,636 2,654 SLOT RPCOM MILL P Mill down from 2,636-ft to 2,654-ft w/ BHA#20(8-1/4"Pilot Mills 2nd run) on 4"DP at 504 gpm,420 psi, 85 rpm,3 to 4k Milling TD TQ w/8k WOB jetting flowline continuously. 06:00 12:30 6.50 2,654 2,670 SLOT RPCOM MILL P Mill down from 2,654-ft to 2,670-ft w/ BHA#20(8-1/4"Pilot Mills 2nd run) on 4"DP at 504 gpm,420 psi, 85 rpm, 3 to 4k Milling TD TQ w/8k WOB jetting flowline continuously, fighting to maintain fluid properties. 12:30 15:30 3.00 2,670 2,670 SLOT RPCOM COND P bring on 150 bbls of sea water visc up same. 15:30 20:00 4.50 2,670 2,687 SLOT RPCOM MILL P Mill down from 2,670-ft to 2,687-ft w/ BHA#20(8-1/4"Pilot Mills 2nd run) on 4"DP at 504 gpm,420 psi,85 rpm, 3 to 4k Milling TD TQ w/8k WOB jetting flowline continuously, still fighting to maintain fluid properties. 20:00 21:00 1.00 2,687 2,687 SLOT RPCOM CIRC P Pump 20 bbl Hi-Vis sweep 580 gpm, 550 psi. Change out shaker screens CS C. 21:00 22:00 1.00 2,687 2,687 SLOT RPCOM PRTS P Test 10-3/4"Casing integrity to 1500 n_ psi on chart,good 15 minutes. install diverter plate. • 22:00 00:00 2.00 2,687 2,690 SLOT RPCOM MILL P Mill down from 2,684-ft to 2,690-ft w/ BHA#20(8-1/4"Pilot Mills 2nd run) on 4"DP at Up 85k, Dn 80k, 546 gpm,440 psi, 90 rpm,3 to 4.5k Milling TD TQ w/8k WOB jetting flowline intermittently. 09/14/2012 Complete Pilot Milling of 7"Casing from 2,690-ft to 2,750-ft.TOOH with Pilot Mill Assembly. Page 21 of 43 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 2,690 2,710 SLOT RPCOM MILL P Mill down from 2,690-ft to 2,710-ft w/ BHA#20(8-1/4"Pilot Mills 2nd run) on 4"DP at 580 gpm,460 psi, 90 rpm, 3 to 4.5k Milling TD TQ w/8k WOB jetting flowline intermittently, pumping Hi-visc sweep every 5-ft milled. 06:00 20:30 14.50 2,710 2,750 SLOT RPCOM MILL P Mill down from 2,710-ft to 2,745-ft w/ BHA#20(8-1/4"Pilot Mills 2nd run) on 4"DP at 580 gpm,500 psi, 100 rpm,3 to 4.5k Milling TD TQ w/8k WOB jetting flowline intermittently, pumping Hi-visc sweep every 5-ft _ milled. 20:30 22:00 1.50 2,750 2,750 SLOT RPCOM CIRC P Circulate bottoms up 3X volume w/ 40 bbl weighted(11 ppg)Hi-visc sweep while reciprocating DP. 22:00 23:30 1.50 2,750 194 SLOT RPCOM TRIP P TOOH w/BHA#20 Pilot mill assembly standing back 4"DP. 23:30 00:00 0.50 194 40 SLOT RPCOM PULD P Change over floors,stand back 6-1/4"DC's. 09/15/2012 Lay Down Pilot Mill Assembly.Wash BOPE Stack. Single down 3-1/2"Tubing f/Derrick. Load, Drift and Tally 5"HWDP.Test BOPE for 5". Run 10-3/4"Scraper Assembly. 00:00 00:30 0.50 40 0 SLOT RPCOM PULD P Lay Down Pilot Mill Assembly. Pilot worn to 6.0"OD, Blades worn to 7.8125"OD,Mill Blades cut out 2.625"up from bottom. 00:30 02:30 2.00 0 0 SLOT RPCOM OTHR P Clean and Clear floor,MU up wash tool and wash BOPE Stack. Change over floors. 02:30 05:30 3.00 0 0 SLOT RPCOM TRIP P PJSM-RIH with 11 stands of 3-1/2" De-completion tubing used for cement stinger and 6 stands of 4" HWDP from derrick, Single out same. 05:30 07:00 1.50 0 0 SLOT RPCOM OTHR P PJSM-Bring in 30 jts 5"HWDP, Drift, and Tally same. 07:00 09:00 2.00 0 0 SLOT RPCOM OTHR P Wash BOP Stack of metal shavings and milling debris. 09:00 10:00 1.00 0 0 SLOT RPCOM OTHR P Attempt to set test plug and found that ram spacing would not allow for the use of 5"HWDP-lay down test plug and call out test joint. Load Baker tools in mean time. 10:00 14:00 4.00 0 0 SLOT RPCOM OTHR T 5"test joint arrived, load on rig floor. MU to test plug and RIH-found test joint to be to short for rig design, lay down same,call out for 1 joint of 5" Drill pipe. 14:00 16:00 2.00 0 0 SLOT RPCOM BOPE P Load joint on rig floor and make up to test plug, RIH and land in profile. RU test equipment and test VBR's and annular at 250/3,000 psi. RD test equipment. 16:00 20:45 4.75 0 1,179 SLOT RPCOM PULD P PU and MU BHA#21 (Whipstock gauge run and cleanout assy) RIH picking up 5"HWDP to 1,179-ft. Page 22 of 43 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:45 22:30 1.75 1,179 2,594 SLOT RPCOM PULD P Continue to RIH w/BHA#21, PU remaining 4"DP from pipe shed, Took weight, 5k at 2,594-ft. 22:30 00:00 1.50 2,594 2,690 SLOT RPCOM CIRC P Kelly up and set parameters 110k Up, 97k Dn, 110k ROT,60 rpm,420 gpm at 530 psi,3.5k free torque, RIH from 2,594-ft,4 to 4.5k TD torque,8- 10k WOB to 2,690-ft,good cement returns over shakers. 09/16/2012 Run 10-3/4"Scraper Assembly.Circulate Well. PIT 10-3/4"Casing.TOOH w/Scraper Assembly.Wash BOPE Stack. RU E-line. Run CCUGR Log. RD E-line. Prep to Run Whip stock. MU and Run 10-3/4"Whip stock 00:00 00:30 0.50 2,690 2,690 SLOT RPCOM CIRC P Circulate bottoms up 504 gpm,625 psi. 00:30 01:30 1.00 2,690 2,750 SLOT RPCOM MILL P RIH from 2,690-ft, 110k Up,97k Dn, Rot 110k,60 rpm,504 gpm at 625 psi,3.5k free torque,4 to 4.5k TD torque,8 to 10k WOB to 2,750-ft with good returns. 01:30 02:30 1.00 2,750 2,750 SLOT RPCOM CIRC P Circulate bottoms up 4X volume w/ 40 bbl weighted(11 ppg) Hi-visc sweep while reciprocating DP. 02:30 03:15 0.75 2,750 2,750 SLOT RPCOM PRTS P RU test equipment. Pressure Test 10-3/4"Casing to 1500 psi for 30 min on chart. Rd test equipment 03:15 05:00 1.75 2,750 262 SLOT RPCOM TRIP P PJSM-TOOH w/BHA#21 Scraper/ Clean Out Assembly standing back 4"DP and 5"HWDP 05:00 07:00 2.00 262 0 SLOT RPCOM PULD P Lay down BHA#21,clean magnets, empty boot baskets. 07:00 09:00 2.00 0 0 SLOT RPCOM OTHR P Clean and Clear work floor 09:00 11:00 2.00 0 0 SLOT RPCOM OTHR P With double barriers in place, Set test plug and wash BOPE at 4 bpm at 1,200 to 1,400 psi 11:00 13:00 2.00 0 0 SLOT RPCOM OTHR P Open BOP Cavity doors. Clean and inspect. Close up doors 13:00 14:00 1.00 0 0 SLOT RPCOM BOPE P Install test jt and RU test equipment and test at 250 /3,000 against f annular to cover all ram cavity doors that were opened for inspection. RD test equipment. 14:00 15:00 1.00 0 0 SLOT RPCOM OTHR P load and Install dutch riser for RU of Eline. 15:00 19:00 4.00 0 0 SLOT RPCOM PULD P Held PJSM w/eline and rig crew on RU of eline. RIH w/CCL and GR to 2,800-ft and log out of the hole for verification of 10 3/4"CSG collars and 7"Casing stub. RD Eline and pull Dutch riser. 19:00 19:30 0.50 0 0 SLOT RPCOM OTHR P Off load tools,verify 10-3/4"casing collars and prep to run whip stock. 19:30 20:00 0.50 0 0 INTRM1 WHPST SFTY P PJSm-Discuss hazards with make up and running of whip stock. 20:00 21:00 1.00 0 0 INTRM1 WHPST WPST P PU MU Milling assembly and MWD with float and UBHO sub. Page 23 of 43 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 21:00 21:30 0.50 0 0 INTRM1 WHPST WPST P Scribed mills to MWD and had 68.226 offset from mill to MWD, alligned lug in UBHO sub to scribe line. PU and set tools aside. 21:30 22:00 0.50 0 0 INTRM1 WHPST WPST P PU 25-ft of 7"spacer joint with bull nose and set in hole. PU 10-3/4" whip stock and MU to 7"casing spacer joint with Baker Lock. 22:00 23:00 1.00 0 48 INTRM1 WHPST WPST P Witness removal of shippig bolt and 3 shear bolts in anchor assembly,3 3 shear bolts left in anchor assembly at 20k shear.Set whip stock on handleing bar in rotary table, PU milling assembly and bolt mills to whip stock, bolt 45k shear, PU and remove handleing bar. 23:00 00:00 1.00 48 317 INTRM1 WHPST WPST P RIH assebeling BHA#1 to drill collars. Up wt.55k 09/17/2012 Continue to run 10-3/4"Whip stock Assembly.Orientate and Set Whip stock.Mill Window in 10-3/4"Casing from TOW @ 2,701-ft to BOW @ 2,721-ft plus 10-ft of OH to 2,731-ft. Perform LOT. EMW=14.3 ppg. POOH and lay down Milling BHA. 00:00 00:15 0.25 347 347 INTRM1 WHPST WPST P Perform shallow pulse test 504 gpm at 650 psi.good per MD Rep. 00:15 03:30 3.25 347 2,660 INTRM1 WHPST WPST P RIH w/Whip stock from 347-ft to 2,660-ft 03:30 05:00 1.50 2,660 2,750 INTRM1 WHPST WPST P Obtain do wt of 100k, Up wt of 125k with pumps off. 98k do wt and 122k up wt with pumps on. Orient whip stock face to 61°LHS and set W 5 anchor with 18k slack off pumps on. overpull 15k pumps on and shear 45k Brass shear screw w/50k slack off pumps on. Pick up off whip stock with Top at 2,701-ft and bottom of slide at 2,721-ft. 05:00 12:30 7.50 2,701 2,731 INTRM1 WHPST WPST P Held Pre-spud with crew coming on tour for early crew change day prior to milling operations. Held crew change out,gather parameters, Up 125k, Dn 100k ROT 110k, 5k free torque,80 rpm,450 gpm, 1000 psi, begin milling ahead from 2,701-ft Mill torque 6 to 10k,WOB 8 to 10k to 2,731-ft, Up wt 125k, Dn wt 100k, ROT 110k,Torque off bottom 5k. 12:30 14:00 1.50 2,731 2,696 INTRM1 WHPST WPST P Work mill through window pumps on, ROT on/off with no bobbles, reciprocate pipe pumping 35 bbl Hi-visc super sweep, PUH to 2696-ft and circulate hole clean. Page 24 of 43 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 14:00 15:00 1.00 2,696 2,696 INTRM1'WHPST WPST P Conduct LOT w/8.6 ppg fluid in hole. Pressure broke over at 710 psi in 16 strokes,continue pumping until pressure stabilizes at 610 psi. Shut down and record pressure drop for 10 LO I minutes. Lost 510 psi in 10 minutes, Bleed off and recover.7 bbls of 2.7 bbls pumped. EMW 14.3 ppg. RD test equipment. 15:00 16:30 1.50 2,696 2,696 INTRM1 WHPST WPST P PJSM-change hole over to 9.5 LSND,230 gpm,330 psi,260 bbls w/1;1 returns 16:30 17:00 0.50 2,696 2,696 INTRM1 WHPST WPST P Monitor well 30 minutes. PJSM- discussed hazards of tripping out and laying down BHA. 17:00 00:00 7.00 2,696 0 INTRM1 WHPST WPST P TOOH with Window Mill Assembly, stand back 4"DP,single out 1st 15 joints of 5"HWDP and stand back last 15 joints of 5"HWDP,single out 6-1/4"DC's, Lay down and off load Baker milling assembly. 09/18/2012 Clean and Clear rig of unneeded tools. Install test plug and wash BOPE. Open and inspect ram cavities. Conduct week) BOP test. 00:00 00:45 0.75 0 0 INTRM1 WHPST OTHR P Clean and Clear rig of unneeded tools. 00:45 01:00 0.25 0 0 INTRM1 WHDBO SFTY P Held PJSM on setting test plug, washing BOP stack and opening doors to preform cavity inspection. 01:00 09:00 8.00 0 0 INTRM1 WHDBO OTHR P Set test plug,washing BOP stack and opening doors to preform cavity inspection. Close up BOP rani cavity doors. 09:00 23:30 14.50 0 0 INTRM1 WHDBO BOPE T Shell test and found door seal leaking and replace, Continue to Conduct weekly BOP test at 250/ 3,000 psi(Test pressure different than stated on sundry do to 11"3M Casing flange). Test VBR's and annular with 4"and 5"Test joints. 24 hr Notice was given at 07:55 hrs on 9-17-12 and Right to witness was waived by Chuck Scheve at 18:40 hrs on 9-17-12. 12.5 hrs for BOP test due to door seal and 2 7/8 x 5"VBR's-change and replace packer and top seal 2 hrs McEvoy 11"Test plug seal 23:30 00:00 0.50 0 0 INTRM1 WHDBO MPSP P Pull test plug 09/19/2012 Set wear ring, PJSM, PU and MU Drlg BHA#1, Down Load LWD,Con't to RIH w/BHA,Shallow Pulse, Con't to RIH and gather Torque and Drag to 2,730-ft. Gather Parameters, Begin Directional Drlg from 2,730-ft to 2,800-ft into the Ugnu Formation, Con't to Directional drill from 2,800-FT thru the Ugnu formation and into the West sak at 2,979-ft(2,609-FT TVD) and Con't to Directional drill from 2,979-FT thru the West Sak formation and into the Tabasco formation at 3,776-ft(3,301-FT TVD)to 3,900-ft. 3,411-FT(TVD)as of Midnight. Page 25 of 43 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 0 0 INTRM1 DRILL OTHR P Install and set wear ring 11"x 9.0625"ID x 10.875"Long 01:00 01:30 0.50 0 0 INTRM1 DRILL SFTY P Held PJSM with Sperry, Nordic,and MI on PU and MU Drlg BHA#1 01:30 03:30 2.00 0 87 INTRM1 DRILL PULD P PU, MU and RIH to 87-ft. 03:30 04:30 1.00 87 87 INTRM1 DRILL OTHR P Down load LWD tool 04:30 05:15 0.75 87 637 INTRM1 DRILL PULD P Continue to PU, MU and RIH w/Drlg BHA 31 from 87-ft to 637-ft 05:15 05:45 0.50 637 637 INTRM1 DRILL DHEQ P Conduct Shallow pulse test on drlg BHA#1, Good Test, BDTD,CO Elevators 05:45 07:00 1.25 637 2,630 INTRM1 DRILL TRIP P Continue RIH from 725-2630'. Up wt 95k#down 85k# 07:00 08:00 1.00 2,630 2,630 INTRM1 DRILL EQRP P Circulate 10 bpm at 870 psi. Shakers not keeping up. Screen down to 160. 08:00 08:30 0.50 2,630 2,730 INTRM1 DRILL TRIP P Continue RIH to 2730'with Pumps off. 08:30 11:30 3.00 2,731 2,979 INTRM1 DRILL DDRL P Drill ahead from 2730'-2,979-ft MD (2,609-ft TVD)thru the Ugnu Formation. Up 103k#, Down 92k#. TQ on 2700 ft-lbs,TQ off 2300 ft-lbs. Slide and Rotate out of Window as per DD. Average WOB 5-8k#, pumping 540 gpm at 1550 psi on, 1400 psi off. 11:30 00:00 12.50 2,979 3,900 INTRM1 DRILL DDRL P Continue to drill ahead from 2,979-ft MD(2,609-ft TVD)thru the West Sak sands and into the Tabasco Formation from 3,776-ft MD(3,301-ft TVD)to 3,900-ft(3,411-ft TVD). Up 125k#, Down 96k#. TQ on 4500 ft-lbs,TQ off 2700 ft-lbs. Slide and Rotate out of Window as per DD. Average WOB 6-13k#, pumping 463 gpm at 1518 psi on, 1400 psi off. 100 RPM's Total Bit Hours 10.97 Total Jar Hours 10.97 Total Slide Hrs 2.43 Total Rotate Hours 8.54 Total Circulation Hours 4.74 09/20/2012 Continue to Directional drill from 3,900-ft to 4,300-ft+/-, CBU and change hole over to clean LSND for logging. POOH and RU E-line for Caliper and Core logging-not able to get past. 00:00 05:30 5.50 3,900 4,238 INTRM1 DRILL DDRL P Continue to drill ahead from 3,900-ft (3,411-ft ND)thru the Tabasco Formation to 4,238-ft. Up 125k#, Down 104k#. TQ on 4100 ft-lbs,TQ off 2500 ft-lbs. Slide and Rotate out of Window as per DD. Average WOB 6-13k#, pumping 463 gpm at 1518 psi on, 1400 psi off. 100 RPM's Page 26 of 43 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 06:30 1.00 4,238 4,238 INTRM1 DRILL CIRC P CBU, and condition OH section for logging purposes. New 9.5+ppg LSND down DP at 10 bpm at 1260 psi. Circulate surface to surface+10 bbls. 06:30 07:00 0.50 4,238 4,238 INTRM1 DRILL OWFF P Monitor well for flow on trip tank, static. BDTD. 07:00 11:30 4.50 4,238 30 INTRM1 DRILL TRIP P PJSM, POOH with drlg BHA#1 from 4238'(up 125k#)to 730'. Monitor well,static. Continue to POOH standing back BHA. 11:30 12:30 1.00 30 0 INTRM1 DRILL OTHR P Download data from MWD tools, continue POOH, Break off bit and stand back. 12:30 13:00 0.50 0 0 INTRM1 DRILL OTHR P Clean and Clear Rig Floor 13:00 14:00 1.00 0 0 INTRM1 EVALFN ELOG P PJSM, Load and RU Dutch Riser, Load HES Tools on the Rig. 14:00 15:00 1.00 0 0 INTRMI EVALFNSFTY P PJSM, RU Eline Tools 15:00 21:00 6.00 0 0 INTRM1 EVALFN ELOG T RIH w HES 6 Arm Caliper and sit down at 2684', reconfigure tools and RIH to 2,684-ft and set down, POOH, Reconfigure tool string to 2 bow spring centralizers w/hole finder, RIH and set down at 2,681-ft-POOH- found clays on tools. 21:00 00:00 3.00 0 0 INTRM1 EVALFN ELOG T Change tools to coring tools and @ 22:45 hrs RIH to 2,688-ft and set down. POOH and set E-line 09/21/2012 Set back E-line and RU for c/o run to 4,238-ft, CBU x 2, POOH to shoe, PO thru window to above window into 10 3/4,CBU x 2, Con't to POOH. RU E-line and run wellbore eval. logs. 00:00 01:00 1.00 0 0 INTRM1 EVALFN RURD T Set back E-line and pull dutch riser. 01:00 02:30 1.50 0 0 INTRM1 DRILL OTHR T Change over and gather components for C/O BHA#25 02:30 09:00 6.50 0 4,238 INTRM1 DRILL TRIP T PJSM on MU and RIH w/Clean out BHA#25 to 2779'and Tag. Up wt 85k#, Down 75k#, Kelly Up and Circulate 2.5 BPM at 150 psi, Rot 30 RPM , Rot Wt 80k#,Tq Off 1300 ft-lb, Max Tq On 1500 ft-lb. Work Down to 2790', Cont RIH to 4238'. Up wt 105 k#. 09:00 11:00 2.00 4,238 4,238 INTRM1 DRILL CIRC T PJSM,Circulate 12 bpm at 1140 psi, Rot 80 RPM,3 x Bottoms up 15000 stks while Recip. A lot of Clay and Cuttings over Shakers between 1-2 Bottoms Up. Pretty clean after 2 BU. Page 27 of 43 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 13:30 2.50 4,238 2,650 INTRM1 DRILL WPRT T PJSM, POOH from 4238'to 2750'. Up 85k#and Down 77k#. RIH with Pumps off down to 2840'no indication of trouble area. Pull up to to 2688'. Pump out of Hole to 2688'- 2650'at 12 bpm-840 psi. Circluate 3 x Bottoms up 10000 stks while Rot 80 RPM and Recipricating from 2688' -2650'. Clean Returns Throughout. 13:30 15:30 2.00 2,650 279 INTRM1 DRILL WPRT T POOH from 2650'. 15:30 16:00 0.50 279 0 INTRM1 DRILL PULD T POOHw/BHA#25 16:00 16:15 0.25 0 0 INTRM1 EVALFN SFTY T Held PJSM with rig crew and E-line 16:15 17:15 1.00 0 0 INTRMI EVALFN RURD T RU HES Eline and Dutch riser 17:15 18:30 1.25 0 0 INTRM1 EVALFN ELOG T RIH w/Caliper logging tools and setdown at 2,714-FT, POOH and remove centralizer from string. 18:30 20:30 2.00 0 0 INTRMI EVALFN ELOG P RIH w/Caliper logging tools to 4,240-FT and log back to inside window at 2,701-FT, POOH and Lay down tools. 20:30 00:00 3.50 0 0 INTRMI EVALFN ELOG P PJSM,MU and function tool string , RIH w/mechanical side wall coring tools to 3,853-FT and Correlate to get on depth. 09/22/2012 Continue to gather core samples with a-line. RD E-line. RIH w/DrIg BHA to 4,146-ft. 00:00 01:00 1.00 0 0 INTRM1 EVALFN ELOG P Drill selective core logs in the Tabasco Interval. Core 3 wouldn't go chamber-POOH. Recover Core from 3849'. Clean and Redress Tool. 01:00 08:30 7.50 0 0 INTRM1 EVALFN ELOG P RIH w/Mechanical Sidewall Coring Tool and recover Cores from 3785', 3783',3779', 3808', 3816'. Core Stuck in Tube. POOH. 08:30 10:45 2.25 0 0 INTRM1 EVALFN ELOG P Rig Down Primary Toolstring and RU and test Backup String. 10:45 16:00 5.25 0 0 INTRM1 EVALFN ELOG P RIH w/second Mechanical Sidewall Coring Tool and attempt to recover 11 more cores as per Geologist picks. Third attempt lost oil pressure in Tool. POOH. On Surface. No Cores Recovered. Rig Down Eline and Dutch Riser. 16:00 17:00 1.00 0 86 INTRM1 DRILL TRIP P PJSM, PU Drilling BHA#26. RIH to 86-FT 17:00 18:00 1.00 86 86 INTRM1 DRILL OTHR P Upload LWD/MWD combo 18:00 19:00 1.00 86 637 INTRM1 DRILL TRIP P Continue to RIH f/86-FT to 637-FT BHA Depth. 19:00 20:00 1.00 637 637 INTRM1 DRILL OTHR P Shallow Pulse test LWD/MWD - Good Test. Page 28 of 43 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 20:00 21:30 1.50 637 2,534 INTRM1 DRILL TRIP P Trip in hole to 2,534-FT,Gather parameters: 95 Up wt,80 Dn wt. w/ 9.6 ppg MW, Pump#1 20 stks @ 160 Psi,40 stks @ 210 Psi. Pump #2 20 stks @ 150 Psi,40 stks @ 210 Psi. 21:30 00:00 2.50 2,534 4,146 INTRM1 DRILL TRIP P Continue to RIH f/2,534-FT,thru window at 2,701-FT and take 5k slack off wt @ 2,775-FT. Continue to RIH to 4,146-FT as of Midnight. 09/23/2012 Continue to RIH to 4,238-ft, CBU gather Parameters and Begin drlg new 8.75"hole to TD.to 5,662-ft. 00:00 00:30 0.50 4,146 4,235 INTRM1 DRILL TRIP P Continue to RIH f/4,146-FT to 4,235-Ft 00:30 01:30 1.00 4,235 4,238 INTRM1 DRILL CIRC P CBU x 1.5,Gather Parameters: With pumps on 125k Up wt,98k Dn wt, ROT wt 110k Circ at 465 gpm @ 1,550 Psi. SPR's Pump#1 @ 24 spm @ 190 Psi,48 spm @ 260 Psi Pump#2 @ 24 spm @ 180 Psi,48 spm @ 260 Psi Parameters w/Pumps off-127k Up wt, 103k Dn wt, ROT wt 114k 01:30 16:30 15.00 4,238 5,239 INTRM1 DRILL DRLG P Continue to drilling ahead Sliding and Rotating as per DD from 4,238-FT MD(3,755-ft ND)to 5239-ft MD (4,596-ft TVD). Up 148k#, Down 114k#. TQ 4800 ft-lbs. Average WOB 10k#, pumping 550 gpm at 2550 psi on,2350 psi off. 105 RPM's. SPR's at 5285'with 9.6 ppg. Pump#1 @ 20 spm @ 220 Psi,40 spm @ 310 Psi Pump#2 @ 20 spm @ 220 Psi,40 spm @ 300 Psi 16:30 00:00 7.50 5,239 5,662 INTRM1 DRILL DDRL P Continue Drilling from 5,239-FT MD (4,596-FT ND)to 5,662-FT MD (4,970-FT ND) 153k Up wt, 115k Dn wt 127k ROT wt. Circulating at 550 gpm at 2,680 psi w/4,300 ft/lbs On Bottom Tq and 3,500 ft/lbs Off Bottom Tq.at 105 Rpm's.As of midnight. SPR's at 5,471-Ft with 9.6 ppg. Pump#1 @ 25 spm @ 280 Psi, 50 spm @ 400 Psi Pump#2 @ 25 spm @ 280 Psi, 50 spm @ 400 Psi 09/24/2012 Pump wt sweep and circ Surf to Surf. Monitor well -static. POOH to 4,842-ft to 2,688-ft. Monitor well. S&C drill line. RIH and con't to drill from 5,662-ft to 5,854-FT as of midnight 00:00 02:00 2.00 5,662 5,662 INTRM1 DRILL CIRC P Pump a 40 bbl 12 ppg weighted sweep and circulate surface to surface @ 500 gpm at 2,180 psi. Page 29 of 43 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 02:00 03:00 1.00 5,662 5,662 INTRM1 DRILL OWFF P Monitor well for flow on trip tank for 30 minutes-static. 03:00 04:00 1.00 5,662 4,713 INTRM1 DRILL TRIP P POOH on elevators to 4,842-ft and began pulling over by 10 to 20k to 4,685-ft. 04:00 09:30 5.50 4,713 2,914 INTRM1 DRILL REAM P Continue to POOH back reaming up from 4713'. Up 148k#, Dn 110 k#. Pumping 500 gpm at 2050 psi at 50 rpm. Heavy Returns 09:30 10:00 0.50 2,914 2,819 INTRM1 DRILL CIRC P PJSM,Circulate 1.5 x BU Rotating and Reciprocating from 2914-2819'. Clean Returns. Up 90k#,do 80k#. Monitor Well Static. SPR's at 2828'with 9.9 ppg. Pump#1 @ 20 spm @ 190 Psi,40 spm @ 250 Psi Pump#2 @ 20 spm @ 190 Psi,40 spm @ 260 Psi 10:00 10:30 0.50 2,819 2,630 INTRM1 DRILL TRIP P Orient Motor 60 deg left. POOH from 2819'to 2630' 10:30 11:00 0.50 2,630 2,630 INTRM1 DRILL OTHR P Clean and Clear Rig Floor. 11:00 14:30 3.50 2,630 2,630 INTRM1 RIGMNT SLPC P PJSM, BDTD, Slip and Cut Drilling Line,Service Top Drive 14:30 14:45 0.25 2,630 2,630 INTRM1 DRILL SFTY P PJSM on RIH thru window and back to 5,662-FT 14:45 15:15 0.50 2,630 2,688 INTRM1 DRILL TRIP P RIH from 2630'-2688'and verify orientation of Motor through Window 15:15 18:30 3.25 2,688 5,595 INTRMI DRILL TRIP P Continue to RIH to 5,330-FT,seen sticky interval to 5,362-FT taking 10 SO wt. Continue to RIH to 5,595-FT 18:30 20:30 2.00 5,595 5,595 INTRMI DRILL CIRC P Circulate surface to surface changing hole over to 9.8 ppg LSND drlg fluid at 500 gpm at 2,200 psi. 20:30 00:00 3.50 5,662 5,854 INTRM1 DRILL DDRL P Continue in hole to 5,662-FT and begin sliding at 5,662-FT to 5,695-Ft w/5k WOB at 550 gpm at 2,750 psi, Rotary drill to 5,758-FT w/10 to 15K WOB at 550 gpm at 2,750 psi,then sliding at 5,758-FT to 5,781-Ft w/5k WOB at 550 gpm at 2,750 psi at 10° LHS,then Rotary drill to 5,854-FT w/ 10 to 15K WOB at 550 gpm at 2,750 psi. 09/25/2012 Continue to Dir. Drill f/5,854-FT to 6,896-FT. 00:00 06:00 6.00 5,855 6,040 INTRM1 DRILL DDRL P Continue to slide at 5,855-FT to 5,890-Ft w/5k WOB at 550 gpm at 2,750 psi, Rotary drill to 5,890-FT to 5,945-FT w/10 to 15K WOB at 550 gpm at 2,750 psi,then sliding at 5,945-FT to 5,990-Ft w/5k WOB at 550 gpm at 2,750 psi,then Rotary drill to 5,990-FT to 6,040-FT w/10 to 15K WOB at 550 gpm at 2,750 psi. Page 30 of 43 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 09:00 3.00 6,040 6,163 INTRM1 DRILL DDRL P Continue to slide and rotating per DD. At 6163'sliding at-45 deg. WOB 10k#at 550 gpm at 2694 psi. Torque 159 ft-lbs, ROP 28 fph 09:00 12:00 3.00 6,163 6,297 INTRM1 DRILL DDRL P Continue to slide and rotating per DD. At 6297'sliding at-45 deg. WOB 10k#at 550 gpm at 2727 psi. Torque 100 ft-lbs, ROP 68 fph 12:00 15:00 3.00 6,297 6,398 INTRM1 DRILL DDRL P Continue to slide and rotating per DD. At 6398'sliding at 0 deg. WOB 10k#at 550 gpm at 2662 psi. Torque 200 ft-lbs, ROP 56 fph 15:00 18:00 3.00 6,398 6,603 INTRM1 DRILL DDRL P Continue to slide and rotating per DD. At 6603'rotating. WOB 10k# at 525 gpm at 2722 psi. 100 RPS at Torque 5695 ft-lbs, ROP 150 fph 18:00 21:00 3.00 6,603 6,750 INTRM1 DRILL DDRL P Slide from 6,705 to 6,732'.Continue Rotating per DD.WOB 10k to 12k# at 12.7 bpm, rotating at 133 RPM, 2,806 SPP, 10.0 PPG in 10.0 PPG out,VIS 56 in and 58 out, ROP 133 fph,Top Drive Torque 5600#. 21:00 00:00 3.00 6,750 6,895 INTRM1 DRILL DDRL P Slide from 6,827'to 6,860'.Continue Rotating per DD.WOB 10k, 12.3 BPM, ROP 166 fph,2,472 SPP, RPM 103,Top Drive Torque 5900#, 10.0 PPG in and out. Up Wt 165k/ Dn Wt 120K/Rotating Wt 140k 09/26/2012 Called TD at 6,895-ft.CBU x4 while rotating and reciprocating f/6,965-ft to 6,600-ft.TOOH to 2,912-ft and CBU x 3.5 while rotating and reciprocating f/2912 to 2817-ft.TIH to TD at 6,965-ft and CBU x 4 at 12 bpm, 2415 SPP,continue rotating and reciprocating until returns where clean. Start TOOH to surface standing back Drill Pipe. 00:00 00:45 0.75 6,895 6,965 INTRM1 DRILL DDRL P Drilling ahead from 6,895-ft at 12.5 BPM, rotating at 105 RPM,2,758 SPP, 10k WOB,Top Drive Torque 5,875#. Up Wt 165k/Dn Wt 118k/ Rotating Wt 140k 00:45 01:00 0.25 6,965 6,965 INTRM1 DRILL DDRL P TD Called @ 6,965-ft. Backreem up to two stands, RIH to 6,965-ft and 111 shoot survey while circulating at 204 i/ SPM,2,350 SPP. 01:00 05:00 4.00 6,965 6,600 INTRM1 DRILL CIRC P Circulating hole clean at 12.0 BPM while rotating at 50 RPM,2,330 SPP,While Reciprocating Drill Pipe slowly.CBU x 4 racking back one stand after each bottoms up. 05:00 05:15 0.25 6,600 6,600 INTRM1 DRILL OWFF P Observe well for Flow 05:15 11:15 6.00 6,600 2,912 INTRM1 DRILL TRIP P PJSM,TOOH from 6610'. Up 165k#, dwn 120 k#to 2912'. Up 103k#,dwn 85k#. 11:15 13:00 1.75 2,912 2,912 INTRM1 DRILL CIRC P Circulate 3.5 x bttms up at 11.5 bpm at 1590 psi while Rotating and Recipricating from 2912'to 2817' 13:00 13:15 0.25 2,912 2,912 INTRM1 DRILL OWFF P Blow Down Top Drive, Monitor Well, Static 13:15 17:00 3.75 2,912 6,896 INTRM1DRILL TRIP P PJSM. TIH from 2912'to 6,896-ft. Page 31 of 43 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 17:00 21:30 4.50 6,965 6,600 INTRM1 DRILL CIRC P Kelly Up, Up Wt 163k/Dn Wt 115k, RIH to TD at 6,965. Pump 30 bbl High-Vis Sweep at 12.0 BPM,2415 SPP while Rotating at 50 RPM and Recipricating,continue to CBU x 4 standing back 1 stands after each BU. Returns To Shakers are Clean and fluid from solids control van is good. Seeing 10.0 PPG in/out. 21:30 22:00 0.50 6,600 6,600 INTRM1 DRILL OWFF P Shut Down Mud Pumps and BD Top Drive. Monitor Well For Flow. No Gain or Lost seen. 22:00 22:15 0.25 6,600 6,600 INTRM1 DRILL SFTY P Hold PJSM and Discuss hazard for TOOH with Drill Pipe and Drilling Assembly. 22:15 00:00 1.75 6,600 5,170 INTRM1 DRILL TRIP P TOOH from 6,600-ft Standing back Drill Pipe and maintaining proper hole full while POOH. Up Wt 165k 09/27/2012 TOOH and LID Drilling Assembly after Wellbore was condition. Download Data from LWD Tools. Set Storm packer and test. Set Test plug and C/O Lower Ram's to 7"and Test and Chart Same. Pull Test Plug. 00:00 03:15 3.25 5,170 2,687 INTRM1 DRILL TRIP P Continue to TOOH from 5,170-ft Standing back Drill Pipe and maintaining proper hole fill while POOH. Orient up thru window. 03:15 04:00 0.75 2,687 2,635 INTRM1 DRILL CIRC P Once above Window into 10 3/4" surface Casing,CBU at 11.5 BPM, 1423 SPP while Recipricating f/ 2,687'to 2,635'Up Wt 105k/Dn Wt 85k, no problem pulling thru window. Clean Fluid seen at shaker. 04:00 06:00 2.00 2,635 700 INTRM1 DRILL TRIP P Continue to TOOH from 2,635-ft Standing back Drill Pipe and maintaining proper hole fill while POOH. Up Wt 105k. Perform Torque and Drag every 10 stands. 06:00 11:00 5.00 700 0 INTRM1 DRILL PULD P Stand Back HWDP and Collars, Download LWD Tools, LD BHA 11:00 13:30 2.50 0 INTRM1 DRILL PULD P Clear and Clean Floor. Offload and Load Tools. 13:30 15:30 2.00 INTRM1 DRILL PLUG P Load Storm Packer. PJSM, Drain and Clean Stack, Pull Wear Ring 15:30 17:30 2.00 0 655 INTRM1 WHDBO MPSP P MU BHA#27, 10 3/4"Storm Packer. RIH with 5 Stands of HWDP& 1 Stand of Collars and Set Center Element of Storm Packer at 73-ft. TOOH and L/D Running Tool. 17:30 18:00 0.50 73 0 INTRM1 WHDBO PRTS P PJSM.Test Storm Packer to 200 psi for 10 minutes. 18:00 18:15 0.25 0 0 INTRM1 WHDBO MPSP P PJSM. Install Test Plug 18:15 20:00 1.75 0 0 INTRM1 WHDBO.OTHR P PJSM.Suck Out Stack.Change Out Lower Set of Ram's from VBR's to 7" Rams. Page 32 of 43 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 23:45 3.75 0 0 INTRM1 WHDBO BOPE P RU Test Equipment.Shale test BOP stack, Lower section w/7"Rams pp installed and Annular to 250/3000 psi ` Oi and Chart Same. RD Testing Equipment. 23:45 00:00 0.25 0 0 INTRM1 WHDBO SFTY P PJSM on MU Pulling Assembly to Retreive Storm packer. 09/28/2012 Latched&Pulled 10 3/4"Storm Packer and L/D same, continue OOH and LID and off loaded 5"HWDP and collars. MU Halliburton float shoe and float collar assembly and continue in hole with 7"Casing. 00:00 00:30 0.50 0 73 INTRM1 WHDBO PULD P MU Pulling Assembly to Retrieve Storm Packer. 00:30 02:00 1.50 73 0 INTRM1 WHDBO MPSP P Latch&Release Storm Packer and Pull to Rig Floor and LID Same. 02:00 04:00 2.00 655 0 INTRM1 WHDBO TRIP P Continue OOH Laying Down Drill Collars and HWDP. 04:00 04:30 0.50 0 0 INTRMI WHDBO SFTY P PJSM on Changing Out handling Equipment. 04:30 06:30 2.00 0 0 INTRM1 RPCOM PULD P Clean&Clear Floor. Change Out Handling Equipment to run 7" Casing. 06:30 08:00 1.50 0 0 INTRM1 RPCOM SFTY P PJSM 08:00 13:30 5.50 0 2,611 INTRM1 RPCOM RNCS P MU Shoetrack with Bakerlock and RIH 7"Casing to 2611' 13:30 14:30 1.00 2,611 2,611 INTRM1 RPCOM CIRC P RU Circulating Equipment,Circ 6 bpm @ 240 psi while Reciprocating. Up 90k#,down 85k#. 14:30 18:00 3.50 2,611 4,795 INTRMI RPCOM RNCS P Continue RIH with 7"Casing. 18:00 19:30 1.50 4,795 4,795 INTRM1 RPCOM CIRC P RU Circulating Equipment, Circ 6 bpm @ 380 psi while Reciprocating. Up 90k#,down 85k#. 19:30 23:00 3.50 4,795 6,905 INTRM1 RPCOM RNCS P Continue RIH with 7"Casing while recording PU&SO weight every 10 joints. 23:00 00:00 1.00 6,905 6,915 INTRM1 RPCOM CIRC P MU head pin on Joint 159 and circulate 7"CSG down to bottom for space of of cementing head. Up Wt 230k/Dn Wt 140k. Circulating Pressure at 1500 psi at 3 bpm, Continue to Reciprocate to get Casing on depth. 09/29/2012 Reach Desired Depth of 6,921-ft with 7"Casing. Batch up and perform 2 stage cement job. First stage was 50 bbls of 15.8 ppg class G with Gasblok and the second stage was 33 bbls of 12.5 ppg Litecrete slurry. Installed 7"Casing Hangers,Packoff and Tubing spool adapter and tested same. 00:00 01:15 1.25 6,915 6,950 INTRM1 RPCOMICIRC P Continue to circulate 7"CSG down to bottom for space of cementing head. Up Wt 230k/Dn Wt 140k. Circulating Pressure at 1500 psi at 3 bpm,Continue to Reciprocate to get Casing on depth. 01:15 02:30 1.25 6,950 6,950 INTRM1 RPCOM PULD P Able to Reach TD with 7"Casing Completion. PJSM. Swap out bails for cement head. Install Cement Head Page 33 of 43 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 02:30 04:15 1.75 6,950 6,950 INTRM1 RPCOM CIRC P Continue to Circulate hole and thin mud properties to Condition Mud while reciprocating casing before starting cementing operation at 2 bpm,200 psi. MIRU SLB and Batch 45 bbls of 11.0 PPG Mudpush. 04:15 04:30 0.25 6,950 6,950 INTRM1 CEMEN'SFTY P PJSM. Discuss Hazard and Review Pumping Procedure for Pumping Cement. 04:30 07:30 3.00 6,950 6,950 INTRM1 CEMEN'PUCM P PT SLB Treating Iron to 250/4200 psi.Start Pumping Stage#1 follow Pumping Procedure while slowly reciprocating. Pump 35 bbls of CW-100 at 4 bpm,390 psi,swap G M� over and pump 38 bbls of 11.0 ppg Mudpush at 4 bpm,360 psi. Shut down and launch wiper plug. Pump 2 bbls of 11.0 ppg mudpush at 4 bpm, 455 psi.Shut down and load top plug. Start pumping 50 bbls. Gasblok cement slurry at 4 bpm,635 psi.Shut down and launch top plug. Pump 10 bbls of water from SLB unit at 4 bpm, 140 psi..Swap to Rig mud pump and displace Slurry with 253 bbls 10.0 ppg active mud at 4 bpm, Initial pressure at 135.Slow rate to 2.5 bpm at 630 psi and seen Plug bump at 253 blls away at 1200 psi. 07:30 07:45 0.25 6,950 6,950 INTRM1 CEMEN'OTHR P Hold pressure on plug for 5 minutes. Bleed down pressure and check floats and load closing plug into cement head. 07:45 09:00 1.25 6,950 6,950 INTRM1 CEMEN"CIRC P Pressure up on casing to+/-3160 psi to shift open the stage collar. Establish circulating through stage collar and CBU to condition 8 3/4"x 7"annulus. 09:00 10:15 1.25 6,950 6,950 INTRM1 CEMEN-PUCM P Start Pumping Stage#2 follow GMT Pumping Procedure. Pump 20 bbls of CW-100 at 4 bpm, 140 psi,swap n �� over and pump 30 bbls of 11.0 ppg J Mudpush at 4 bpm,200 psi. Start pumping 33.2 bbls of 12.5 ppg Litecrete cement slurry at 4 bpm, 380 psi. Shut down and launch top plug. Pump 10 bbls of water from SLB unit at 5 bpm,200 psi..Swap to Rig mud pump and displace Slurry with 144.2 bbls 10.0 ppg active mud at 4 bpm, Initial pressure at 150 psi. Slow rate to 2.5 bpm and see Cement Retainer close at 1360 psi. Bleed back to zero and verify Tool is closed. No Flow. 10:15 12:00 1.75 6,950 6,950 INTRM1 CEMEN"PULD P RD SLB Cementers Page 34 of 43 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 12:00 14:30 2.50 6,950 6,950 INTRM1 RPCOM NUND P PJSM,Monitor Well-Static, ND BOPs 14:30 15:30 1.00 6,950 0 INTRM1 RPCOM NUND P PJSM,Set 7"Casing in Slips with 135k#on Weight Indicator, RILDS 15:30 17:00 1.50 0 0 INTRM1 RPCOM OTHR P RU Wachs Cutter,Cut 7"Casing, LD 29.63'of 7"Casing 17:00 23:45 6.75 0 0 INTRM1 RPCOM NUND P PJSM. N/D BOPE and set back on stump. Nipple Down 3k x 5k Cross Over Adapter. Install Pack-off and Nipple Up Tubing Head. 23:45 00:00 0.25 0 0 INTRMI RPCOM PRTS P PJSM. Pressure Tested Pack-off to 3000 psi for 10 Minutes. 09/30/2012 Fitted BOPE w/VBR's in Lower section. Peform SIS-NOV Derrick Inspection. Perform Bi-Weekly BOP Test. Perform LOT on the 10-3/4"x 7"casing annulus. 00:00 03:00 3.00 0 0 INTRM1 WHDBO NUND P NU BOPE. 03:00 06:00 3.00 0 0 INTRM1 WHDBO NUND P C/O Lower Rams from 7"to VBR's and RU Riser. 06:00 12:30 6.50 0 0 INTRM1 RPCOM SFTY P Perform SIS-NOV Derrick Inspection. Load Tubing 12:30 21:30 9.00 0 0 INTRMI WHDBO BOPE P Perform bi-weekly BOP Test at 250/ 3,500 psi. Test VBR's and annular with 3-1/2",4"and 4-1/2"Test joints. 41? 24 hr Notice was given at 07:55 hrs on 9-28-12 and right to witness was waived by John Crisp at 12:20 hrs on 9-30-12. Performed Draw Down Test. RD Testing Equipment and Pull Test Plug 21:30 22:00 0.50 0 0 INTRM1 EVALWE SFTY P PJSM. Discuss Hazard for Testing Annulus. 22:00 00:00 2.00 0 0 INTRM1 EVALWE LOT P RU Circulating Equipment and Perform LOT for Freeze Protecting Annulus. 10/01/2012 Perform LOT on 10-3/4"x 7"and freeze protected same with diesel down to 2000-ft. RIH 6-1/8"Drilling Assembly down to TOC at 3955-ft, Drill down and Tagged plug at 3,983-ft,Wash and Drill down to 6,767-ft. Perform Casing Integrity test to 3500 psi for 30 minutes.Continue to Wash and Drill down to 6,921-ft where drilling assembly got struck at the Casing shoe. Unable to circulate or PUH or RIH, but able to get Jarring action with Jar's.Start Jarring on Drilling assembly. 00:00 02:15 2.25 0 0 INTRM1 RPCOM CIRC P RU Circulating Equipment and Pump 200 bbls of Fresh Water after pumping 4 bbl of 10.0 ppg Mud for LOT Test. Initial Pump Rate&Pump Pressure for Fresh Water. (1 bpm at 1140 psi)Final Pump Rate& Pressure(3 bpm at 920 psi) Pressure after pumping fresh water, 520 psi. 02:15 02:30 0.25 0 0 INTRM1 RPCOM SFTY P PJSM with LRS. Discuss Hazard for High Pressure Pumping. Page 35 of 43 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 03:30 1.00 0 0 INTRM1 RPCOM FRZP P Start Freeze Protecting 10-3/4"x 7" Casing anulus with 100 bbls of Diesel down to 2000-ft with LRS. Initial Pump rate 1 bpm at 500 psi, increase pump rate at 2 bpm, 1050 psi,final pump rate 2 bpm, 1100 psi. Pressure after shut down 750 psi. RDMO LRS 03:30 04:00 0.50 0 0 PROD1 DRILL PULD P PJSM. Install Wear Bushing. 04:00 04:15 0.25 0 0 PROD1 DRILL SFTY P PJSM with all party involved in MU Drilling BHA. 04:15 10:30 6.25 0 660 PROD1 DRILL PULD P PJSM,MU 6-1/8"Drilling Assembly, Upload LWD,Shallow Pulse test- good. Load Nuke Sources, BDTD, Contiunue MU BHA 10:30 13:00 2.50 660 3,885 PROD1 DRILL TRIP P Continue RIH to 3885'. Fill Pipe, Up 105k#,dwn 85k# 13:00 15:30 2.50 3,885 4,070 PROD1 DRILL MILL P Kelly Up,Wash down at 2.5 bpm at 600 psi,Tag Contaminated Cement at 3955', Drill through and tag Plug at 3983', Drill Cementer at 5 bpm at 1280 psi,40 rpm, 3000-3500 ft-lb, 2-5 k#WOB to 3985'. Wash down to 4070'. 15:30 17:00 1.50 4,070 6,730 PROD1 DRILL TRIP P RIH to 6730',Wash Down to Cement Tag at 6767'. Up 165k#, Down 106k#. 17:00 18:00 1.00 6,730 6,730 PROD1 DRILL PRTS P PJSM, Perform Casing Integrity Test, 3500 psi for 30 minutes and Chart. 18:00 18:30 0.50 6,730 6,730 PROD1 DRILL SFTY P Crew C/O and PJSM before drilling ahead. 18:30 20:30 2.00 6,730 6,826 PROD1 CEMEN"DRLG P Continue down hole drilling cement inside 7"casing f/6,730-ft with 10.0 PPG mud at 5 bpm, 1670 psi rotating at 41 RPM,with 2-3k WOB, Up&Dn weight w/pumps off 165k/ 106k. Up&Dn weight w/pumps at 2.5 bpm, 155k/102k. 20:30 21:30 1.00 6,826 6,921 PROD1 CEMEN"DRLG P Drill down to 6,826-ft. Reciprocate up hole rotating and circulating at 51 RPM. PU another stand and continue to drill out cement at 5 bpm, 1620 SPP, rotating at 51 RPM with 4-5k WOB f/6826-ft 21:30 22:45 1.25 6,921 6,921 PROD1 CEMEN"DRLG P Drill down to 6,921-ft. Reciprocate up hole rotating and circulating at 51 RPM. PU another stand and continue to drill out cement at 5 bpm, 1620 SPP, rotating at 53 RPM with 5-6k WOB f/6921-ft Page 36 of 43 7 Time Logs Date From To Dur S. Depth E.Death Phase Code Subcode T Comment 22:45 00:00 1.25 6,921 6,921 PROD1 DRILL JAR T Lost circulation to drilling assembly once Bits reached 6,921-ft and SPP LOS increased to 2200 psi,shut down mud pump and try to PUH. Let Jars fire at 180k. Bit is right at the shoe. Continue to try and circulate and work drill pipe up and down while jarring. 10/02/2012 Freed struck Drilling Assembly. Drill out cement inside 7"casing and 20-ft of new formation. Condition Mud and Wellbore to 10.5 PPG MUD. Perform formation integrity test up to 16.0 PPG. Continue with Drilling Operation down to 7,310-ft as of Midnight. 00:00 01:30 1.50 6,921 6,858 PROD1 DRILL JAR T Continue Jarring operation to free struck Drilling Assembly.After 22 Jar Hits up and 6 Jar hits down,we where able to move drilling assembly 01:30 02:45 1.25 6,858 6,858 PROD1 DRILL CIRC P CBU while Reciprocate and rotating at 30 RPM and circulating at 5 BPM, with 1,340 SPP. 02:45 03:45 1.00 6,858 6,858 PROD1 DRILL SVRG P PJSM. Perform Derrick Inspection after Jarring Operation to free Drilling String. 03:45 05:30 1.75 6,931 6,965 PROD1 CEMEN"DRLG P Back to Normal Drilling Operation. RIH down to Casing shoe and continue to Drill out into formation 20-ft. Drilling Parameters,81 SPM at 1428 SPP, Rotating at 45 RPM, Free Rotating Weight 123k,4-5k WOB. 05:30 06:00 0.50 6,965 6,985 PROD1 DRILL CIRC P Drilled Down to 6,985-ft/5,984 TVD. 10.0 ppg drilling fluid contaminated CBU while Reciprocate and rotating at 50 RPM and circulating at 6 BPM, with 2,195 SPP. 06:00 10:00 4.00 6,985 6,985 PROD1 DRILL CIRC P CBU while Reciprocate and rotating at 50 RPM and circulating at 5 BPM, with 1,525 SPP. 10:00 14:30 4.50 6,985 6,985 PROD1 DRILL OWFF T PU above shoe and monitor well while waiting on mud conditioning to 10.5 ppg,transport pump down. 14:30 16:30 2.00 6,985 6,985 PROD1 DRILL CIRC P PJSM-Start circulating out hole from 10.0 ppg and condition to 10.5 PPG while reciprocating and circulating at 5 BPM with 1300 SPP,260 bbls with 10.5 ppg at surface. 16:30 17:30 1.00 6,985 6,985 PROD1 DRILL LOT P Conduct FIT w/10.5 ppg fluid in hole. Pressure up to 1710 psi in 33 stks (1.9 bbls)Shut down and record pressure drop for 10 minutes. Lost 270 psi in 10 minutes, Bleed off and recover 1.6 bbls of 1.9 bbls pumped. EMW 16.1 ppg. RD test equipment. Page 37 of 43 7 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 17:30. 20:00 2.50 6,985 7,110 PROD1 DRILL DRLG P PJSM-RIH to 6,950-ft and set drilling parameters 81 SPM at 1325 SPP, Rotating at 51 RPM, Free Rotating Weight 125k.Continue with Drilling operation f/6985-ft at 6 bpm, 1,975 psi, rotating at 100 RPM with 5-8k WOB, 11.82 ECD, Free Rotating Weight 125k. Drill down to 7,110-ft. 20:00 22:00 2.00 7,110 7,237 PROD1 DRILL DRLG P Continue with Drilling operation f/ 7,110-ft at 6 bpm, 1,975 psi, rotating at 100 RPM with 5-8k WOB, 11.82 ECD, Free Rotating Weight 125k. Drill down to 7,130-ft and perform flow check above C-Sands for 5 minutes. Perform Slide from 7,130-ft to 7,155-ft at 6 bpm,2185 SPP. Continue Drilling at same parameters. 22:00 00:00 2.00 7,237 7,310 PROD1 DRILL DRLG P Drill down to 7,237-ft.Stop and perform flow check above A-sands for 5 minutes.Continue with Drilling Operation f/7,237-ft at 6 bpm,2060 SPP, rotating at 100 RPM,4-6k WOB, ECD 11.90. 10/03/2012 TD 6 1/8"Production Hole Section at 7,375-ft/6,258-TVD. Circulate and Condition hole with 10.5 PPG LSND Mud. UD Drilling Assembly and download LWD data. C/O Handling equipment and PU 4 1/2"Production Liner. 00:00 01:00 1.00 7,310 7,375 PROD1 DRILL DRLG P Continue with Drilling Operation f/ 7,237-ft at 6 bpm,2060 SPP, rotating at 100 RPM,4-6k WOB, ECD 11.90.Average ROP 40-60 FPH. Called TD at 7,375-ft/6,258 TVD. 01:00 03:00 2.00 7,375 7,375 PROD1 DRILL CIRC P CBU x 4 while Reciprocating and Rotating at 50 RPM. Up Weight 160k /Dn Weight 113k/rotating Weight 132k. Pump rate at 5 bpm, 1400 SPP. Racking back one stand after each bottoms up. 03:00 04:00 1.00 7,375 6,900 PROD1 DRILL TRIP P Wiper trip into casing shoe. 04:00 05:30 1.50 6,900 6,810 PROD1 DRILL CIRC P CBU x 2 while Reciprocating . Up Weight 150k/Dn Weight 110k. Pump rate at 5 bpm, 1,375 SPP. 05:30 06:30 1.00 6,813 7,375 PROD1 DRILL TRIP P TIH back to bottom. 06:30 10:30 4.00 7,375 7,108 PROD1 DRILL CIRC P CBU x 4 while Reciprocating and Rotating at 50 RPM. Up Weight 160k /Dn Weight 115k/rotating Weight 125k. Pump rate at 5 bpm, 1550 SPP from 7,335-ft to 7,108-ft,clean returns to surface 10:30 11:30 1.00 7,108 6,823 PROD1 DRILL TRIP P TOOH from 7,108-ft to 6,823-ft,CBU x 1, returns clean across shakers. 11:30 12:00 0.50 6,823 6,823 PROD1 DRILL OWFF P 'Monitor well, static. Page 38 of 43 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 12:00 17:30 5.50 6,823 660 PROD1 DRILL TRIP P PJSM- BDTD. Drop 2.15"drift and POOH with Drilling BHA#3 standing back 4"DP to 660-ft. 17:30 21:00 3.50 660 0 PROD1 DRILL PULD P Lay down BHA#3,single down 4" HWDP. Remove and secure Neutron source. Download LWD data and finish laying down BHA and un-load from rig floor. 21:00 21:30 0.50 0 0 COMPZ RPCOM OTHR P Clean&Clear rig floor and prep to run 4 1/2"Production Liner. 21:30 22:30 1.00 0 0 COMPZ RPCOM PULD P PJSM. Change out Handling Equipment. RU and Install Pup's on Cement Head. 22:30 22:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM. Discuss Hazard for Handling and Picking up 4 1/2"Liner equipment. 22:45 00:00 1.25 0 0 COMPZ RPCOM PUTB P MU Float shoe+float collar and landing joint,wait on right centralizers.well secure. 10/04/2012 Ran 4 1/2"Liner 00:00 08:30 8.50 0 0 COMPZ RPCOM RUNL T Waiting on the Correct Size Bow Spring Centralizer. 08:30 09:30 1.00 0 0 COMPZ RPCOM RUNL P 15ea. New centralizers on site, confirmed right size for job, load to rig floor. 09:30 10:00 0.50 0 0 COMPZ RPCOM SFTY P PJSM. Discuss Hazard for Handling and Picking up 4 1/2"Liner equipment. 10:00 12:00 2.00 0 560 COMPZ RPCOM PULD P MU and RIH with Lower 4 1/2"liner, float shoe+float collar and landing joint(Bowspring Centralizer installed across first 12 collars of Openhole liner)Verify 4 1/2"12.6#wiper plug installed, continue to MU 5"Seal Bore Extension, 5"Flex-Lock Liner Hanger and 5"ZXP Liner Top Packer. 12:00 13:00 1.00 560 560 COMPZ RPCOM SFTY P PJSM-Change over floors to run 4" DP. 13:00 13:30 0.50 600 600 COMPZ RPCOM RUNL P PU 1 stand and lay down 1 joint for cement head space out, MU to Liner Completion and RIH to 600-ft, Up wt 48k, Dn wt 45k, Kelly up and preform flow test thru Liner 15 bbls, 3 bpm at 110 psi. 13:30 19:00 5.50 600 6,885 COMPZ RPCOM RUNL P Continue to RIH with 4 1/2"Liner Completion on 4"DP slowing down thru cementer and continuing on to target depth. 19:00 20:15 1.25 6,885 6,885 COMPZ RPCOM CIRC P While filling Drill pipe at Stand#67, • Noticed a trace of gas in returns, CBU at 3 bpm,400 DPP until gas is clear, 10.5 ppg mud in/out. 20:15 20:30 0.25 6,885 6,885 COMPZ RPCOM OWFF P Shut down pumping operation after pumping 216 bbls and monitor well for 15 minutes for flow.Well on a slight drink. Page 39 of 43 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 21:15 0.75 6,885 7,325 COMPZ RPCOM RUNL IP Continue to RIH f/6,885-ft with 4 1/2" Liner Completion on 4"DP.Up Wt 135k/110k DN Wt 21:15 21:30 0.25 7,325 7,325 COMPZ RPCOM PULD P PU&MU Baker Plug Dropping Head and Space out same. Up Wt 145k/ Dn Wt 110k. 21:30 23:00 1.50 7,325 7,375 COMPZ RPCOM CIRC P RIH while Circulating at 1 bpm,285 psi to TD with 4 1/2"Liner.Continue to stage up pump rate to 4 BPM,960 psi while reciprocating drill pipe. Start Mixing up Mud Push at 2215 hours. Final pressure 725 psi at 4 bpm. 23:00 23:30 0.50 7,375 7,375 COMPZ RPCOM SFTY P PJSM. Discuss hazard for 3rd party pumping operation with SLB, Nordic and ASRC truck pusher. 23:30 00:00 0.50 7,375 7,375 COMPZ RPCOM CMNT P Start Cement operation for 4 1/2" Liner.Start batching up cement. Up Wt 145k/Dn Wt 110k.Continue to reciprocate. 10/05/2012 Ran 4 1/2"Liner to target depth. Pumped 15.8 PPG Class G Cement around liner and landed same. Condition wellbore and TOOH sideways with Drill Pipe. MIRU SLB E-Line unit and tools for CBU of 4 1/2" Liner. 00:00 00:15 0.25 7,375 7,375 COMPZ RPCOM PRTS P Continue to reciprocate 7-10-ft. Cement batch at midnight. Pumped 5 bbls of CW-100 @ 4 bpm,730 psi. LPT to 750 psi/HPT to 4,500 psi. 00:15 01:00 0.75 7,375 7,375 COMPZ RPCOM PUCM P Continue to reciprocate 7-10-ft. Pumped 10 bbls of CW-100 at 4 bpm,700 psi. Pumped 15 bbls of 13 PPG Mudpush II at 4 bpm,740 psi. ���� Pumped 19 bbls of 15.8 PPG G+ Adds at 4 bpm. Initial Psi 680 psi/ Final 425 psi. Shut down and close lower TIW valve and Pump 10 bbls of fresh wayter top clear lines.Open upper TIW and flush cement hose to cutting box. Close upper TIW& launch Dart. Open Lower TIW. 01:00 01:30 0.50 7,375 7,375 COMPZ RPCOM PUCM P Continue to reciprocate 7-10-ft. Circulate 67 bbls of 10.5 PPG New Mud at 4 bpm, 730 psi.Slow pump rate to 3 bpm with liner on depth. 74 bbls away,3 bpm,2000 psi Latch up and seen plug bump at 81 bbls away,pressure up to 3,950 psi, slacked off string with 50,000 lbs to set. 01:30 01:45 0.25 7,375 7,375 COMPZ RPCOM PUCM P Bleed pressure to zero and checked floats. No flow to cement van. PU 20k and check liner hanger is set. Slacked off to 20k and rotated 12 turns and released setting tool from liner. Pressure DP to 875 psi and slowly PU while watching for the pack-off to clear liner top,seen good release. Packer Set. Page 40 of 43 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 01:45 02:45 1.00 7,375 6,830 COMPZ RPCOM CIRC P Increased pump rate to 6 bpm, 1,055 psi and circulated hole clean. Estimated 8 to 10 bbls of cement circulated out.Circulated 232 bbls until hole and SBE area was clean. 02:45 03:45 1.00 6,830 6,830 COMPZ RPCOM PULD P Lay down Baker Cement Head. 03:45 04:30 0.75 6,830 6,800 COMPZ RPCOM PRTS P PUH above Liner Top Packer. Pressure tested the Liner and the Liner top packer to 3,500 psi for 30 minutes. RD Testing Equipment. 04:30 07:00 2.50 6,800 6,766 COMPZ RPCOM CIRC P Circulate 40 bbls of 12.5 ppg Mud Push follow with 80 bbls og SS-W and 290 bbls of 10.5 PPG CaClw KWB at 5 BPM, 370 PSI while Reciprocating work string. 07:00 16:30 9.50 6,766 0 COMPZ RPCOM TRIP P TOOH single down 4"DP,offload as needed from 6,766-ft 16:30 17:30 1.00 0 0 COMPZ RPCOM PULD P Lay down, clean and inspect running tool,good shape,off load Baker tools. 17:30 18:30 1.00 0 0 COMPZ RPCOM SFTY P PJSM-Pull Wear Bushing and set test plug. 18:30 20:30 2.00 0 0 COMPZ RPCOM CIRC P Wash stack w/lateral wash nozzle at 3 bpm,600 psi, pull test plug and wash tubing head area at same rate. 20:30 22:00 1.50 0 0 COMPZ RPCOM ELOG P PJSM. Discuss hazard with SLB e-line and nordic. MIRU e-line unit and load tools to rig floor. 22:00 22:30 0.50 0 0 COMPZ RPCOM ELOG T RIH w/CBL on SLB e-line down to 3000-ft. Having communication problems with tools. 22:30 23:30 1.00 0 0 COMPZ RPCOM ELOG T POOH f/3000-ft and trouble shoot tools. 23:30 00:00 0.50 0 0 COMPZ RPCOM ELOG P RIH w/CBL tools. 0))� 10/06/2012 Perform CBL of 4 1/2"Liner. Ran 3 1/2"Production Completion. 00:00 00:30 0.50 0 0 COMPZ RPCOM ELOG T Started having trouble with Logging tools at 1000-ft. POOH with tools. 00:30 01:00 0.50 0 0 COMPZ RPCOM ELOG T Swap out Logging tools. 01:00 08:00 7.00 0 0 COMPZ RPCOM ELOG P RIH w/CBU Logging tools and Log 4 1/2"Liner section. Could not make it past 7,200-ft with toolstring. Log up from 7,200-ft to 6,800-ft. POOH with E-line Ultra Sonic Imaging Tool, V J down load and E-mail to Town.Tools clean.Confer with town engineer, not deep enough, call out for smaller OD Sonic tool from Prudhoe. 08:00 09:00 1.00 0 0 COMPZ RPCOM RURD T Schlumberger crew has timed out for work hours, no relief crew avaliable, PJSM-Rig back SLB equipment while waiting for SLB Tools from Prudhoe. 09:00 09:30 0.50 0 0 COMPZ RPCOM OTHR T Slickline on site, Spot equipment. Page 41 of 43 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 09:30 09:45 0.25 0 0 COMPZ RPCOM SFTY T PJSM-Rigging up Slickline and associated risks. 09:45 12:15 2.50 0 0 COMPZ RPCOM SLKL T RU Slickline and RIH with 2.5"DD bailer and 3.83"stiff BL brush to 7,322-ft SLM,did not sit down, 3.83" OD brush at 7,315-ft-POOH-8" piece of Duct tape in brush. Information from town engineer at 12:00, logs good enough. SLB L° S E-line relief crew on site with Sonic tool at 12:00. 12:15 13:00 0.75 0 0 COMPZ RPCOM RURD P PJSM-RD of Slickline and E-line equipment from rig floor. RDMO HES Slickline and Relief Crew for SLB E-line equipment. 13:00 13:30 0.50 0 0 COMPZ RPCOM SFTY P PJSM-running of 3-1/2"completion and associated risks, running order of completion. 13:30 18:00 4.50 0 4,881 COMPZ RPCOM TRIP P RIH with 3-1/2"Upper Completion as per running order. 4,881 4,881 COMPZ RPCOM DHEQ P RU and Inspect the SSSV. Purge and tested the control line to 5500 psi for 5 minutes. 18:00 22:00 4.00 4,881 6,813 COMPZ RPCOM RCST P Continue to run completion while holding 5,500 psi on control line to hold valve in the open position and Installing SS Bands of Every joint. 22:00 23:15 1.25 6,813 6,813 COMPZ RPCOM RCST P Engage charge pump while the completion until seals engage and pressure increase was seen,shut down charge pump and continue down hole with completion the locator hit the No-go.Marked depth for space out. Need 24.32-ft of space out pups below joint#213 which leave the bottom of the 3 1/2" completion at 6862.96-ft MD. 23:15 23:45 0.50 6,813 6,797 COMPZ RPCOM RURD P PUH above 15-ft above Liner Top Packer and RU pumping equipment. 23:45 00:00 0.25 6,797 6,797 COMPZ RPCOM CIRC P MU to Top Drive and circulate 200 bbls of fresh water at 5 BPM, 500 psi 10/07/2012 Condition wellbore with Corrosion Inhib 9.6 PPG Brine. Landed 3 1/2"Production Completion.Tested Tubing x Casing to 3500 psi for 30 minutes each and charted same. ND BOPE and NU Adapter and Tree and Tested same to 5000 psi for 30 Minutes.Sheared SOV and Freeze protect Tubing x IA annulus with Diesel to 2000-ft. 00:00 03:00 3.00 6,797 6,797 COMPZ RPCOM CIRC P Continue to circulate 200 bbls of fresh water at 5 BPM, Initial Psi 935 Final 500 psi. Swap over to 9.6 PPG NaCI brine and pump 290 bbls at 5 bpm. Initial Psi 480 psi, Final Psi 435 psi. Monitor Well.Swap over and pump 185 bbls of 9.6 PPG Inhibited Brine at 5 bpm, ICP 450 psi FCP 385.Monitor Well.Swap over and Pump 60 bbls of 9.6 PPG NaCI Brine at 5 bpm, ICP 400 psi, FCP 380 psi. Page 42 of 43 Time Logs Date From To Dur S. Depth E.Death Phase Code Subcode T Comment 03:00 03:30 0.50 6,797 6,863 COMPZ RPCOM HOSO P String into SBE and Space out 6 foot above fully located position and land tubing hanger with landing joint. RILDS on Hanger. Install 67 SS Bands.Average Torque was 3000 lbs-ft 03:30 07:00 3.50 6,863 6,863 COMPZ RPCOM PRTS P RU Testing Equipment&Pressure Test Tubing to 3,500 psi for 30 Minutes and Chart same. Bleed TBG pressure to 2,000 psi and Pressure test 3 1/2"x 7"Annulus to 3,500 psi for 30 Minutes and Chart Same. Bleed pressure from TBG and Shear the DCR-1 valve. Bleed TBG and Annulus to zero. Monitor 10 min. RD test equipment, lay down landing joint 07:00 08:00 1.00 0 0 COMPZ WELCTI MPSP P PJSM-Set BPV in Tubing Hanger, Pressure up IA to 3000 psi and test BPV,Tubing Hanger Seal in direction of flow,chart 10 min. Bleed down IA to zero after test. 08:00 08:30 0.50 0 0 COMPZ WELCT[OWFF P Monitor Well for flow for 30 minutes. 08:30 17:00 8.50 0 0 COMPZ WHDBO NUND P PJSM. Nipple Down BOPE. Open up all doors and clean all cavities. Break out single gate for shipment to town. secure BOPE on Stump. 17:00 18:30 1.50 0 0 COMPZ WHDBO NUND P Nipple Up tree&adapter. 18:30 22:45 4.25 0 COMPZ WHDBO PRTS P Tested void to 5,000 psi for 30 minutes. Pull BPV and Set two way check and tested tree to 5,000 psi for 30 minutes and chart same. Pull two way checks. 22:45 23:00 0.25 COMPZ WHDBO SFTY P PJSM. Discuss Hazard for pumping operation with Nordic&LRS. 23:00 00:00 1.00 COMPZ WHDBO FRZP P Freeze protect w/80 bbls of diesel at 2 bpm. ICP 650/FCP 400. RDMO LRS pumping unit.Allow diesel to U-tube from IA to Tubing. 10/08/2012 Completed Freeze Protect. RDMO Nordic 3 and Clean and Clear Equipment off Location. 00:00 00:30 0.50 COMPZ WHDBO FRZP P Allow Diesel to U-Tube from IA to Tubing. 00:30 04:00 3.50 COMPZ MOVE DMOB P RDMO Nordic Rig 3.Clean and Clear Location. Rig Release at 0400 hours. Page 43 of 43 ix H II N C 7 m c 3 a^ — V E p_ 2 E z a j= c E N a)) Q F- a U i) Iii d a 0 a) 3 = m O z H t75 N o _ � m E z a o a N o E o ` zoo a '2m > tp_ 1- ° Nzl' >, o =E > I- ` c . t, z c> o T mA. c c 0 awS F c ,D : m ) a - p ` A,= - o o 0 0 cr-c N n c a) UN � aa).. m CCp o CO cncEo a I1!: III !II1 ! b ! Jt1JIiIi EOESNEa > 0 N ' ` a -ay0Od H - ot -o _EaZoa)- acisv 0wm21irn- oI > o � a me! Fo8ou_ 1223 I VIVO lAd E E R1aw ca co 0 0 E cc m M a> all n) E = o> — = J Y (D 0 o_ a as v Q U) oz -/I 3 T Z CV0 LL. 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' ••••-•-•- •----. i • • • - i I — 1-1 ::::::A CI - • - I 11-----1 11:::11 I I 1 I I Il--<1:1 Ilr VINIIISINIIMINI; 'Oil I III I I --500.0000 1000.0000 - 0.5000 -500.0000 - 1.0000 0.3000 - 1.5000 2.6000 -' 2.0000 3.0000 - 2.5000 3.5000 - 3.0000 4.0000 • - 3.5000 - .0000 Cable Internal radius External radius 55500 4.0000 Minimum of AlAI 5..5000000 Speed (CS) Average Average - 4.5000 (AIMN) Bonded 5.5555 (F/HR) (IRAV) (ERAV) - 5.0000 5.5000 0 (MRAY) 10 0 2000 2.4 (IN) 1.4 1.4 (IN) 2.4 6.0000 7.0000 6.5000 7.5000 7.0000 8.0000 7.5000 1 8.0000 Cement Map with Impedance !, Classification (Al MICRO Raw Acoustic Imped. (AIBK) 1DEBONDING IMAGE) (MRAY) (MRAY) Gamma External Internal radius . Ray(GR_ radius Average Average of Al EDTC) Average (AIAV) Gas or Dry (GAPI) (ERAV) (IRAV) i 0 (MRAY) 10 MicroA 0 150 2.4 (IN) 1.4 1.4 (IN) 2.4 ,,r, ..,.._ Image Internal radius Internal radius rotation Maximum Maximum Maximum of Al (UCAZ) (IRMX) (IRMX) (AIMX) (I'[tf1:1 0 (DEG360) 2.4 (IN) 1.4 1.4 (IN) 2.4 0 (MRAY) 10 Casing Collar Min of Internal Min of Internal Locator radius(IRMN) radius(IRMN) Micro-debon (CCL) 2.4 (IN) 1.4 1.4 (IN) 2.4 '•'' -20 20 Format: USI_Cement1 Vertical Scale: 5" per 100' Graphics File Created: 10-Oct-2012 14:44 OP System Version: 19C1-222 USIT-D 19C1-222 EDTC-B 19C1-222 CAL-Y 19C1-222 All USI Images are outside views Center of image corresponds to bottom of casing USI : HIGH Frequency Compression Mode Used For Logging. Recommended casing thickness range for optimum cement impedance measurement : 0.18 to 0.31 IN. Parameters DLIS Name Description Value USIT-D: Ultrasonic Imaging- D AGMN Minimum Gain of Cartridge -4 DB AGMX Maximum Gain of Cartridge 20 DB BERJ Bad Echo Rejection ON CDIA Casing Outer Diameter 4.5 IN CSDE Casing Density 486.94 LBCF CSID Casing Inner Diameter 3.96129 IN DFVL Default Fluid Velocity 206 US/F DOT Diameter of Transducer Sensor 1.756 IN EMXV EMEX Voltage 50 V FDII FPM Data Interpolation Interval 0 FT IMAR Image Rotation RB MW Mud Weight 10.5 LB/G RCOD Reference Calibrator Outer Diameter 4.5 IN Depth Fluid Velocity(DFVL) Acoustic Impedance(ZMUD) 7200.00 189.49 2.32 7150.00 186.06 2.33 7100.00 185.24 2.24 7050.00 185.93 2.32 7000.00 186.08 2.43 6950.00 183.78 2.41 6900.00 183.10 2.45 6850.00 183.26 2.39 6800.00 183.46 2.44 6750.00 183.46 2.44 Casing Collar Locator (CCL) -20 20 Image rotation (UCAZ) (DEG) O 360 Gamma Ray(GR_ E DTC) (GAPI) 0 150 Azimuth of eccent. (AZEC) (DEG) 0 360 -500.0000 -6.0000 -5.6000 -5.2000 -4.8000 -4.4000 -4.0000 -3.6000 -3.2000 -2.8000 Min of Min of Cable 2..4000 4000 Internal Internal Speed(CS) _1.6000 radius radius Micro-de. (F/HR) -1.2000 (IRMN) (IRMN) . .', . O 2000 -4.8444 (IN) (IN) -0.4000 0.5000 2.4 1.4 1.4 2.4 Amplitude of echo minus Max (AWBK) (DB) Maximum Internal Internal Maximum Rev.speed of radius radius of /De A%A ■�....:......« new..:........ TMiwl.wwww 1r7JMV) Amplitude '''' II IYIOAl111Y 111 I IIWf\11CT..l ,. ..(RPS) (AWMX) (IRM (IRMX) (THMX) -8 -6 0 (DB) 75 (IN) (IN) (IN) 2.4 1.4 1.4 2.4 0.1 0.6 Internal Internal Average of Rev.s eed Average of radius radius p Amplitude Average Average Thickness Gas or (RSAV) (AWAV) (IRAV) (IRAV) (THAN) Dry 6 (RPS) 8 0 (DB) 75 (IN) (IN) (IN) 1, . s 2.4 1.4 1.4 2.4 0.1 0.6 ■-500.0000 ■-500.0000 1000.0000 1 -0.0760 -0.0760 -500.0000 -500.0000 0.3000 -0.0680 -0.0680 0.5000 2.6000 -0.0600 -0.0600 1.0000 3.0000 -0.0520 1 -0.0520 1.5000 3.5000 -0.0440 4 -0.0440 2.0000 -0.0360 -0.0360 2.5000 4.5000 4.5000 -0.0280 -0.0280 3.0000 5.0000 0.5000 • -0.0200 -0.0200 3.5000 1.5000 ■ -O.0120 ■ -0.0120 55000 2.5000 External External ■ -0.0040 ■ -0.0040 4,0000 6.0000 j 3.5000 Min. of ■ Min of • 4.5000 6.5000 Eccent. 5.5000 radius radius ■ 0.0040 Thickness ■ 0.0;0 5.0000 7.0000 Amplitude Average Average ■ ■ 5.5000 7.5000 (ECCE) AWMN ■ 0.0200 (THMN) 0.0200 5.0000 Bonded 5.0000 0 IN 0.5 ( ) (ERAV) (ERAV) ■ o.ozao 0.0280 6.0000 ( ) Process. 0 (DB) 75 (IN) (IN) 0.0360 (IN) 0.0360 7.0000 flags 2.4 1.411.4al 0.0440 2.4 • 0.0520 0.1 0.6 0.0440 0.0520 7.5000 Cement (UFLG) 0.0600 0.0600 8.0000 Map with (----) 0.0680 0.0680 Impedance 0.0760 0.0760 Raw Classificati Acoustic on (AI_ I Internal Thickness Imped. MICRO_ radii minus minus Ave' (AIBK) DEBONDIN Ave(IRBK) (THBK) (MRAY) G_IMAGE) (IN) (IN) (MRAY) •n I ti,1:, yCti: L „I IIIi,�.rll 1 I. ' Fli . -:-:- • , • • •.1.GUMMI ' • • ....._. ..„,„,,,,,,,,,,:,4„ ,,,. ., ,.„...,-, " . . . . . . .s.... _=/1 ,.,,,, „,,,,:„. ..6,.... "i' .Y.r1i�„ ....::.,.i 'sii.la ...4 .. ..... ... .... . MIEIMMMI .i ',r 4 .J.,1. 1. g �1.5 1'1.11111 C) , ....A 17,, P 1. , � . 1111111 k + ..:. < 'ti '.. M■1 ,, .,.... ' � :71 n1.1... y .JL.... ►�- •�.�151MIMI .In uu 1"O .�. ISI rb 1 . I ..; r .. .. . ,r4R--- 1. ' I •• ',.. .' 4Iri I.�,I11111R91R 411 Cy-..... auau .... @'aa 1{hYhii % 1 ! 5' S,}I j-'K4 }JI{!I-'P 1.' - Liner Top Packer mss, , -MN ',I, IIIA l ].::-.'l / ir I, c .' 2- I i I ! 1 SCA A .900 ::,--. ° - lmCAZ 4.4,. 1(15. „4. 1 UCAZ ` `t - ' ' " t .11 I I Az mi it C • :.-:-.. , . .. ! . ,1. •-•iit w • ,- i :-.--.--,1 . •. ! , , • •• - ... I poL I.i , • ,, ,, . .. • . 1 k. le ... 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L ,v,„..,,,,„,!,„.._,...., CAZ �rill 1 � �� • • • 1 i••1 '' N 4 - ' .M 0 . 4 • t .1-A 1QIP N • • 4 Il' IFA { -� • 10 : i 1 ti :i' �� .. E._. ..._.. - 1, t '1'7 •A y.*llr ' ' CL 1 :=1� . .: . 0 s • T1= ., ..: Ill ' '-I, i'''''t -FR 1 j k 1' ,••. „ e. Y' • C I i y, ii •1! v 1,' -500.0000 -500.0000 - 1000.0000 I -0.0760 -0.0760 --500.0000 -500.0000 - 0.3000 -0.0680 -0.0680 0.5000 - 2.6000 -0.0600 -0.0600 1.0000 - 3.0000 - -0.0520 -0.0520 1.5000 - 3.5000 - -0.0440 -0.0440 2.0000 - -0.0360 -0.0360 - 4.0000 2.5000 - 4.5000 - -0.0280 -0.0280 3.0000 0.5000 -0.0200 -0.0200 7 5.0000 1.5000 - -0.0120 -0.0120 3.5000 1w:,- 5.5000 2.5000 External External - -0.0040 -0.0040 4.0000 6.0000 Min OT 40000 6.5000 3.5000 Min.of radius radius - 0.0040 0.0040 Eccent. 5.0000 7.00008.5000 Amplitude Average Average - 0.0120 Thickness 0.0120 5.5000 7.5000 (ECCE) AWMN - 0.0280 (THMN) 0.0200 6.0000 6.5000 Bonded 8.0000 0 (IN) 0.5 ( ) (ERAV) (ERAV) - 0.0280 0.0280 Process. 0 (fN(DB) 75 (IN) (IN) - 0.0360 ) 0.0360 7.0000 - 0.0440 0.1 0.6 0.0440 7.5000 Cement flags 2.4 1.4 1.4 2.4 (UFLG) - 0.0520 0.0520 8.0000 0.0600 0.0600 Map with (----) - 0.0680 0.0680 Impedance - 0.0760 0.0760 Raw Classificati Acoustic on(Al Internal Thickness Imped. MICRO_ radii minus minus Ave (AIBK) DEBONDIN Ave(IRBK) (THBK) (MRAY) GIMAGE) (IN) (IN) (MRAY) Internal Internal Average of radius radius Average of Rev. speed Thickness Gas or (RSAV) Amplitude Average Average THAV Dry 6 (RPS) 8 0 ( (DB) 75 (IRAV) (IRAV)R (THAV)(IN) MicroA (IN) (IN) 0.1 0.6 2.4 1.4 1.4 2.4 Maximum Internal Internal Maximum Rev.speed of radius radius of (RSAV) A..,',It.,..le Maximum Maximum Thickness • i ranNuauuc a . (RPS (AWMX) (IRi (IRMX) (THMX) - 0 (DB) 75 (IN) (IN) (IN) 2.4 1.4 1.4 2.4 0.1 0.6 -500.0000 -6.0000 -5.6000 -5.2000 -4.8000 -4.4000 -4.0000 -3.6000 -3.2000 -2.8000 Min of Min of Cable 11 -2.4000 Internal Internal Speed (CS)i -2.0000-1.6000 2.0000-1s000 radius radius Micro-de. (F/HR) -1.2000 (IRMN) (IRMN) .1 .'i . 0 2000 -0.8000 (IN) (IN) -0.4000 0.5000 2.4 1.4 1.4 2.4 Amplitude of echo minus Max (AWBK) 1 (DB) Azimuth of eccent. (AZEC) (DEG) 0 360 Gamma Ray(GR_ EDTC) (GAPI) 0 150 Image rotation (UCAZ) (DEG) 0 360 Casing Collar Locator (CCL) (----) -20 20 Format: USIComposite_1 Vertical Scale: 5" per 100' Graphics File Created: 10-Oct-2012 14:44 OP System Version: 19C1-222 USIT-D 19C1-222 EDTC-B 19C1-222 CAL-Y 19C1-222 All USI Images are outside views Center of image corresponds to bottom of casing COMPUTATION FLAGS LABELLING (0-1.5) UFLG 1 UTIM error (1.5-2.5) UFLG 2 Pulse origin not detected (2.5-3.5) UFLG 3 WINLEN error Page 1 of 2 Schwartz, Guy L (DOA) From: Guo, Haibin [Haibin.Guo@conocophillips.com] Sent: Tuesday, September 11, 2012 4:24 PM 2_1 Z, �— To: Schwartz, Guy L (DOA) Cc: Davies, Stephen F (DOA) Subject: RE: 3H-11A kickoff high in surface casing Attachments: 3H-11A (wp11a)- Proposal Report- NAD27.pdf; 3H-11A Proposed Schematic updated 0911.pdf; 3H-11A kick off higher explanation letter.doc Guy, I included the updated well schematic, new directional plan and explanation letter as attached. If you need any thing more, let me know. Thanks. Haibin Guo Drilling Engineer ConocoPhillips Alaska Office: 907.265.1487 Cell: 907.297.9113 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, September 11, 2012 9:21 AM To: Guo, Haibin Cc: Davies, Stephen F (DOA) Subject: [EXTERNALJRE: 3H-11A kickoff high in surface casing Looks like trying to pull 7" casing down to the surface casing shoe is not very likely. Your plan to set a whipstock at 2700' and (above the current casing stub is approved.) Please send us the new directional plan via email as soon as possible with a explanation letter attached. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Guo, Haibin [mailto:Haibin.Guo@conocophillips.com] Sent: Monday, September 10, 2012 11:01 AM To: Schwartz, Guy L (DOA) Subject: RE: 3H-11A kickoff high in surface casing Guy, More information for you. We set cement in 7" casing 5600' MD-4365' MD with two cement plugs before the cut and pull. We'll do the integrity test with 1500 psi for surface casing and the cement plugs before set whipstock. So maybe we do not need to set another plug in surface casing. Attached is the CBL we 9/11/2012 Page 2 of 2 got for 7" casing. If you need more information, let me know. Thanks. Haibin Guo Drilling Engineer ConocoPhillips Alaska Office: 907.265.1487 Cell: 907.297.9113 ember 10,2012 10:39 AM L(DOA)' kickoff high in surface casing Guy, The original plan is cut and pull 7" casing from 4300' MD. Kick off and sidetrack at 3720' MD. We ran CBL in 7" casing after pulling the tubing, found the TOC in 7"x 10-3/4"was at 2472' MD. Much higher than we thought. We ran 9-5/8"washover shoe and washpipe to wash over the 7", but made slow progress. Managed washover to 2541' MD last Wednesday. Ran 5-1/2" multi-string cutter to cut 7", could not get the cutter in. Ran 6-1/8"tapered mill to dress and clean the 7", could not go deeper either. Ran 7" casing spear, fished out 60.32'washed 7". 32'washed 7" still in hole. Ran 9-3/4"junk mill, no progress, the casing was spinning. Ran 6- 1/8" swage tool, recovered 14.63'washed 7". Ran 9-3/4"junk mill and milled to 2540' MD yesterday. Right now we are trying to use 8-1/4" pilot mill to chew up 7"casing to 2720' MD. Set whipstock and kickoff with the top of window at 2700' MD. If pilot mill could not make progress, we may need to kickoff at current depth (2540' MD). The targets will keep the same. Can you please approve us to kickoff higher? Thanks. Haibin Guo Drilling Engineer ConocoPhillips Alaska Office: 907.265.1487 Cell: 907.297.9113 9/11/2012 3H-11A kick off higher explanation letter 3H-11A original plan was to cut and pull 7" casing at 4,300' MD Set cement plug and kick off below surface casing shoe at 3,720' MD On 08/29/2012, we ran CBL for 7" casing found cement behind 7" casing from 2,472' MD to 4,250' MD We cut and pulled the free 7" from 2,451' MD. Then ran 9-5/8" wash over assembly to wash down 7" on 09/03/2012. The penetration was very slow. Washed to 2,543' MD on 09/05/2012. Then ran 5-1/2" multi-string cutter to cut 7", but could not get the cutter in 7" Ran 6- 1/8"tapered mill to dress and clean the 7", could not go deeper either. Ran 7"casing spear, fished out 60.32'washed 7". 32' washed 7" still in hole. Ran 9-3/4"junk mill, no progress, the casing was spinning. Ran 6-1/8" swage tool, recovered another 14.63'. Ran 9-3/4"junk mill milled to 2540' MD on 09/09/2012. Yesterday, 09/10/2012, we ran 8-1/4" pilot mill milled down to 2,588' MD, made 48' progress It's not likely we can pull 7" casing down to surface casing shoe at 3637' MD. We are targeting to mill to 2,750' MD and kick off at 2,700' MD. 50' rat hole for setting whipstock and keep away from casing collar for milling window. The formation targets will be the same with original plan. We'll do the 10-3/4" casing integrity test before set whipstock. An updated proposal schematic and the new directional plan are attached. Regards, Haibin Guo Drilling Engineer ConocoPhillips Alaska E- il''tV� - m�0 Z00 ...sr-4m c9 - 2c mc,mr O a p rnN HD .h OWm —h O . U� � 3z N..Q m.. v x�o. , "$ 200g A ]3 E.Ern 2a 2 - 3 P: d1n O b NO r —O .41"). - a 0 o z3 5 U - o 4. oma' —, N A 20 1- U a - ,00,0,- QS gl en,r~~ - z .. N 0,— 40 o O - O - m OHO._. 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N Lf) lO V) CO t0 t0 0 1.....(u!/3109L)43dea�eoi�an anal = n 0, Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 3H-11 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: 3H-11A @ 69.60ft(Nordic 3(38.7+30.9)) Project: Kuparuk River Unit MD Reference: 3H-11A @ 69.60ft(Nordic 3(38.7+30.9)) Site: Kuparuk 3H Pad North Reference: True Well: 3H-11 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3H-11A Design: 3H-11A(wp11a) Project Kuparuk River Unit,North Slope Alaska,United States 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 3H Pad Site Position: Northing: 6,000,110.73 ft Latitude: 70°24'41.531 N From: Map Easting: 498,655.44 ft Longitude: 150°0'39.416 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: -0.01 ° Well 31-1-11 Well Position +N/-S 0.00 ft Northing: 6,000,425.37 ft Latitude: 70°24'44.626 N I +E/-W 0.00 ft Easting: 498,655.44 ft Longitude: 150°0'39.418 W I Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 38.70 ft j Wellbore Plan:3H-11A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2011 9/14/2012 15.97 79.96 57,378 Design 3H-11A(wp11a) Audit Notes: Version: Phase: PLAN Tie On Depth: 2,700.00 Vertical Section: Depth From(TVD) +NI-S +E/-W Direction (ft) (ft) (ft) r) L30.90 0.00 0.00 83.00 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (°) (0) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (0) 2,700.00 41.43 99.67 2,400.07 2,330.47 -110.19 1,036.87 0.00 0.00 0.00 0.00 2,719.90 42.57 96.85 2,414.86 2,345.26 -112.10 1,050.04 11.06 5.71 -14.16 -60.00 2,819.90 42.57 96.85 2,488.51 2,418.91 -120.16 1,117.21 0.00 0.00 0.00 0.00 3,350.99 27.63 69.86 2,924.34 2,854.74 -98.94 1,414.60 4.00 -2.81 -5.08 -144.50 5,693.23 27.63 69.86 4,999.49 4,92989 274.99 2,434.42 0.00 0.00 0.00 0.00 6,332.96 45.00 37.00 5,517.70 5,448.10 510.62 2,714.48 4.00 2.72 -5.14 -62.67 7,151.65 45.00 37.00 6,096.60 6,027.00 972.95 3,062.87 0.00 0.00 0.00 0.00 7,266.34 45.00 37.00 6,177.70 6,108.10 1,037.72 3,111.67 0.00 0.00 0.00 0.00 7,375.23 45.00 37.00 6,254.70 6,185.10 1,099.21 3,158.01 0.00 0.00 0.00 0.00 9/11/2012 4:08:33PM Page 2 COMPASS 2003.16 Build 69 Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 3H-11 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: 3H-11A @ 69.60ft(Nordic 3(38.7+30.9)) Project: Kuparuk River Unit MD Reference: 3H-11A @ 69.60ft(Nordic 3(38.7+30.9)) Site: Kuparuk 31-1 Pad North Reference: True Well: 31-1-11 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3H-11A Design: 3H-11A(wp11a) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +EI-W Northing Easting DLS Vert Section (ft) (') (°) (ft) ft (ft) (ft) (ft) (ft) -38.70 1 30.90 0.00 0.00 30.90 -38.70 0.00 0.00 6,000,425.37 498,655.44 0.00 0.00 I 93.60 0.13 118.43 93.60 24.00 -0.03 0.06 6,000,425.34 498,655.50 0.21 0.06 i 193.60 0.20 120.83 193.60 124.00 -0.18 0.31 6,000,425.19 498,655.75 0.07 0.29 i 1 293.60 0.25 129.72 293.60 224.00 -0.41 0.63 6,000,424.96 498,656.07 0.06 0.58 1 393.60 0.92 114.42 393.59 323.99 -0.88 1.53 6,000,424.49 498,656.97 0.681.41 493.60 4.47 96.45 493.47 423.87 -1.65 6.13 6,000,423.72 498,661.57 3.61 5.89 I 593.60 8.52 94.78 592.81 523.21 -2.70 17.39 6,000,422.66 498,672.83 4.05 16.93 1 693.60 13.45 92.37 690.94 621.34 -3.80 36.41 6,000,421.56 498,691.84 4.95 35.67 793.60 16.08 92.53 787.63 718.03 -4.89 61.87 6,000,420.47 498,717.30 2.63 60.81 893.60 17.72 93.21 883.31 813.71 -6.36 90.90 6,000,419.00 498,746.33 1.65 89.45 993.60 18.95 93.71 978.23 908.63 -8.26 122.30 6,000,417.09 498,777.72 1.24 120.38 I 1,093.60 20.95 94.33 1,072.23 1,002.63 -10.66 156.33 6,000,414.68 498,811.75 2.01 153.87 j 1,193.60 22.55 94.57 1,165.10 1,095.50 -13.54 193.27 6,000,411.80 498,848.69 1.60 190.18 I 1,293.60 24.17 94.75 1,256.90 1,187.30 -16.76 232.79 6,000,408.57 498,888.20 1.62 229.01 1,393.60 25.22 94.21 1,347.76 1,278.16 -20.02 274.44 6,000,405.30 498,929.85 1.07 269.96 1,493.60 26.88 94.11 1,437.60 1,368.00 -23.21 318.24 6,000,402.11 498,973.64 1.66 313.04 1,593.60 30.95 95.34 1,525.11 1,455.51 -27.22 366.41 6,000,398.09 499,021.81 4.11 360.36 I 1,693.60 34.25 95.22 1,609.35 1,539.75 -32.18 420.05 6,000,393.12 499,075.44 3.30 413.00 i 1,793.60 36.03 95.02 1,691.12 1,621.52 -37.31 477.38 6,000,387.98 499,132.76 1.78 469.27 1,893.60 36.90 96.01 1,771.54 1,701.94 -43.03 536.53 6,000,382.25 499,191.91 1.05 527.29 1 1,993.60 37.65 96.10 1,851.11 1,781.51 -49.42 596.76 6,000,375.85 499,252.13 0.75 586.29 2,093.60 38.20 96.37 1,929.99 1,860.39 -56.09 657.86 6,000,369.17 499,313.22 0.57 646.12 2,193.60 38.20 96.68 2,008.58 1,938.98 -63.12 719.30 6,000,362.13 499,374.65 0.19 706.24 j 2,293.60 38.17 97.56 2,087.18 2,017.58 -70.78 780.64 6,000,354.46 499,435.99 0.54 766.20 2,393.60 38.83 98.28 2,165.44 2,095.84 -79.36 842.30 6,000,345.86 499,497.64 0.80 826.35 i2,493.60 39.40 98.72 2,243.03 2,173.43 -88.69 904.69 6,000,336.53 499,560.02 0.63 887.14 1 2,593.60 40.45 99.26 2,319.72 2,250.12 -98.72 968.08 6,000,326.49 499,623.40 1.11 948.83 1 2,693.60 41.40 99.64 2,395.27 2,325.67 -109.48 1,032.70 6,000,315.72 499,688.01 0.98 1,011.66 I 2,700.00 41.43 99.67 2,400.07 2,330.47 -110.19 1,036.87 6,000,315.01 499,692.19 0.58 1,015.71 TOW @ 2700'MD,2400'TVD:1342'FNL,1318'FWL-Sec12-T12N-R08E 2,700.02 41.43 99.67 2,400.09 2,330.49 -110.19 1,036.88 6,000,315.01 499,692.20 0.00 1,015.72 10 3/4"TOW 2,719.90 42.57 96.85 2,414.86 2,345.26 -112.10 1,050.04 6,000,313.10 499,705.36 11.07 1,028.56 2,758.92 42.57 96.85 2,443.60 2,374.00 -115.24 1,076.25 6,000,309.95 499,731.56 0.00 1,054.19 NB 2,800.00 42.57 96.85 2,473.85 2,404.25 -118.56 1,103.84 6,000,306.63 499,759.15 0.00 1,081.17 2,819.90 42.57 96.85 2,488.51 2,418.91 -120.16 1,117.21 6,000,305.02 499,772.52 0.00 1,094.24 2,900.00 40.00 93.95 2,548.70 2,479.10 -125.17 1,169.80 6,000,300.01 499,825.10 4.00 1,145.83 2,969.27 37.83 91.19 2,602.60 2,533.00 -127.14 1,213.26 6,000,298.02 499,868.55 4.00 1,188.72 1 WEST SAK D 3,000.00 36.90 89.88 2,627.03 2,557.43 -127.32 1,231.91 6,000,297.84 499,887.20 4.00 1,207.21 i 3,011.94 36.54 89.36 2,636.60 2,567.00 -127.27 1,239.05 6,000,297.89 499,894.34 4.00 1,214.30 1 WEST SAK C 1 3,046.56 35.51 87.78 2,664.60 2,595.00 -126.77 1,259.40 6,000,298.39 499,914.69 4.00 1,234.56 WEST SAK B 9/11/2012 4:08:33PM Page 3 COMPASS 2003.16 Build 69 Halliburton -Sperry HALLIBURTDN Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 3H-11 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: 3H-11A @ 69.60ft(Nordic 3(38.7+30.9)) Project: Kuparuk River Unit MD Reference: 3H-11A @ 69.60ft(Nordic 3(38.7+30.9)) Site: Kuparuk 3H Pad North Reference: True Well: 3H-11 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3H-11A Design: 3H-11A(wp11a) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N!-S +E/-W Northing Easting DLS Vert Section (ft) (°) (*) (ft) ft (ft) (ft) (ft) (ft) 2,620.00 3,077.10 34.62 86.33 2,689.60 2,620.00 -125.87 1,276.92 6,000,299.29 499,932.21 4.00 1,252.06 WEST SAK A4 3,100.00 33.96 85.19 2,708.52 2,638.92 -124.91 1,289.78 6,000,300.24 499,945.07 4.00 1,264.94 3,143.20 32.75 82.95 2,744.60 2,675.00 -122.47 1,313.40 6,000,302.68 499,968.69 4.00 1,288.69 WEST SAK A3 3,200.00 31.23 79.76 2,792.78 2,723.18 -117.96 1,343.14 6,000,307.18 499,998.43 4.00 1,318.76 3,220.78 30.69 78.53 2,810.60 2,741.00 -115.95 1,353.64 6,000,309.19 500,008.93 4.00 1,329.42 WEST SAK A2 3,300.00 28.76 73.46 2,879.40 2,809.80 -106.50 1,391.73 6,000,318.63 500,047.02 4.00 1,368.38 3,322.98 28.24 71.87 2,899.60 2,830.00 -103.24 1,402.20 6,000,321.89 500,057.48 4.00 1,379.17 WEST SAK Al 3,350.99 27.63 69.86 2,924.34 2,854.74 -98.94 1,414.60 6,000,326.19 500,069.88 4.00 1,391.99 1 3,400.00 27.63 69.86 2,967.76 2,898.16 -91.12 1,435.94 6,000,334.01 500,091.22 0.00 1,414.13 3,419.00 27.63 69.86 2,984.60 2,915.00 -88.08 1,444.21 6,000,337.04 500,099.49 0.00 1,422.71 BASE W SAK 3,500.00 27.63 69.86 3,056.36 2,986.76 -75.15 1,479.48 6,000,349.96 500,134.75 0.00 1,459.29 3,600.00 27.63 69.86 3,144.96 3,075.36 -59.19 1,523.02 6,000,365.92 500,178.29 0.00 1,504.45 3,700.00 27.63 69.86 3,233.55 3,163.95 -43.22 1,566.56 6,000,381.87 500,221.83 0.00 1,549.61 3,776.80 27.63 69.86 3,301.60 3,232.00 -30.96 1,600.00 6,000,394.13 500,255.27 0.00 1,584.30 Tabasco 3,800.00 27.63 69.86 3,322.15 3,252.55 -27.26 1,610.10 6,000,397.83 500,265.37 0.00 1,594.77 3,900.00 27.63 69.86 3,410.75 3,341.15 -11.29 1,653.64 6,000,413.78 500,308.91 0.00 1,639.94 4,000.00 27.63 69.86 3,499.34 3,429.74 4.67 1,697.18 6,000,429.74 500,352.45 0.00 1,685.10 4,087.20 27.63 69.86 3,576.60 3,507.00 18.59 1,735.14 6,000,443.65 500,390.41 0.00 1,724.48 Base Tabasco 4,100.00 27.63 69.86 3,587.94 3,518.34 20.64 1,740.72 6,000,445.69 500,395.99 0.00 1,730.26 4,200.00 27.63 69.86 3,676.54 3,606.94 36.60 1,784.26 6,000,461.65 500,439.53 0.00 1,775.42 4,300.00 27.63 69.86 3,765.13 3,695.53 52.57 1,827.80 6,000,477.60 500,483.07 0.00 1,820.58 4,400.00 27.63 69.86 3,853.73 3,784.13 68.53 1,871.34 6,000,493.56 500,526.60 0.00 1,865.74 4,500.00 27.63 69.86 3,942.33 3,872.73 84.50 1,914.88 6,000,509.51 500,570.14 0.00 1,910.90 4,600.00 27.63 69.86 4,030.92 3,961.32 100.46 1,958.42 6,000,525.47 500,613.68 0.00 1,956.07 4,700.00 27.63 69.86 4,119.52 4,049.92 116.42 2,001.96 6,000,541.42 500,657.22 0.00 2,001.23 4,800.00 27.63 69.86 4,208.12 4,138.52 132.39 2,045.50 6,000,557.38 500,700.76 0.00 2,046.39 4,900.00 27.63 69.86 4,296.71 4,227.11 148.35 2,089.04 6,000,573.33 500,744.30 0.00 2,091.55 5,000.00 27.63 69.86 4,385.31 4,315.71 164.32 2,132.58 6,000,589.29 500,787.84 0.00 2,136.71 5,100.00 27.63 69.86 4,473.91 4,404.31 180.28 2,176.12 6,000,605.24 500,831.38 0.00 2,181.87 5,200.00 27.63 69.86 4,562.50 4,492.90 196.25 2,219.66 6,000,621.20 500,874.92 0.00 2,227.03 5,300.00 27.63 69.86 4,651.10 4,581.50 212.21 2,263.20 6,000,637.15 500,918.46 0.00 2,272.20 5,400.00 27.63 69.86 4,739.70 4,670.10 228.18 2,306.74 6,000,653.11 500,961.99 0.00 2,317.36 5,500.00 27.63 69.86 4,828.29 4,758.69 244.14 2,350.28 6,000,669.06 501,005.53 0.00 2,362.52 5,600.00 27.63 69.86 4,916.89 4,847.29 260.11 2,393.82 6,000,685.02 501,049.07 0.00 2,407.68 5,693.23 27.63 69.86 4,999.49 4,929.89 274.99 2,434.42 6,000,699.89 501,089.66 0.00 2,449.78 5,700.00 27.75 69.35 5,005.48 4,935.88 276.09 2,437.37 6,000,700.99 501,092.61 4.00 2,452.84 5,800.00 29.81 62.22 5,093.15 5,023.55 295.89 2,481.16 6,000,720.79 501,136.41 4.00 2,498.73 5,900.00 32.21 55.99 5,178.87 5,109.27 322.40 2,525.27 6,000,747.28 501,180.51 4.00 2,545.73 9/11/2012 4:08:33PM Page 4 COMPASS 2003.16 Build 69 Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 3H-11 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: 3H-11A @ 69.60ft(Nordic 3(38.7+30.9)) Project: Kuparuk River Unit MD Reference: 3H-11A @ 69.60ft(Nordic 3(38.7+30.9)) Site: Kuparuk 3H Pad North Reference: True Well: 3H-11 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3H-11A Design: 3H-11A(wpl la) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +Ei-W Northing Easting DLS Vert Section (ft) (1 (*) (ft) ft (ft) (ft) (ft) (ft) 5,192.64 6,000.00 34.87 50.58 5,262.24 5,192.64 355.47 2,569.46 6,000,780.34 501,224.70 4.00 2,593.62 6,100.00 37.74 45.87 5,342.84 5,273.24 394.94 2,613.52 6,000,819.80 501,268.77 4.00 2,642.17 6,200.00 40.77 41.74 5,420.27 5,350.67 440.63 2,657.24 6,000,865.48 501,312.49 4.00 2,691.13 6,300.00 43.93 38.11 5,494.18 5,424.58 492.31 2,700.41 6,000,917.15 501,355.66 4.00 2,740.28 6,332.96 45.00 37.00 5,517.70 5,448.10 510.62 2,714.48 6,000,935.45 501,369.74 4.00 2,756.47 6,400.00 45.00 37.00 5,565.10 5,495.50 548.48 2,743.00 6,000,973.30 501,398.27 0.00 2,789.40 6,500.00 45.00 37.00 5,635.82 5,566.22 604.95 2,785.56 6,001,029.76 501,440.83 0.00 2,838.52 6,600.00 45.00 37.00 5,706.53 5,636.93 661.42 2,828.11 6,001,086.22 501,483.39 0.00 2,887.64 6,700.00 45.00 37.00 5,777.24 5,707.64 717.89 2,870.67 6,001,142.68 501,525.95 0.00 2,936.76 6,737.28 45.00 37.00 5,803.60 5,734.00 738.95 2,886.53 6,001,163.73 501,541.82 0.00 2,955.07 Base HRZ 6,800.00 45.00 37.00 5,847.95 5,778.35 774.37 2,913.22 6,001,199.13 501,568.51 0.00 2,985.88 6,892.85 45.00 37.00 5,913.60 5,844.00 826.80 2,952.73 6,001,251.55 501,608.03 0.00 3,031.49 K-1 6,900.00 45.00 37.00 5,918.66 5,849.06 830.84 2,955.78 6,001,255.59 501,611.07 0.00 3,035.00 6,986.33 45.00 37.00 5,979.70 5,910.10 879.59 2,992.51 6,001,304.33 501,647.81 0.00 3,077.40 7"Casing n 6986'MD,5980'TVD:353'FNL,2006'FEL-Sec12-T12N-R08E-7"x 8 3/4" 7,000.00 45.00 37.00 5,989.37 5,919.77 887.31 2,998.33 6,001,312.05 501,653.63 0.00 3,084.12 ' 7,000.33 45.00 37.00 5,989.60 5,920.00 887.49 2,998.47 6,001,312.24 501,653.77 0.00 3,084.28 Top KUP D @ 7000'MD,5990'TVD:345'FNL,2000'FEL-Sec12-T12N-R08E-Kup D 7,015.88 45.00 37.00 6,000.60 5,931.00 896.28 3,005.09 6,001,321.02 501,660.39 0.00 3,091.92 Kup C4 7,047.00 45.00 37.00 6,022.60 5,953.00 913.85 3,018.33 6,001,338.59 501,673.63 0.00 3,107.20 Kup Cl 7,049.82 45.00 37.00 6,024.60 5,955.00 915.45 3,019.54 6,001,340.18 501,674.84 0.00 3,108.59 B ' 7,100.00 45.00 37.00 6,060.08 5,990.48 943.78 3,040.89 6,001,368.51 501,696.19 0.00 3,133.24 7,112.05 45.00 37.00 6,068.60 5,999.00 950.59 3,046.02 6,001,375.31 501,701.32 0.00 3,139.16 A5 7,127.61 45.00 37.00 6,079.60 6,010.00 959.37 3,052.64 6,001,384.10 501,707.94 0.00 3,146.80 A3 7,151.65 45.00 37.00 6,096.60 6,027.00 972.95 3,062.87 6,001,397.67 501,718.18 0.00 3,158.61 3H-11A(wp09)T1 7,155.89 45.00 37.00 6,099.60 6,030.00 975.34 3,064.67 6,001,400.07 501,719.98 0.00 3,160.69 Top KUP A2 @ 7156'MD,6100'TVD:257'FNL,1933'FEL-Sec12-T12N-R08E-A2 7,199.73 45.00 37.00 6,130.60 6,061.00 1,000.10 3,083.33 6,001,424.82 501,738.64 0.00 3,182.23 Al 7,200.00 45.00 37.00 6,130.79 6,061.19 1,000.25 3,083.44 6,001,424.97 501,738.75 0.00 3,182.36 7,266.34 45.00 37.00 6,177.70 6,108.10 1,037.72 3,111.67 6,001,462.42 501,766.99 0.00 3,214.95 7,267.61 45.00 37.00 6,178.60 6,109.00 1,038.44 3,112.22 6,001,463.14 501,767.53 0.00 3,215.57 Base Kup 7,300.00 45.00 37.00 6,201.50 6,131.90 1,056.73 3,126.00 6,001,481.43 501,781.32 0.00 3,231.48 7,375.23 45.00 37.00 6,254.70 6,185.10 1,099.21 3,158.01 6,001,523.90 501,813.34 0.00 3,268.43 TD @ 7375'MD,6255'TVD:133'FNL,1840'FEL-Sec12-T12N-R08E 9/11/2012 4:08:33PM Page 5 COMPASS 2003.16 Build 69 Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 3H-11 Company: ConocoPhillips(Alaska)Inc.-Kup2 ND Reference: 3H-11A @ 69.60ft(Nordic 3(38.7+30.9)) Project: Kuparuk River Unit MD Reference: 3H-11A @ 69.60ft(Nordic 3(38.7+30.9)) Site: Kuparuk 3H Pad North Reference: True Well: 3H-11 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3H-11A Design: 3H-11A(wplla) Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E1-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) 3H-11A vv,'p09)_,I 0.00 0.00 6,096.60 972.95 3,062.87 6,001,397.67 501,718.18 -plan hits target center -Circle(radius 100.00) 7,375.25 6,254 71 4 1/2"x 6 1/8" 4-1/2 6-1/8 6,986.33 5,979.70 7"x 8 3/4" 7 8-3/4 2,700.02 2,400.09 103/4"TOW 10-3/4 13-1/2 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (°) (°) 4,087.20 3,576.60 Base Tabasco 0.00 3,220.78 2,810.60 WEST SAK A2 0.00 7,155.89 6,099.60 A2 0.00 2,670.08 2,377.60 UGNU A 0.00 6,892.85 5,913.60 K-1 0.00 7,047.00 6,022.60 Kup Cl 0.00 7,127.61 6,079.60 A3 0.00 3,077.10 2,689.60 WEST SAK A4 0.00 3,046.56 2,664.60 WEST SAK B 0.00 3,419.00 2,984.60 BASE W SAK 0.00 3,011.94 2,636.60 WEST SAK C 0.00 3,143.20 2,744.60 WEST SAK A3 0.00 7,267.61 6,178.60 Base Kup 0.00 7,112.05 6,068.60 A5 0.00 2,969.27 2,602.60 WEST SAK D 0.00 7,015.88 6,000.60 Kup C4 0.00 7,000.33 5,989.60 Kup D 0.00 6,737.28 5,803.60 Base HRZ 0.00 3,322.98 2,899.60 WEST SAK Al 0.00 3,776.80 3,301.60 Tabasco 0.00 2,758.92 2,443.60 NB 0.00 7,049.82 6,024.60 B 0.00 7,199.73 6,130.60 Al 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 2,700.00 2,400.07 -110.19 1,036.87 TOW @ 2700'MD,2400'TVD:1342'FNL,1318'FWL-Sec12-T12N-R08E 6,986.33 5,979.70 879.59 2,992.52 7'Casing @ 6986'MD,5980'TVD:353'FNL,2006'FEL-Sec12-T12N-RO8E 7,000.33 5,989.60 887.50 2,998.47 Top KUP D @ 7000'MD,5990'ND:345'FNL,2000'FEL-Sec12-T12N-R08E 7,155.89 6,099.60 975.34 3,064.67 Top KUP A2 @ 7156'MD,6100'1VD:257'FNL,1933'FEL-Sec12-T12N-R08E 7,375.23 6,254.70 275.01 2,434.48 TD @ 7375'MD,6255'TVD:133'FNL,1840'FEL-Seci2-T12N-R08E 9/11/2012 4:08:33PM Page 6 COMPASS 2003.16 Build 69 3H-11A Slot Recovery Proposed Schematic Haibin Guo, updated September 2012 16"conductor set at 115' Schlumberger TRMAXX-CMT-5-SR @ 1,930'MD/1,800'TVD 3-1/2"9.3#,L-80,EUE Tubing GLM # TVD ft MD ft Valve Type 1.1 1 2,500 2,835 Dummy 2 3,700 4,399 Dummy 10-3/4"Whipstock @2,700'MD 3 4,600 5,406 Dummy 4 5,295 6,184 Dummy l. 5 5,795 6,863 SOV (annulus to 7"cemented stub @2,750'MD tubing shear) Note: 5 ea Camco 3-1/2"x 1-1/2" MMG IIIII 10-3/4"J-55,45.5#surface casing @ 3,637'MD. 2"d TAM Port Collar @+1-3,700'MD :01 • Bottom of Cement @ 4,250'MD Tabasco sand @3,950'—4,300'MD ,. . 9 l''TAM Port collar+/-4,900'MD Set cement in 7"casing from 4,365' ` 5,600'MD :::L::_:: TOC @5,800'MD/4,957'TVD 3-'/2'tubing Cut @+/-5,600' TOC in 7"&3-'/2"tubing @+/- 5,800' Q3 '/2" HES"X"selective nipple w/2.813" .ii\X 1 .. ID @+/-6,904'MD, /5,824'TVD Cement Retainer+/-7,164'MD Baker ZXP liner top Packer@ 6,924' 1: MD/5,838'TVD .V` •7"26#L80 BTCM casing set(topset) @ 7,124'MD/5,980'TVD 1 4-1/2" 12.6#L80 IBTM Liner set ILI 41 '414 @ 7,513'MD/6,255'TVD I Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, August 31, 2012 11:10 AM To: 'Myers, Monty M' Cc: Regg, James B (DOA) Subject: RE: 3H-11A BOPE Question? (PTD 187-124) (212-062) Monty, I looked at the procedure... there is no detail in there about pulling the BOP stack and tubing spool to pull 7" casing. (It can be inferred and you provided the Wellhead showing a 3000 psi 11"flange that would be used for the BOP stack after the tubing spool is pulled.) That detail should have been spelled out in the procedure and requested a lower pressure in writing. There is no other option: test to 3000 psi .. assume you are testing against the 7" plug set at 4900' md. Document reasons in BOP test report submitted and reference this email. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Myers, Monty M [mailto:Monty.M.Myers@conocophillips.com] Sent: Friday, August 31, 2012 10:34 AM To: Schwartz, Guy L(DOA) Subject: 3H-11A BOPE Question? Guy, I am covering the 3H-11A(Permit#212062, API#50-103-2009-01-00)for Haibin Guo while he is out of the office. A question came up this morning about the BOP test that I need to discuss with you. We have written in the permit to test the BOP stack to 3500 psi, but after we nipple down the tubing head to perform our 7"casing cut and recover, we will not be able to install a test plug in the casing head to isolate the spool below us that is only rated to 3000 psi. My question is, can we use 3000 psi for our test in this section? We will be working in cased and cemented hole while recovering the 7" csg. Thanks. Monty M Myers Drilling Engineer ConocoPhillips Alaska 907.265.6318 office 907.538.1168 cell 8/31/2012 Page 1 of 3 • Schwartz, Guy L (DOA) From: Guo, Haibin [Haibin.Guo@conocophillips.com] Sent: Thursday, September 20, 2012 9:45 AM To: Guo, Haibin; Schwartz, Guy L(DOA) Subject: RE: Change of 3H-11A 2nd Stage Cement PTD(212 062) Guy, We just drilled through Tabasco sand this morning. It is shallower than we thought 3778'-3880' MD as attached log. We still plan to set 500'+cement above top of Tabasco TOC @3200' MD and set bottom of cement(stage collar)@ 4000' MD. If you have any comments, please let me know. Thanks 9/20/2012 Page 2 of 3 --- - --- 3750 -----. -• .... #�z ,• 3800 N--f--- —.._ ,' t T - 3z: 3850 ---...__�.... _. V —att.; , 3900 • -,•.• 1 • ' - 3950 -- —_M_. - ----•• MD=3970.53 ft - 4000 ----• 1 Sin Phase Resistivity=3.7 ohmr I I 1 .- — --__.. 39in Phase Resistivity=4.05 oh( —•— —r �---- --- -- �� 4,-- _ 4050 !--- --•• - • 4100 ----- i I •., 4150 ------- -•—•----- imi 4200 — ;------._ MI I 9/20/2012 Page 3 of 3 Haibin Guo Drilling Engineer ConocoPhillips Alaska Office: 907.265.1487 Cell:907.297.9113 From: Guo,Haibin Sent: Tuesday,September 18,2012 10:57 AM To: 'Schwartz,Guy L(DOA)' Subject: Change of 3H-11A 2nd Stage Cement PTD(212 062) Guy, In the issued PTD 212062 for 3H-11A,we planned to run 2 ea Stage collars for the 2nd Stage Cementing job to set cement at 3700'-4900'. Tabasco sand is at 3950'-4300'. The reason we wanted to 2 ea stage collars was to ensure TOC is low, the surface casing shoe(3637') is free of cement for later freeze protect. Since we kicked off high at 2701' MD(original plan was at 3720'), TOC is not an issue for the freeze protect. Our current plan is to run 1 ea stage collar at 4300' (base of Tabasco)and have the TOC at 3450' (500'above top of Tabasco). Attached are the new proposal schematic, old schematic, new cement design, issued PTD 212062. If you need more information, let me know. Can please you approve this change? Thanks. << File: 3H-11A Proposed Schematic V9.pdf>> << File: Old schematic.pdf>> << File: 3H-11, 7in Intermediate 2nd Stage Summary v5 9.18.12.pdf>> << File:Approved permit 3H-11A 212062.pdf» Haibin Guo Drilling Engineer ConocoPhillips Alaska Office: 907.265.1487 Cell:907.297.9113 9/20/2012 STATE OF ALASKA AL A OIL AND GAS CONSERVATION COMI\,._.;,ON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair well r Rug Perforations r Perforate r Other r Prod to WINJ Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program r Operat.Shutdown 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 212-062-0 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service r — 50-103-20091-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL025531 -- 3H-11A- 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): .- Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7375 feet Plugs(measured) None true vertical 6258 feet Junk(measured) None Effective Depth measured 7322 feet Packer(measured) 26,2701,6776,6826,7065 true vertical 6220 feet (true vertical) 26,2401, 5837,5873,6040 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 115 115 0 0 WINDOW A 20 10.75 2721 2416 0 0 SURFACE 3602 10.75 3637 3088 0 0 PRODUCTION 6879 7 6907 5929 0 0 WINDOW AL1 6 4.5 7072 6044 0 0 LINER A 562 5.98 7375 6258 0 0 Perforation depth: Measured depth: 7285-8452, 7207-8699 True Vertical Depth: 6099-6087,6009-6061 Tubing(size,grade,MD,and TVD) 3.5, L-80,6825 MD, 5872 TVD A r: Packers&SSSV(type,MD,and TVD) HANGER-FMC TUBING HANGER @ 26 MD and 26 TVD WHIPSTOCK-WHIPSTOCK SET FOR SIDETRACK A @ 2701 MD and 2401 TVD NIPPLE-HES X NIPPLE @ 6776 MD and 5837 TVD SEAL ASSY-BAKER SEAL ASSEMBLY W/20'STROKE AND 1/2 MULESHOE(-6'OFF LOCATOR)@ 6826 MD and 5873 ND WHIPSTOCK-SET FOR CTD LATERALS AL1,AL1-01 @ 7065 MD and 6040 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 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 Subsequent to operation 308 825 1516 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service 17, Stratigraphic r 16.Well Status after work: _ Oil r Gas r WDSPL r Daily Report of Well Operations /C GSTOR r WINJ r; WAG r 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: 313-113 Contact Bob_ hristensen/Darrell Humphrev Email N1139t conocophillips.com Printed Name lee D - ' tense Title NSK Production Engineering Specialist Signature Phone:659-7535 Date 1cW/5 I 1,2V Form 10-404 Revised 12/R8DMS MAR 2 9 2013( V� /� Sub it Original Only 4// // ,405-spit 3H-11A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 03/20/13 PULLED OV&GLVs @ 6593', 5978', 5303', 4256' &2867' RKB. SET DVs @ 5978', 5303', 4256' &2867' RKB. IN PROGRESS. 03/21/.13 LOADED IA WITH INHIBITED SW& DSL CAP. CMIT FAILED. SET DV @ 6593' RKB. MIT IA 2500 PSI, PASSED. PULLED AVA CATCHER @ 6776' RKB. 03/25/13 Commenced WINJ service KUP III 3H-11A Ds i Conoco`Phillips Wel Attributes Max Angle&MD TO Alaska Inc Wellbore APA WI Field Name Well Status Incl(°) MD MB) Act Btm(ftKB) 501032009101 KUPARUK RIVER UNIT PROD 46.18 7,165.15 7,375.0 Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date '- WeIICon(ig.DEVIATED-3H-11A312720139'4S.07 AM SSSV:TRDP 245 11/26/2009 Last WO: 8/17/2012 42.01 12/28/1987 _ -- --Schematic•Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:WAIVER CANCELLED 3/20/2013 osborl 3/27/2013 HANGER,26- r Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd CONDUCTOR 16 15.062 35.5 115.0 115.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt..String... String Top Thrd SURFACE 103/4 9.950 35.2 3,637.1 3,178.4 45.50 J-55 BTC Cavin Description 0... String ID...Top(MB) 8h 9String 9 ( ) Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd ..= WINDOWA 103/4 8.000 2,701.0 2,721.0 2,415.7 d Casing Description String 0... String ID...lop(RKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd _row CONDUCTOR. PRODUCTION 7 6.276 27.9 6,907.2 5,929.0 26.00 L-80 BTC 35115 POST S/F o Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd LINER A 4 1/2 3.930 6,813.0 7,375.0 12.60 L-80 IBT-M SAFETY VLV, 1,978 Liner Details Il▪iTop Depth ,___._...___._._____ (ND) Top Incl Noma... WHIPSTOCK. Top(ftKB) (ftKB) C) Item Description Comment ID(in) 2,701\ WINDOW A. F - 6,813.0 5,863.1 45.40 PACKER BAKER ZXP LINER TOP PACKER 4.410 . 2.701-2,711 - _ 6,831.5 5,876.2 45.58 HANGER BAKER KSI HYDRAULIC FLEX LOCK HANGER---- 4.470 6,842.1 5,883.6 45.69 SBE 80-40 SEAL BORE EXTENSION 4.000 GAS LIFT, 2,867 - - Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd WINDOW AL1 41/2 3.958 7066.0 L70720 6,04I 111 6.3 Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(1...Set Depth(TVD)...Siring Wt...Stnng... String Top Thrd TUBING WO 2012 31/2 2.992 26.0 6,863.0 5,898.4 9.30 L-80 EUE8RDMOD Completion Details Top Depth SURFACE, j II (TVD) Top Incl Nomi... 353,637 Top(ftKB) (ftKB) C) Item Description Comment ID(in) i 26.0 26.0 -0.01 HANGER FMC TUBING HANGER 3.950 1,978.3 1,839.0 37.57 SAFETY VLV CAMCO TRMAXX-CMT-SR-5 SAFETY VALVE w/2.813"PROFILE 2.812 6,776.3 5,837.4 45.03 NIPPLE HES X NIPPLE 2.813 II6,825.1 5,871.7 45.52 LOCATOR BAKER 80-40 GBH-22 LOCATOR SUB 3.000 GAS LIFT. 6,826.4 5,872.6 45.53 SEAL ASSY BAKER SEAL ASSEMBLY w/20'STROKE AND 1/2 MULESHOE C6' 2.990 4.256 -- - �: OFF LOCATOR) ill 'For In Hole(Vireline retrievable plugs,valves,pumps,fish,etc.) Top Depth . (ND) Top Incl GAS LIFT_ Top(RKB) (ftKB) Cl Description Comment Run Date ID(in) 5'303 2,701.0 2,400.8 41.44 WHIPSTOCK WHIPSTOCK SET FOR SIDETRACK A 9/17/2012 ■I 7,065.0 6,039.7 44.89 WHIPSTOCK SET FOR CTD LATERALS AL1,AL1-01 11/21/2012 - : _ NOtes:GenerSi "I"1 VP End Date Annotation 4/30/1999 NOTE:WORKOVER GAS LIFT, 5,978 7/21/2001 NOTE:WORKOVERIL 8/17/2012 NOTE:WELL WORKOVER/SIDETRACK'A'-Original Prod Csg cut/pulled @ 2451' ■ 12/2/2012 NOTE:CTD ADDED LATERALS AL1,AL1-01 1.1 GAS LIFT - 6,593 a a a NIPPLE,6,776 --- Ili. IL I LOCATOR, 6,825 I!. SEAL ASSY, 6826 .( PRODUCTION (, POST Sir, 28-6,907 Mandrel Details -- WHIPSTOCK, Top Depth Top I Port 7,065 a g,,, (ND) Incl OD Valve Latch Size TRO Run WINDOW ALI. f N...Top(ftKB) (ftKB) C) Make Model (in) Sery Type Type (in) (psi) Run Date Cont.. 7,066-7,072 LINER A. 1 2,867.4 2,524.0 41.74 CAMCO MMG 1 12 GAS LIFT GLV R-20 0.188 1,300.0 12/11/2012 6.813.7,375 TD(3H-11A), 2 4,255.9 3,723.1 26.79 CAMCO MMG 1 12 GAS LIFT GLV R-20 0.188 1,277.0 12/122012 7,375 SLOTS, 3 5,302.7 4,651.926.44 CAMCO MMG 1 12 GAS LIFT GLV R-20 0.188 1,256.0 12/12/2012 7.027.8,700 Liner AL1-01, 4 5,978.4 5,243.432.82 CAMCO MMG 112 GAS LIFT GLV R-20 0.188 1,237.0 12/122012 7,026A,700 5 6,593.4 5,707.545.04 CAMCO MMG 1 1/2 GAS LIFT OV rdo20 0.250 0.0 12/11/2012 I%%,s THE STATE Alaska Oil and Gas g ;71AM OPAL aSKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue O e• Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Darrell R. Humphrey NSK Production Engineering Specialist f ConocoPhillips Alaska, Inc. off, fa-- 0 '" P.O. Box 100360 ��---' Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 31-1-11A Sundry Number: 313-113 Dear Mr. Humphrey: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair DATED this ��day of March, 2013. Encl. ` STATE OF ALASKA o1� I KA OIL AND GAS CONSERVATION COMMI; N 1•I4 APPLICATION FOR SUNDRY APPROVALS 3 20 AAC 25.280 1.Type of Request: Abandon ❑ Aug for Redrill ❑ Perforate New Pool ❑ Repair w ell ❑ Change Approved Program ❑ Suspend ❑ Aug Perforations ❑ Perforate ❑ Pull Tubing ❑ lime Extension ❑ Operational Shutdown ❑ Re-enter Susp.Well ❑ Stimulate ❑ Aker casing ❑ Other: Prod to WINJ . M. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Development 17. Exploratory ❑ 212-062-0 3.Address: Stratigraphic❑ Service ❑ 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-103-20091-01 • 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes ❑ No P 3H-11A 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL-25531. Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): • 7375 6258 • 7322' 6220' None None Casing Length Size MD ND Burst Collapse CONDUCTOR 80 16 115' 115' WINDOW 20 10.75 2721' 2416' RECEIVED SURFACE 3602 10.75 3637' 3088' PRODUCTION 6879 7 6907' 5929' M 4R 0 5 2013 WINDOW AL1 6 4.5 7072' 6044' /� (�(� LINER A 562 5.98 7375' 6258' AOG CC Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7285-8452,7207-8699 6099-6087,6009-6061 3.5 L-80 6825 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) HANGER-FMC TUBING HANGER MD=26 TVD=26 • WHIPSTOCK-WHIPSTOCK SET FOR SIDETRACK A MD=2701 ND=2401. NIPPLE-HES X NIPPLE MD=6776 TVD=5837 SEAL ASSY-BAKER SEAL ASSEMBLY W/20'STROKE AND 1/2 M MD=6826 TVD=5873 • WHIPSTOCK-SET FOR CTD LATERALS AL1,AL1-01 MD=7065 TVD=6040 • SSSV-CAMCO TRMAXX-CMT-SR-5 MD=1978 TVD=1839. 12.Attachments: Description Summary of Proposal 17. 13. Well Class after proposed work: Detailed Operations Program 17 BOP Sketch 17Exploratory ❑ Stratigraphic ❑ Development ❑ Service t114 • 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/7/2013 Oil In Gas M. WDSPL ❑ Suspended 16.Verbal Approval: Date: WINJ P1• GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen/Darrell Humphrey Email: N1139anconocophillios.com Printed Name Darrell R. Huhre Title: NSK Production Engineering Specialist Signature 1 � �\''�1 Phone:659-7535 Date 3. 3.. /3 Commission Use Only Sundry Number: l I ,3 Conditions of approval: Notify Commission so that a representative may witness / / Plug Integrity❑ BOP Test ❑ Mechanical Integrity Test rj Location Clearance ❑ ` Other: to (n!! t5-5 _r!/ / '` L7—Lt Cl 14 6_, 1( ! e ef / re GS `NsDMS MAR 12 2O Spacing Exception Required? Yes El No [►( Subsequent Form Required: I G+ —..0 /1, APPROVED BY `� Approved by: P _ COMMISSIONER THE COMMISSION - Date:3 -ll- �-3 GRujfNA0[. Appodapliation is valid for'12-months from the date of approal. -SubmitFormandAttachmentsin Duplicate 3H-11A DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 3H-11A and its associated laterals from Oil Production service to Water Injection service. The CTD Permit to Drill (which added multi-laterals AL1, AL1-01)was completed with the well as an injection well, but the completion report was filed as an oil producer to allow for extended pre-production. The pre-production period following CTD operations has now been completed and the well is being prepared for initial water injection. t KUP 3H-11A ConocoPhiIIips Well Attributes Max Angle&MD TO Alaska,Inc. ? Wellbore API/UWI Field Name Well Statue 'Incl(°) MD(ftKB) Act Btm(ftKB) lo.xxol+whps`t 501032009101 KUPARUK RIVER UNIT PROD 46.18 7,165.15 7,375.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ••, Well Config DEVIATED-3H-IIA.1124/20136:27:09AM SSSV:TRDP 245• 11/26/2009 Last WO: 8/17/2012 42.01 12/28/1987 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:GLV C/O osborl 1/24/2013_ HANGER,26Casing Strings -dosing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 35.5 _ 115.0 115.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth)TVD)...String Wt...String...String Top Thrd SURFACE 103/4 9.950 35.2 3,637.1 3,178.4 45.50 J-55 BTC Casing Deecripion String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd WINDOW A 103/4 8.000 2,701.0 2,721.0 2,415.7 Cuing Deacripiton String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd coNoucroR. PRODUCTION 7 6.276 27.9 6,907.2 5,929.0 26.00 L-80 BTC 35-115 POST S/T Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd LINER A 4 1/2 3.930 6,813.0 7,375.0 12.60 L-80 IBT-M SAFETY VLV, 1,970 l''1 i Liner Details Top Depth (TVD) Top Incl Semi... WHIPSTOCKt Top(ftKB) (ftKB) (°) Item Description Comment ID(in) 2,701A.\ WINDOW A, A 6,813.0 5,863.1 45.40 PACKER BAKER ZXP LINER TOP PACKER 4.410 2.701-2'721 6,831.5 5,876.2 45.58 HANGER BAKER KSI HYDRAULIC FLEX LOCK HANGER 4.470 6,842.1 5,883.6' 45.69 SBE 80-40 SEAL BORE EXTENSION 4.000 GAS LIFT, _ ` __ 2.867 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String... String Top Thrd • WINDOW AL1 4 1/2 3.958 7,066.0 7,072.0 6,046.3 IN Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd TUBING WO 2012 3 1/2 2.992 26.0 6,863.0 5,898.4 9.30 L-80 EUE8RDMOD SUR-ACE, Completion Details Top Depth (ND) Top Incl Noml... x,6 3537 Top(ftKB) (ft(B) (°) Item Description Comment ID(in) 26.0 26.0 -0.01 HANGER FMC TUBING HANGER 3.950 ( 1,978.31 1,839.0 37.57 SAFETY VLV CAMCO TRMAXX-CMT-SR-5 SAFETY VALVE w/2.813"PROFILE 2.812 6,776.3 5,837.4 45.03 NIPPLE HES XNIPPLE 2.813 6,825.11 5,871.7 45.52 LOCATOR BAKER 80-40 GBH-22 LOCATOR SUB 3.000 GAS LIFT, III 5,872.6 45.53 SEAL ASSY BAKER SEAL ASSEMBLY w/20'STROKE AND 1/2 MULESHOE(-6' 2.990 a 256 OFF LOCATOR) Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) III (TVD) Depth (TVD) Top Incl Gas 1=1 ,. Top(ftKB) (ftKB) El Description Comment Run Date ID(in) 5 303 2,701.0 2,400.8 41.44 WHIPSTOCK WHIPSTOCK SET FOR SIDETRACK A 9/17/2012 ■I 7,065.0 6,039.7 44.89 WHIPSTOCK SET FOR CTD LATERALS AL1,AL1-01 11/21/2012 Notes:General&Safety ' 1111End Date Annotation _ _ .,-0 L.r 4130/1999 NOTE:WORKOVER 97°. 7/21/2001 NOTE:WORKOVER 1111 8/17/2012 NOTE:WELL WORKOVER/SIDETRACK'A'-Original Prod Csg cut/pulled @ 2451' U . 12/2/2012 NOTE:CTD ADDED LATERALS AL1,AL1-01 �sL=T 65,3- , ■ ■ ■ NIPPLE 6 776 ■ 1 I LOCATOR, 1.a. 6,825 SEAL ASSY, ., 6,SY, IU PRODUCTION I POST S/T, I • 2643.907 Mandrel Details WHIPSTOCK Top Depth Top Port • 7.065 k (ND) Intl OD Valve Latch Sloe TRO Run WINDOW AL1, N...Top(ftKB) (15KB) El Make Model (in) Sery Type Type (In) (psi) Run Date Com... TON-7.072 LINER A,, 1 2,867.4 2,524.0 41.74 CAMCO MMG 1 1/2 GAS LIFT GLV R-20 0.188 1,300.0 12/11/2012 ' aa13-7,37), TD(311 2 4,255.9 3,723.1 26.79 CAMCO MMG 1 1/2 GAS LIFT GLV R-20 0.188 1,277.0 12/12/2012 7.375 7,375 SLOTS, 3 5,302.7 4,651.9 26.44 CAMCO MMG 1 1/2 GAS LIFT GLV R-20 0.188 1,256.0 12/12/2012 7,027-8,700 Liner 6 4 5,978.4 5,243.4 32.82 CAMCO MMG 1 1/2 GAS LIFT GLV R-20 0.188 1,237.0 12/12/2012 7,0,0er 26-0,4700700 5 6,593.4 5,707.5 45.04 CAMCO MMG 1 1/2 GAS LIFT OV rdo20 0.250 0.0 12/11/2012 ', WELL LOG TRANSMITTAL To: State of Alaska January 10,2013 Alaska Oil and Gas Conservation Commission Attn.: Makana Bender 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501-3539 RE: LWD Formation Evaluation Logs: 3H-11A AK-MW-0009498076 3H-11A 50-103-20091-01 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log 2" x 5"ND TRIPLE COMBO Logs: 1 Color Log Digital Log Images, LAS Data, &DLIS Data w/verification listing 1 CD ROM PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Buster Bryant/Ben Schulze 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-273-3539/907-273-3536 Fax: 907-273-3535 Buster.Bryant@halliburton.com Benjamin.Schulze@ihalliburton.com Date: ed: 3 (�C1Sti�- 2`� Si 6dst ( � �-- RECEIVED ConocoPhillips Nov 0 9 2012 TRANSMITTAL AOGCC CONFIDENTIAL DATA FROM: Sandra D. Lemke,AT01808 TO: Makana Bender ConocoPhillips Alaska, Inc. State of Alaska-AOGCC P.O. Box 100360 333 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501-3539 RE: KRU 3H-11A AOGCC permit: 212-062-0 DATE: 11/7/2012 r.n mitt- .: Kuparuk River Unit, North Slope, Alaska 3H-11A Hardcopy and CDROM t/Final Well report, Mud logging report, Canrig;well 3H-11A(501032009101). Equipment,well data,geological data, pressure/formation strength, drilling data, daily reports,formation logs color prints; Formation log(MD) Formation log(ND)7 Gas ratio (MD)/ Gas ratio (TVD) LWD Combo (MD)' LWD Combo (TVD) Drilling dynamics (MD) Drilling dynamics (TVD)- v'CDROM contains; daily reports, DML data, final well report, LAS files, mud log PDF files, remarks and tiff files 2o"t, c� ? r Sign, scan and return in .pdf format if applicable to Sandra.D.Lemke0Conccophi//ips.com CC: 3H-11A production well files, eSearch Receipt: 1L–.11-5 MINX Date: 9 a,a ).441 1.... GIS-Technical Data Management I ConocoPhillips 1 Anchorage, Alaska i Ph: 907265.6997 AI . - 66Z- Page 1 of 2 4 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, November 02, 2012 2:47 PM To: 'Guo, Haibin' Cc: Jolley, Liz C; Wallace, Chris D (DOA) Subject: RE: 3H-11A 7"casing Tally correction. Permit number: 212062 Haibin, Thank you for being forthwith and letting us know of the casing tally error. The error is relatively minor and does not affect the casing integrity and zonal control as required under UIC rules. As long as the casing tests and liner lap passes an MIT—IA no further action will be needed. The Commission will grant a variance to the 100' lap requirement. BTW.. If you have run a gamma ray log over the casing and liner (with CBL) you might be able to detect the depth of the 7" shoe by looking for a change in the GR attenuation. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Guo, Haibin [mailto:Haibin.Guo@conocophillips.com] Sent: Friday, November 02, 2012 11:58 AM To: Schwartz, Guy L (DOA) Cc: Jolley, Liz C Subject: 3H-11A 7" casing Tally correction. Permit number: 212062 Guy, Well 3H-11A is a Rotary Sidetrack CTD Setup well for two CTD laterals in A2 and A3 sands. Using Nordic 3,well 3H-11A was sidetracked from the 10-3/4"surface casing at 2701'MD. The 8-3/4"hole was drilled and 7"casing run to top setting the Kuparuk sand due to pressure risks. The 6-1/8"production hole was drilled through the Kuparuk sands and a 4-1/2"liner run to TD. The liner was pressure tested and a CBL was run in the 4-1/2"liner indicating good cement bond. To meet the regulation requirements 20 AAC 25.030.D6,"a minimum of 100 feet overlap between the outer and inner strings is required"and the area injection order for Kuparuk,"the packer should be set within 200'above top of pay zone",the design planned for 106'liner overlap. The plan include the 7"casing and the top of liner packer hanger set at 197'above Kuparuk C sand. Recently,an error was found in the casing tally and was corrected. The correct tally indicates the 7"casing shoe is located at 6907'MD. Based on the corrected tally,the liner overlap is 94'and liner top packer is 199'above Kuparuk C described below. Components Depth (top) 4-1/2" Liner packer top 6813' MD 7"casing shoe (bottom) 6907' MD Top of Kuparuk C sand 7012' MD CTD KOPs 7031'-7080' MD. A diagram is attached for your reference. If you have any questions or require further information,please let me know. Sincerely, 11/2/2012 Page 2 of 2 Haibin Guo Drilling Engineer ConocoPhillips Alaska Office: 907265.1487 Cell: 907.297.9113 11/2/2012 3H-11A RKB Change Diagram Original RKB Nordic 3 RKB RKB 42' RKB 27.9' 1 / 7 / Liner top Packer@ 6,813'MD Liner top Packer@ 6,813')1 94'overlap • • : 7"casing set(topset) 7"casingset to se 108'overlap :: ( F.. ::: ::::IhiL @ 6,907'MD @ 6,921'ML1 ::: 14'shallower than we though 199' 199' — Z — — — Kuparuk C sand @7012'MD — — — — L i `'•4-1/2" 12.6#L80 IBTM Liner set :� `4-1/2" 12.6#L80 IBTM Liner @ 7,375'MD/6,258'TVD @ 7,375'MD/6,258'TVD gym~. kw WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 28, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: 6 Arm Caliper/Rotary Sidewall Coring Record: 3H-11A Run Date: 9/21/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3H-11A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20091-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING G G A ND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: \0/1_2-/\2 Signed: GI c"LLLW1- 6-e-64 Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, September 11, 2012 9:21 AM To: 'Guo, Haibin' Cc: Davies, Stephen F (DOA) Subject: RE: 3H-11A kickoff high in surface casing Looks like trying to pull 7" casing down to the surface casing shoe is not very likely. Your plan to set a whipstock at 2700' and (above the current casing stub is approved.) Please send us the new directional plan via email as soon as possible with a explanation letter attached. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Guo, Haibin [mailto:Haibin.Guo@conocophillips.com] Sent: Monday, September 10, 2012 11:01 AM To: Schwartz, Guy L (DOA) Subject: RE: 3H-11A kickoff high in surface casing Guy, More information for you. We set cement in 7"casing 5600' MD -4365' MD with two cement plugs before the cut and pull. We'll do the integrity test with 1500 psi for surface casing and the cement plugs before set whipstock. So maybe we do not need to set another plug in surface casing. Attached is the CBL we got for 7" casing. If you need more information, let me know. Thanks. Haibin Guo Drilling Engineer ConocoPhillips Alaska Office: 907.265.1487 Cell: 907.297.9113 ember 10,2012 10:39 AM L(DOA)' 1 kickoff high in surface casing Guy, The original plan is cut and pull 7" casing from 4300' MD. Kick off and sidetrack at 3720' MD. We ran CBL in 7"casing after pulling the tubing, found the TOC in 7" x 10-3/4"was at 2472' MD. Much higher than we thought. We ran 9-5/8"washover shoe and washpipe to wash over the 7", but made slow progress. Managed washover to 2541' MD last Wednesday. Ran 5-1/2" multi-string cutter to cut 7", could not get the cutter in. Ran 6-1/8"tapered mill to dress and clean the 7", could not go deeper either. Ran 7" casing spear, fished out 60.32'washed 7". 32'washed 7" still in hole. Ran 9-3/4"junk mill, no progress, the casing was spinning. Ran 6-1/8" swage tool, recovered 14.63'washed 7". Ran 9-3/4"junk mill and milled to 2540' MD yesterday. 9/11/2012 Page 2 of 2 Right now we are trying to use 8-1/4" pilot mill to chew up 7"casing to 2720' MD. Set whipstock and kickoff with the top of window at 2700' MD. If pilot mill could not make progress, we may need to kickoff at current depth (2540' MD). The targets will keep the same. Can you please approve us to kickoff higher? Thanks. 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'- • 1�"'., 'wrf ,-�., {n.....--- --V t a 4 r. 1 A. . til;�^fn f�'ti4)'. °.� Yy +rty J� CO ,...6,41rit ' 1 If k L I !I`l1.1! ! s n ^ ~ -I er O O O q :: p 7 0 3 C. r 1=",`'' I' il L Li A .a _,A , A SEAN PARNELL,GOVERNOR ,_: b Li V,', Lil ALASKA OIL AND GAS 333 W 7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 G. L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3H-11A ConocoPhillips Alaska, Inc. Permit No: 212-062 Surface Location: 1232' FNL, 281' FWL, SEC. 12, T12N, RO8E, UM Bottomhole Location: 132' FNL, 1839' FEL, SEC. 12, T12N, RO8E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, ;.?..,„-)(74"-- Cathy . Foerster //*-- Chair DATED this it day of May, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 0 4 2012 PERMIT TO DRILL n^ 20 MC 25.005 AOGCC 1 a.Type of Work. lb.Proposed Well Class. Development-Oil ❑ Service-Winj a • Single Zone a • 1 c.Specify if well is proposed for Dnll ❑ Re-drill a Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-lisp ❑ Shale Gas ❑ 2.Operator Name: 5 Bond U Blanket H Single Well 11 Well Name and Number. ConocoPhillips Alaska, Inc. Bond No. 59-52-180 ' 3H-11A • 3.Address. 6.Proposed Depth 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD:7513' • ND: 6255' • Kuparuk River Field 4a. Location of Well(Governmental Section) 7.Property Designation(Lease Number): Surface: 1232'FNL,281'FWL,Sec. 12,T12N,RO8E,UM• ADL 25531 • Kuparuk River Oil Pool Top of Productive Horizon: 8 Land Use Permit: 13.Approximate Spud Date: 259'FNL, 1935'FEL,Sec. 12,T12N,RO8E,UM 2657 6/27/2012 Total Depth: 9.Acres in Property: 14.Distance to 132'FNL, 1839'FEL,Sec. 12,T12N,RO8E, UM • 2560 Nearest Property: >1 mile 4b Location of Well(State Base Plane Coordinates-NAD 27) 10 KB Elevation above MSL: 69 feet 15.Distance to Nearest Well Open Surface:x- 498655• y- 6000425 ' Zone- 4 GL Elevation above MSL 39 feet to Same Pool: 3H-11 ,1242'@ 7152' 16 Deviated wells: Kickoff depth: 3720'• ft. 17.Maximum Anticipated Pressures in psig(see 20 MC 25 035) Maximum Hole Angle: 45' deg Downhole:3600 psig Surface:2992 psig 18.Casing Program. Specifications Top - Setting Depth -Bottom Cement Quantity,c f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 8.75" 7" 26# L-80 BTCM 7092' 32' 32' 712( 5980' 280 sx Class G, 180 sx LiteCRETE 6.125" 4.5" 12.6# L-80 IBTM 613' 6900' 5821' 7513' 6255' 89 sx Class G 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft). Plugs(measured) Effective Depth MD(ft). Effective Depth ND(ft) Junk(measured) 7750 6460 7635 6363 Casing Length Size Cement Volume MD ND Conductor/Structural 80' 16" 215 sx AS 1 115' 115' Surface 3602' 10.75" 1200 sx AS III,600 sx Class G 3637' Intermediate Production 7681' 7" 650 sx Class G,300 sx AS I 7716' Liner Perforation Depth MD(ft): Perforation Depth ND(ft): 7274'-7304',7371'-7383',7391'-7411',7430'-7450' 6059'-6084',6140'-6151',6157-6174',6191'-6208' 20.Attachments. Property Plat El BOP Sketch a Drilling Program El Time v Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Programa 20 AAC 25.050 requirements a 21.Verbal Approval: Commission Representative. Date. , 22. I hereby certify that the foregoing is true and correct. Contact Haibin Guo @ 265-1487 ( Printed Name G. L. Alvord Title Alaska Drilling Manager Signature _ t Phon 2ss sr20 Date 5 f 20 IL•A,cn Commission Use Only Permit to Drill �, tOZ API Number: Permit Approv See cover letter Number 50-/03-2 /--r;t I-t I Date n \`\ for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m thane,gas hydrates,or gas contained in shales g Samples req'd: Yes El No Mud log req'd: Yes ❑ No [i Other: 35o )-251: j3 0 P Te5-/- H2S measures: Yes [✓]/ No ❑ Directional svy req'd: Yes [� No ❑ e ,/rel /vb»g /4 f"lrgl5 tviv5t 1Jrvvi'le .4©'e , :41 /r/SBL -1--r ' 1/I if- d , APPROV D BY THE COMMISSION DATE S-- '- Z P ,COMMISSIONER Form 10-401 (Revised 7/2009) This permit is valid 94 n gl Nla of pproval(20 AA 25.005(g)), Submit in 9icate,u y5//G//Z 1/G f% : i _542_ o-i ConocoPhillips Alaska, Inc. Post Office Box 1 ConocoPhillips Anchorage,Alaskaa 995 99510-0360 Telephone 907-276-1215 April 30,2012 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 • Re: Application for Permit to Drill Rotary Sidetrack CTD Setup 3H-11A Injector Dear Commissioner: ConocoPhillips Alaska, Inc.hereby applies for a Permit to Drill/Sidetrack an onshore injector well from the 3H pad for CTD setup. The expected spud date for this well is June 27,2012 conducting operations with Rig Nordic 3. . P10-, eaD� r The 3H-11 wellbore will be temporarily'abandoned p separate sundry with 20 bbls of cement pumped in the A&C sand • between 7,274'-7,450' and 13 bbls cement placed inside the 3-1/2"tubing and IA from 6,789' to 7,164'MD. The proposed plan is to pull the un-cemented tubing and run CBL to assess the 7"casing TOC. If possible, set a 7"bridge plug at+/-4,930' MD. Cut and pull the 7"at+/-4900' MD.Pump+/-130 bbls 17.0 ppg cement to cover Tabasco sand and form a kick off plug from 3,450' to 4,800'.Otherwise,cut and pull 7"just above TOC.However, it may be necessary to washover the 7"from 3,637'to 3,837' to recover the 7"casing if cement behind the 7"casing is high.Then pump cement and set a kick off plug from 3,450' to 3,837'. • Then we will clean out cement and dress off cement plug to+/-3,720' MD and kick off the cement plug with an 8-3/4" bit.After 20' of new formation is drilled,a leak off test will be performed up to 16.0 ppg EMW.A required minimum leak off is 12.5 ppg EMW. The intermediate hole section will be drilled to+/-7,124' MD/5,980' TVD. 7"26#L-80 • casing will be run and cemented(TOC+/-5800' MD). Second stage cement job will be performed to cover the Tabasco Sand. Production hole section will be drilled with a 6-1/8"bit,and a leak off test will be performed up to 16.0 ppg EMW after 20' of new formation is drilled. The required minimum leak off is 13.5 ppg EMW. The production hole section will be drilled to+/-7,513' MD/6,255' TVD. 4-1/2" 12.6#L80 liner will be run from 6,900' MD to 7,513' MD.A 3-1/2" • tubing upper completion string will be landed in a seal bore receptacle at the liner top packer at 6,900' MD. Nordic 3 will then rig down and move off for CTD to sidetrack in the A-sands. • Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Haibin Guo at 265-1487 or Liz Galiunas at 265-6247. Sincerely, Haibin Guo Drilling Engineer ORIGINAL Application for Permit to Drill Document Kuparuk Well 3H-11A Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 3H-11A. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an Item already on file with the commission and identified in the application• (2)a plat identifying the properly and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth,referenced to governmental section lines (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration: (C)the proposed depth of the well at the top of each objective formation and at total depth: Location at Surface 1,232'FNL, 281'FWL, Sec 12, T12N,RO8E,UM NGS Coordinates RKB Elevation 69'AMSL • Northings: 6,000,425.4' Eastings: 498,655,4' Pad Elevation 39'AMSL • Location at Top of 259' FNL, 1,935' FEL, Sec 12,T12N,RO8E,UM Productive Interval (Kuparuk A2 Sand) NGS Coordinates Measured Depth, RKB: 7,288' Northings: 6,001,397.7' Eastings: 501,718.2' Total Vertical Depth, RKB: 6,096' Total Vertical Depth, SS: 6,027' Location at Total Depth 132' FNL, 1,839'FEL, Sec 12,T12N,RO8E,UM NGS Coordinates Measured Depth, RKB: 7,513' • Northings: 6,001,524.6' Eastings:501,813.9' Total Vertical Depth, RKB: 6,255' • Total Vertical Depth, SS: 6,186' and (D)other information required by 20 AAC 25.050(b), Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must (I)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well: Please see Attachment: Directional Plan No close approach issues exist. Separation factors are above 1.5 once the sidetrack is greater than 100' MD beyond the KOP and continue to increase with depth. The 1/4"mile pool scan of the top of Kuparuk Sand shows the closest approach to be the original 31-1-11 wellbore 1,242'away at 7152' MD. • And (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells, to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail, or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. ! ' L Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items,except for an items already on file with the commission and identified in the application• (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037,as applicable; Please reference BOP schematics on file for Nordic 3. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application. (4)information on drilling hazards, including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The maximum potential surface pressure (MPSP)while drilling 3H-11A is calculated using a maximum reservoir pressure of 3,600 psi, a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A sand at 6,076' TVD (WP10): A Sand SIBHP =3,600 psi • HA S4 �'`i' A Sand estimated depth(WP07) = 6,076' TVD Gas Gradient =0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 608 psi (6,076' TVD * 0.10 psi/ft) MPSP = SIBHP—gas column =2,992 psi • (3,600 psi—608 psi) (B)data on potential gas:ones; The well bore is not expected to penetrate any gas zones. And (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; See attached 3H-11A Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file meth the coninnssion and identified in the application (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.030(/), A procedure is on file with the commission for performing LOT's. For 3H-11A the leak off test for the intermediate hole will occur after kicking off the cement plug and 20' of new formation is drilled. The formation at the KOP depth will be pressured until leak-off occurs or up to 16.0 ppg EMW is reached, which ever comes first. A required minimum leak off of 12.5 ppg EMW must be obtained. After setting the 7" intermediate at 7,124' MD/ 5,980' TVD, 20' of new hole will be drilled, and the formation will be pressure tested until leak-off occurs or to up 16.0 ppg EMW is reached, which ever comes first. A required minimum leak off of 13.5 ppg EMW must be obtained. • ' AL Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the coninussion and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre-perforated liner,or screen to be installed Casing Program Casing Hole weight Top Btm OD Size (lb/ft) Grade Connection Length MD/TVD MD/TVD 16" Conductor 62.5 11-40 Weld 81' Surface= 34' 115' / 115' Original 10-3/4" 13-1/2" 45.5 J-55 BTC 3,604' Surface z 33' 3,637 /3,088' Wellbore 7" 8-1/2" 26 J-55 BTC 7,684' Surface 32' 7,716' /6,432' Sidetrack 7"Casing 8-3/4" 26 L-80 BTCM 7,092' Surface 32' 7,124'/5,980' below 10-3/4" 4-1/2"Liner 6-1/8" 12.6 L-80 IBTM 613' 6,900'/5,821' 7,513'/6,255' Surf Csg. 3-1/2" Tubing 9.3 L-80 EUE 6872' Surface rz 28' 6,900'/5,821' Two Stage Cement Program—Intermediate Hole r The 1st stage cement will be placed from the intermediate TD at 7,124' MD to 5,800' MD . The 2"d stage cement will be placed from 4,900' MD to 3,700' MD. The casing shoe will be at 7,124' MD and will be landed at surface+/- 32'. The slurry consists of 280 sacks of Class G cement plus additives at 15.8 ppg with 50% excess yielding 1.17 ft3/sx for the 1St stage, and 180 sacks of LiteCRETE cement plus additives at 12.5 ppg with 50% excess yielding 1.56 ft3/sx for the 2nd stage. 1st Stage Cement System Preflush: 40 bbls Chemical Wash Spacer: 40 bbls MudPush II Lead Slurry: 280 sacks Class G Cement+additives Yield= 1.17 ft3/sx Slurry Volumes Length Capacity Excess Total(ft3) Total(sacks) (ft) (ft3) Open Hole x Casing OD 1324 199 50% 299 256 8.75"x 7.00" Shoe Track ID 80 17 0% 17 15 6.276" Total 316 271 ✓ 2"d Stage Cement System Preflush: 30 bbls Chemical Wash Spacer: 30 bbls MudPush II Lead Slurry: 180 sacks LiteCRETE Cement+additives Yield= 1.56 ft3/sx Slurry Volumes Length Capacity Excess Total(ft3) Total(sacks) (ft) (ft3) Open Hole x Casing OD 1200 181 50% 271 174 8.75"x 7.00" Total 271 174 1 g a L , z ., , u I L Y Single Stage Cement Program—Production Hole Cement will be placed from TD at 7,513' MD to the top of liner at 6,900' MD (+/- 200'of overlap inside the 7" casing. The slurry consists of 89 sacks of Class G cement plus additives at 15.8 ppg with 30% excess yielding 1.17 ft3/sx. Cement System Preflush: 15 bbls Chemical Wash Spacer: 15 bbls MudPush II Lead Slurry: 89 sacks Class G Cement+additives Yield= 1.17 ft3/sx Slurry Volumes Length Capacity Excess Total(ft3) Total(sacks) (ft) (ft3) Liner Lap 200 22 0% 22 19 6.276"x 4.50" Open Hole x Liner OD 388 37 300/0 44 38 ✓ 6.125"x 4.50" Shoe Track ID 80 7 0% 7 6 3.958" Liner Cap 200 26 0% 26 22 6.276" Total 99 85 Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file frith the commission and identified in the application. (7)a diagram and description of the diverter system as required by 20 MC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); This rotary sidetrack will be drilled out below the existing 10-3/4"casing. BOPE will be installed prior to / pulling the existing tubing completion, and therefore no diverter is required. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an items already on file with the commission and identified in the application (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 MC 25.033; Mud Program Summary Depth MD Mud Wt. Funnel API Fluid PV YP Loss pH Comments o (ft) (ppg) Vis(cp) (cc/30min) $.16" LSND 9.2-9.5 50-60 15-30 7-8 <6 9.5-10 3,637'-7,124' ■ LSND 10.5-12.0. 60-80 25-40 5-6 <6 9.5-10 .IZS 7,124'-7,513' Intermediate and Production Hole Sidetrack Fluid: A 9.2—9.5 ppg LSND drilling fluid will be used to drill the intermediate hole to 7,124' MD/5,980' TVD. 10.5 — 12.0 ppg LSND drilling fluid will be used to drill the production hole to 7,513' MD/6,255' / TVD. The drilling mud weight is calculated using an A Sand EMW of 10.0 ppg plus 0.5 ppg trip margin ✓ to result in an 10.5 ppg. Fluid weight will have sufficient density to overbalance the pressure of uncased formations penetrated. Additional focus will be on minimizing the potential of a hydrostatic pressure surge or swab and good hole cleaning practices. These practices include monitoring tripping speeds and PWD data, controlling ROP, pumping regular sweeps, adjusting rheology, and charting drag weights. OJGLNAL Diagram of Nordic 3 Mud System on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A -Application is not for an exploratory or stratigraphic test well. • Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A-Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. • Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application 3H-11 P&A Pre Rig Work(previous sundry): a. Replace GLVs #1 and#2 with dummy valves. Perform MIT-T. b. With open sleeve @7,180' and GLM#5,RIH on coil tubing and set retainer at+/-7,164' RKB. c. Pump 20 bbls of 15.8 ppg cement into A and C sand perforation.Fill the tubing above the retainer and annulus with 13 bbls cement to 6,789' RKB. d. Freeze protect from 2,000'to surface and test the cement plug. /4 e. Pull DV from GLM#4 at 6,678' RKB. P3�Z�1 f. Swap hole with 11.0 ppg corrosion inhabit brine and perform freeze protect. ` g. Reinstall DV in GLM#4 at 6,678'RKB. h. E-line cut tubing at+/-5,197' RKB. jA'vu - Tubing is freeze protected with diesel. - Set BPV. 1. Move Nordic 3 on 3H-11 and rig up. 2. Pull BPV and VR plugs. Record tubing,IA,and OA pressures. Circulate out freeze protect through tubing cut and monitor well for pressure. 3. Set BPV and test to 1,500 psi from below.Nipple down tree. M/U blanking plug in tubing hanger and nipple up BOPE. • • Notify AOGCC field inspector 24 hours prior to BOPE test. .�— • Test BOP to 250 psi low/3,5` l psi high as per drilling permit. • BOP test cycle is one week until kick off fromfement plug. • Upper Pipe Ram will be 2-7/8"x 5"VBR. V • The Lower Pipe Ram will be 4", 5"or 7"per the string OD in hole. • A FOSV is to be kept on the floor at all times with pertinent X-over for DP or casing thread in rotary table. 4. Pull blanking plug and BPV. Pull tubing hanger and lay down 3-1/2"completion. U 6\ t l Vt. i t L- 5. Run 7"casing scraper to+/-5,000' MD. 6. Run CBL in 7"casing to+/-5,000' MD. ✓ 7. Set 7"bridge plug at+/-4,930' MD. 8. Cut 7"casing at+/-4,900' and pull 7"packoff. -OA 9. Lay down 7"casing. --P1/ 10. RIH to top of cut at+/-4,900'with DP and pump a hi-vis pill and+/-130 bbls of Class G cement plus additives at 17.0 ppg for kick off plug. 11. POOH and WOC minimum of 12 hrs roc 12. While WOC prepare directional tools and PU bit,motor and MWD tools and perform housekeeping. It. 13. Run in hole kick off BHA to top of cement plug and dress it off to+/-3,720'MD. 14. Orient MWD and motor and begin to drill off of cement kick off plug. • Note: Start 2 weeks BOP test cycle. 15. Drill 20' into new formation.Perform LOT with rig pump as per CPAI procedure up to 16 ppg EMW. Minimum acceptable leak off is 12.5 ppg EMW. 16. Drill 8-3/4"hole from 3,720' MD to 7,124' MD/5,980' TVD(above Kuparuk D Sand). • 17. At total depth,circulate hole clean and perform wiper trip to KOP. Once back on bottom,circulate until hole is clean. Pull out of hole I..- ok b e cK ill �e and lay down BHA. fc-r -16 18. Run 7",26 ppf,``-'Lff-80 casing to TD and land on mandrel in wellhead. • f 5t 54g. ` i 19. Cement casing to+/-5,800'MD with 15.8 ppg Class G slurry and 50%excess. 20. Second stage cement job will be performed to cover Tabasco sand from 4,900'to 3,700' MD. " S.l.a.�'' 21. Drill out shoe track and 20' of new formation. Displace hole to 10.5 ppg MW. Perform open hole leak off up to 16.0 ppg • EMW. Minimum acceptable leak off is 13.5 ppe EMW. 22. Drill 6-1/8"hole from 7,124' MD to 7,513' (TD). • 23. At total depth,circulate hole clean and perform wiper trip to 7"shoe. Once back on bottom,circulate until hole is clean. Pull out of hole and rack back drill pipe and lay down BHA. 24. Pick up and run 4-1/2" 12.6#L-80 liner. The top of liner will be placed at+/-6,900'MD allowing for 200' of overlap. 25. Cement liner to top with 15.8 ppg Class G slurry and 30%excess. Set liner hanger. Slackoff and set liner top packer.- Circulate acker.Circulate out excess cement above liner. 26. Monitor well then pull out of hole laying down drill pipe. 27. R/U Wireline to run CBL for 4-1/2"liner cement job. 28. Run 3-1/2"upper completion as per procedure with SSSV and 5 GLMs. ir UA}r ',414,_e h r f-.3O rri i v� M 29. RD and MO Nordic 3. Coil tubing drilling rig will return at a future date to dr l.I! A Sand for flood injection. • L � A O Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items,except for an item already on file with the commission and identified in the application. (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorr_ation under 20 AAC 25.080 for an annular disposal operation in the well; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement summary Attachment 4 Well Schematic Attachment 5 Wellhead 3H-11A Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) 8-3/4" Hole with 7" Casing Interval* REvent lvel Mitigation Strategy LeDifficult to wash over 7" Low Set whipstock in 10-3/4" surface casing and sidetrack casing down Open Hole leak off less Moderate Squeeze cement below 10-3/4"casing at window than required Hole instability while Moderate Utilize a mud weight to stabilize formations without drilling shale section sustaining losses Directional control Moderate Placement of KOP and bottom hole location to allow for 4° DLS. Ream 8-3/4"hole with hole opener and proper mud weight Run casing to bottom Moderate for hole stability, directional plan with 4° DLS and a tangent from HRZ to TD, and run 7"casing. Reduced trip speeds, real time equivalent circulating Hole swabbing/surging Moderate density(ECD)monitoring, mud rheology, and proper hole filling. Pump and rotate out of hole as necessary. Abnormal Reservoir BOPE drills, keep mud weight above 2+2_prpg, check for Pressure Low ' flow during connections and if needed increase mud weight. Reduced pump rates,real time equivalent circulating Lost Circulation Low density (ECD)monitoring, mud rheology, and LCM. Use GKA LC decision tree as needed. The 2nd stage cementing job will able to set cement across Two Stages Cement Moderate Tabasco and ensure cleanness of surface casing. 2 TAM port collars will be run. Have PJSM to review the cement procedure thoroughly with all parties involved. Cement Bonding Moderate Run liner with centralization for standoff. Reciprocate during circulation and pump 50%excess cement. H2S drills, detection systems, alarms, and standard well Hydrogen Sulfide Gas Low control practices. *See Well Plan for more detailed risk information and offset data. ORIGINAL 6-1/8" Hole with 4-1/2" Liner Interval* Ri Event Vel Mitigation Strategy LeLeak off test less than Low Squeeze 7"casing shoe. required Hole instability while Moderate Utilize a mud weight to stabilize formations without drilling shale section sustaining losses Directional control Low Tangent part of well. Run liner to bottom Moderate Drill 6-1/8"hole with proper mud weight for hole stability, directional plan, and run 3-1/2" liner. Reduced trip speeds, real time equivalent circulating Hole swabbing/surging Moderate • density(ECD)monitoring, mud rheology, and proper hole filling. Pump and rotate out of hole as necessary. BOPE drills,keep mud weight above 10.5 ppg, check for • Abnormal Reservoir Moderate • flow during connections and if needed increase mud Pressure weight. Reduced pump rates,real time equivalent circulating Lost Circulation Low • density (ECD)monitoring, mud rheology, and LCM. Use GKA LC decision tree as needed. Cement Bonding Moderate Run liner with centralization for standoff. Reciprocate during circulation and pump 30%excess cement. 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H H 1 c 1 r N rM ew\_ I ♦ 1 CO O 1 U —N el M ti~ I h 1 z°z E ' I0') ^� 1 P, ono 1 c Z r0 gl Oo 1 cp p F@J@Jz 0 10 - o �v co mmmE K \ o —. + 0 =coE 14 ,' ^� - Z 3aa O / OW z 1226> a W ` �i C C. .0 - U 0 m `� N F U r. - fh Q. �J > in O o)) - 38p�f . 00 _ h o ZIP Z' X70 —O p^ �7:, o �S,1M O0 - m Q IP d,o_ ah tx r=i ie• O - Y 81 ry ) 2 2.M Q p�, ySp t. �e/ sI °oO a o L t .Q ONYY= @= "as, � � rdri S' ' Ofi, ,_1M • ji) 40 ., > o- Oe F6F a - d �$ ass Bat: e9e'1(4).. —o Q`�,L•S . c5i0 N bit'rill o06_ pe.`£Dd, OSZ£, - O O� r. M —O M3 000£ 1 `" - W 0 I I I I I I I I I I I I I I 1 I I I I I I I I I I I I I I o, kr, o r o o O o c Q oi o r r N i� vi I (U)/13 00£)(+)4u0N/(-)41nos ORI GIL Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 3H-11 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:3H-11A @ 68.70ft(Nordic 3(38.7+30)) . Project: Kuparuk River Unit MD Reference: Plan:3H-11A @ 68.70ft(Nordic 3(38.7+30)) Site: Kuparuk 3H Pad North Reference: True Well: 3H-11 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3H-11A Design: 3I-1-11A(wp10) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Veil Section (ft) (°) C) (ft) ft (ft) (ft) (ft) (ft) -38.70 30.00 0.00 0.00 30.00 -38.70 0.00 0.00 6,000,425.37 498,655.44 0.00 0.00 92.70 0.13 118.43 92.70 24.00 -0.03 0.06 6,000,425.34 498,655.50 0.21 0.06 192.70 0.20 120.83 192.70 124.00 -0.18 0.31 6,000,425.19 498,655.75 0.07 0.29 292.70 0.25 129.72 292.70 224.00 -0.41 0.63 6,000,424.96 498,656.07 0.06 0.58 392.70 0.92 114.42 392.69 323.99 -0.88 1.53 6,000,424.49 498,656.97 0.68 1.41 492.70 4.47 96.45 492.57 423.87 -1.65 6.13 6,000,423.72 498,661.57 3.61 5.89 592.70 8.52 94.78 591.91 523.21 -2.70 17.39 6,000,422.66 498,672.83 4.05 16.93 692.70 13.45 92.37 690.04 621.34 -3.80 36.41 6,000,421.56 498,691.84 4.95 35.67 792.70 16.08 92.53 786.73 718.03 -4.89 61.87 6,000,420.47 498,717.30 2.63 60.81 892.70 17.72 93.21 882.41 813.71 -6.36 90.90 6,000,419.00 498,746.33 1.65 89.45 992.70 18.95 93.71 977.33 908.63 -8.26 122.30 6,000,417.09 498,777.72 1.24 120.38 1,092.70 20.95 94.33 1,071.33 1,002.63 -10.66 156.33 6,000,414.68 498,811.75 2.01 153.87 1,192.70 22.55 94.57 1,164.20 1,095.50 -13.54 193.27 6,000,411.80 498,848.69 1.60 190.18 1,292.70 24.17 94.75 1,256.00 1,187.30 -16.76 232.79 6,000,408.57 498,888.20 1.62 229.01 1,392.70 25.22 94.21 1,346.86 1,278.16 -20.02 274.44 6,000,405.30 498,929.85 1.07 269.96 1,492.70 26.88 94.11 1,436.70 1,368.00 -23.21 318.24 6,000,402.11 498,973.64 1.66 313.04 1,592.70 30.95 95.34 1,524.21 1,455.51 -27.22 366.41 6,000,398.09 499,021.81 4.11 360.36 1,692.70 34.25 95.22 1,608.45 1,539.75 -32.18 420.05 6,000,393.12 499,075.44 3.30 413.00 1,792.70 36.03 95.02 1,690.22 1,621.52 -37.31 477.38 6,000,387.98 499,132.76 1.78 469.27 1,892.70 36.90 96.01 1,770.64 1,701.94 -43.03 536.53 6,000,382.25 499,191.91 1.05 527.29 1,992.70 37.65 96.10 1,850.21 1,781.51 -49.42 596.76 6,000,375.85 499,252.13 0.75 586.29 2,092.70 38.20 96.37 1,929.09 1,860.39 -56.09 657.86 6,000,369.17 499,313.22 0.57 646.12 2,192.70 38.20 96.68 2,007.68 1,938.98 -63.12 719.30 6,000,362.13 499,374.65 0.19 706.24 2,292.70 38.17 97.56 2,086.28 2,017.58 -70.78 780.64 6,000,354.46 499,435.99 0.54 766.20 2,392.70 38.83 98.28 2,164.54 2,095.84 -79.36 842.30 6,000,345.86 499,497.64 0.80 826.35 2,492.70 39.40 98.72 2,242.13 2,173.43 -88.69 904.69 6,000,336.53 499,560.02 0.63 887.14 2,592.70 40.45 99.26 2,318.82 2,250.12 -98.72 968.08 6,000,326.49 499,623.40 1.11 948.83 2,692.70 41.40 99.64 2,394.37 2,325.67 -109.48 1,032.70 6,000,315.72 499,688.01 0.98 1,011.66 2,792.70 41.92 100.03 2,469.08 2,400.38 -120.83 1,098.19 6,000,304.35 499,753.50 0.58 1,075.28 2,892.70 42.23 100.31 2,543.31 2,474.61 -132.66 1,164.15 6,000,292.51 499,819.45 0.36 1,139.30 2,992.70 42.75 100.80 2,617.05 2,548.35 -145.04 1,230.55 6,000,280.12 499,885.84 0.62 1,203.70 3,092.70 43.07 101.36 2,690.29 2,621.59 -158.12 1,297.36 6,000,267.03 499,952.64 0.50 1,268.42 3,192.70 43.15 101.56 2,763.30 2,694.60 -171.70 1,364.34 6,000,253.44 500,019.61 0.16 1,333.25 3,292.70 43.48 101.74 2,836.06 2,767.36 -185.56 1,431.53 6,000,239.58 500,086.79 0.35 1,398.24 3,392.70 43.62 101.91 2,908.53 2,839.83 -199.67 1,498.96 6,000,225.45 500,154.22 0.18 1,463.46 3,492.70 43.65 102.49 2,980.91 2,912.21 -214.26 1,566.41 6,000,210.85 500,221.66 0.40 1,528.62 3,592.70 43.67 103.35 3,053.26 2,984.56 -229.69 1,633.70 6,000,195.41 500,288.94 0.59 1,593.53 3,629.70 43.94 103.41 3,079.96 3,011.26 -235.62 1,658.62 6,000,189.48 500,313.85 0.74 1,617.54 10-3/4"x 13-1/2" 3,692.70 44.40 103.50 3,125.15 3,056.45 -245.83 1,701.31 6,000,179.26 500,356.54 0.74 1,658.67 3,720.00 44.30 103.52 3,144.67 3,075.97 -250.29 1,719.86 6,000,174.80 500,375.09 0.38 1,676.54 i KOP @ 3720'MD,3145'TVD:1482'FNL,2001'FWL-Sec12-T12N-RO8E 3,800.00 41.84 100.52 3,203.12 3,134.42 -261.69 1,773.27 6,000,163.38 500,428.49 4.00 1,728.16 3,900.00 38.88 96.35 3,279.32 3,210.62 -271.26 1,837.28 6,000,153.81 500,492.49 4.00 1,790.53 4/3/2012 2:59:26PM Page 3 COMPASS 2003.16 Build 69 ORG1NAL Halliburton -Sperry I-IALLIBURT0N Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 3H-11 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:3H-11A @ 68.70ft(Nordic 3(38.7+30)) Project: Kuparuk River Unit MD Reference: Plan:3H-11A @ 68.70ft(Nordic 3(38.7+30)) Site: Kuparuk 3H Pad North Reference: True Well: 3H-11 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3H-11A Design: 3H-11A(wp10) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +El-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 3,238.00 3,934.93 37.89 94.77 3,306.70 3,238.00 -273.36 1,858.86 6,000,151.70 500,514.07 4.00 1,811.69 Top Tabasco @ 3935'MD,3307'TVD:1505'FNL,2140'FWL-Sec12-T12N-R08E-Tabasco 4,000.00 36.10 91.63 3,358.68 3,289.98 -275.57 1,897.94 6,000,149.49 500,553.14 4.00 1,850.21 4,100.00 33.52 86.26 3,440.80 3,372.10 -274.61 1,954.96 6,000,150.44 500,610.16 4.00 1,906.93 4,200.00 31.21 80.16 3,525.28 3,456.58 -268.38 2,008.07 6,000,156.66 500,663.26 4.00 1,960.39 4,300.00 29.23 73.25 3,611.71 3,543.01 -256.91 2,056.99 6,000,168.12 500,712.18 4.00 2,010.35 4,400.00 27.64 65.53 3,699.68 3,630.98 -240.26 2,101.50 6,000,184.76 500,756.69 4.00 2,056.56 4,500.00 26.53 57.09 3,788.74 3,720.04 -218.51 2,141.38 6,000,206.50 500,796.57 4.00 2,098.79 4,600.00 25.94 48.13 3,878.47 3,809.77 -191.76 2,176.43 6,000,233.24 500,831.62 4.00 2,136.84 4,700.00 25.93 38.97 3,968.44 3,899.74 -160.15 2,206.48 6,000,264.84 500,861.67 4.00 2,170.52 4,719.90 26.00 37.16 3,986.33 3,917.63 -153.29 2,211.85 6,000,271.70 500,867.04 4.00 2,176.68 4,800.00 26.00 37.16 4,058.33 3,989.63 -125.31 2,233.06 6,000,299.67 500,888.25 0.00 2,201.14 4,900.00 26.00 37.16 4,148.21 4,079.51 -90.38 2,259.53 6,000,334.59 500,914.73 0.00 2,231.68 5,000.00 26.00 37.16 4,238.09 4,169.39 -55.45 2,286.01 6,000,369.51 500,941.21 0.00 2,262.21 5,100.00 26.00 37.16 4,327.98 4,259.28 -20.52 2,312.48 6,000,404.43 500,967.69 0.00 2,292.75 5,200.00 26.00 37.16 4,417.86 4,349.16 14.41 2,338.96 6,000,439.36 500,994.17 0.00 2,323.28 5,300.00 26.00 37.16 4,507.74 4,439.04 49.34 2,365.44 6,000,474.28 501,020.65 0.00 2,353.82 5,332.22 26.00 37.16 4,536.70 4,468.00 60.59 2,373.97 6,000,485.53 501,029.18 0.00 2,363.65 C35 5,400.00 26.00 37.16 4,597.62 4,528.92 84.27 2,391.91 6,000,509.20 501,047.13 0.00 2,384.35 5,500.00 26.00 37.16 4,687.51 4,618.81 119.20 2,418.39 6,000,544.12 501,073.61 0.00 2,414.89 5,600.00 26.00 37.16 4,777.39 4,708.69 154.13 2,444.86 6,000,579.04 501,100.09 0.00 2,445.42 5,700.00 26.00 37.16 4,867.27 4,798.57 189.06 2,471.34 6,000,613.96 501,126.57 0.00 2,475.96 5,800.00 26.00 37.16 4,957.16 4,888.46 223.99 2,497.81 6,000,648.89 501,153.04 0.00 2,506.49 5,900.00 26.00 37.16 5,047.04 4,978.34 258.92 2,524.29 6,000,683.81 501,179.52 0.00 2,537.03 5,995.25 26.00 37.16 5,132.66 5,063.96 292.19 2,549.51 6,000,717.07 501,204.75 0.00 2,566.11 6,000.00 26.19 37.16 5,136.92 5,068.22 293.85 2,550.77 6,000,718.73 501,206.01 4.00 2,567.57 6,100.00 30.19 37.11 5,225.04 5,156.34 331.50 2,579.28 6,000,756.37 501,234.52 4.00 2,600.45 6,200.00 34.19 37.07 5,309.66 5,240.96 373.98 2,611.39 6,000,798.84 501,266.64 4.00 2,637.50 6,300.00 38.19 37.04 5,390.35 5,321.65 421.09 2,646.96 6,000,845.94 501,302.21 4.00 2,678.55 6,400.00 42.19 37.02 5,466.74 5,398.04 472.59 2,685.81 6,000,897.43 501,341.07 4.00 2,723.39 6,470.37 45.00 37.00 5,517.70 5,449.00 511.34 2,715.02 6,000,936.17 501,370.28 4.00 2,757.10 6,495.83 45.00 37.00 5,535.70 5,467.00 525.71 2,725.85 6,000,950.54 501,381.11 0.00 2,769.60 C30 6,500.00 45.00 37.00 5,538.65 5,469.95 528.07 2,727.62 6,000,952.89 501,382.89 0.00 2,771.65 6,600.00 45.00 37.00 5,609.36 5,540.66 584.54 2,770.18 6,001,009.35 501,425.45 0.00 2,820.77 6,640.08 45.00 37.00 5,637.70 5,569.00 607.17 2,787.23 6,001,031.98 501,442.51 0.00 2,840.46 Top HRZ 6,700.00 45.00 37.00 5,680.07 5,611.37 641.01 2,812.73 6,001,065.81 501,468.01 0.00 2,869.89 6,800.00 45.00 37.00 5,750.78 5,682.08 697.48 2,855.29 6,001,122.27 501,510.57 0.00 2,919.01 6,873.43 45.00 37.00 5,802.70 5,734.00 738.95 2,886.53 6,001,163.73 501,541.82 0.00 2,955.07 Base HRZ 6,900.00 45.00 37.00 5,821.49 5,752.79 753.96 2,897.84 6,001,178.73 501,553.13 0.00 2,968.13 7,000.00 45.00 37.00 5,892.20 5,823.50 810.43 2,940.40 6,001,235.19 501,595.69 0.00 3,017.25 4/3/2012 2:59,26PM Page 4 COMPASS 2003.16 Build 69 ORIGINAL Halliburton -Sperry HALLI B U RTO N Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 3H-11 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:3H-11A @ 68.70ft(Nordic 3(38.7+30)) Project: Kuparuk River Unit MD Reference: Plan:3H-11A @ 68.70ft(Nordic 3(38.7+30)) Site: Kuparuk 3H Pad North Reference: True Well: 3H-11 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3H-11A Design: 3H-11A(wp10) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +6/-W Northing Easting DLS Vert Section (ft) (°) (") (ft) ft (ft) (ft) (ft) (ft) 5,844.00 7,028.99 45.00 37.00 5,912.70 5,844.00 826.80 2,952.73 6,001,251.55 501,608.03 0.00 3,031.49 K-1 7,100.00 45.00 37.00 5,962.91 5,894.21 866.90 2,982.95 6,001,291.65 501,638.25 0.00 3,066.37 7,123.74 45.00 37.00 5,979.70 5,911.00 880.31 2,993.06 6,001,305.05 501,648.36 0.00 3,078.03 7"Casing @ 7124'MD,5980'TVD:352'FNL,2005'FEL-Sec12-T12N-RO8E-7"x 8 3/4" 7,136.47 45.00 37.00 5,988.70 5,920.00 887.49 2,998.47 6,001,312.24 501,653.77 0.00 3,084.28 Top KupD @ 7136'MD,5989'TVD:345'FNL,2000'FEL-Sec12-T12N-R08E-Kup D 7,152.03 45.00 37.00 5,999.70 5,931.00 896.28 3,005.09 6,001,321.02 501,660.39 0.00 3,091.92 Kup C4 7,183.14 45.00 37.00 6,021.70 5,953.00 913.85 3,018.33 6,001,338.59 501,673.63 0.00 3,107.20 Kup C1 7,185.97 45.00 37.00 6,023.70 5,955.00 915.45 3,019.54 6,001,340.18 501,674.84 0.00 3,108.59 B 7,200.00 45.00 37.00 6,033.62 5,964.92 923.37 3,025.51 6,001,348.11 501,680.81 0.00 3,115.49 7,243.95 45.00 37.00 6,064.70 5,996.00 948.19 3,044.21 6,001,372.92 501,699.52 0.00 3,137.07 A5 7,259.51 45.00 37.00 6,075.70 6,007.00 956.98 3,050.83 6,001,381.70 501,706.14 0.00 3,144.72 A3 7,287.79 45.00 37.00 6,095.70 6,027.00 972.95 3,062.87 6,001,397.67 501,718.18 0.00 3,158.61 Top KupA2 @ 7288'MD,6096'TVD:259'FNL,1935'FEL-Sec12-T12N-R08E-A2-3H-11A(wp09)T1 7,300.00 45.00 37.00 6,104.33 6,035.63 979.84 3,068.06 6,001,404.56 501,723.37 0.00 3,164.61 7,333.04 45.00 37.00 6,127.70 6,059.00 998.51 3,082.12 6,001,423.22 501,737.44 0.00 3,180.84 Al 7,399.51 45.00 37.00 6,174.70 6,106.00 1,036.04 3,110.41 6,001,460.75 501,765.73 0.00 3,213.49 Base Kup 7,403.76 45.00 37.00 6,177.70 6,109.00 1,038.44 3,112.22 6,001,463.14 501,767.53 0.00 3,215.57 7,500.00 45.00 37.00 6,245.76 6,177.06 1,092.79 3,153.17 6,001,517.48 501,808.49 0.00 3,262.85 ' 7,512.65 45.00 37.00 6,254.70 • 6,186.00 1,099.93 • 3,158.55 • 6,001,524.62 501,813.88 0.00 3,269.06 TD @ 7513'MD,6255'TVD:132'FNL,1839'FEL-Sec12-T12N-R08E-4 1/2"x 6 1/8" • Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +El-W Northing Easting -Shape (°) (") (ft) (ft) (ft) (ft) (ft) 3H-11A(rvp09j MI 0.00 0.00 6,095.70 972.95 3,062.87 6,001,397.67 501,718.18 -plan hits target center -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 7,512.65 6,254.70 4 1/2"x 6 1/8" 4-1/2 6-1/8 7,123.74 5,979.70 7"x 8 3/4" 7 8-3/4 3,629.70 3,079.96 10 3/4"x 13 1/2" 10-3/4 13-1/2 4/3/2012 2:59:26PM Page 5 COMPASS 2003.16 Build 69 ORG1NAL Halliburton -Sperry HALLI B U RTO N Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 3H-11 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:3H-11A @ 68.70ft(Nordic 3(38.7+30)) Project: Kuparuk River Unit MD Reference: Plan:3H-11A @ 68.70ft(Nordic 3(38.7+30)) Site: Kuparuk 3H Pad North Reference: True Well: 3H-11 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3H-11A Design: 3H-11A(wp10) Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (°) (°) 6,873.43 5,802.70 Base HRZ 0.00 7,399.51 6,174.70 Base Kup 0.00 7,287.79 6,095.70 A2 0.00 7,183.14 6,021.70 Kup Cl 0.00 7,136.47 5,988.70 Kup D 0.00 6,495.83 5,535.70 C30 0.00 6,640.08 5,637.70 Top HRZ 0.00 7,185.97 6,023.70 B 0.00 7,152.03 5,999.70 Kup C4 0.00 7,333.04 6,127.70 Al 0.00 5,332.22 4,536.70 C35 0.00 7,259.51 6,075.70 A3 0.00 3,934.93 3,306.70 Tabasco 0.00 7,028.99 5,912.70 K-1 0.00 7,243.95 6,064.70 A5 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 3,720.00 3,144.67 -250.29 1,719.86 KOP @ 3720'MD,3145'TVD:1482'FNL,2001'FWL-Sec12-T12N-R08E 3,934.93 3,306.70 -273.36 1,858.86 Top Tabasco @ 3935'MD,3307'TVD:1505'FNL,2140'FWL-Sec12-T12N-R08E 7,123.74 5,979.70 880.31 2,993.06 7"Casing @ 7124'MD,5980'TVD:352'FNL,2005'FEL-Sec12-T12N-R08E 7,136.47 5,988.70 887.50 2,998.47 Top KupD @ 7136'MD,5989'TVD:345'FNL,2000'FEL-Sec12-T12N-R08E 7,287.79 6,095.70 972.95 3,062.87 Top KupA2 @ 7288'MD,6096'TVD:259'FNL,1935'FEL-Sec12-T12N-R08E 7,512.65 6,254.70 1,099.93 3,158.55 TD @ 7513'MD,6255'TVD:132'FNL,1839'FEL-Sec12-T12N-R08E 4/3/2012 2:59:26PM Page 6 COMPASS 2003.16 Build 69 zn 0 m • w • L a Q ` t ai I Q Q. - Ts r�� cu Y !Nle E II NM I N V C C to 0 m0. `o -2)':7; 653 N • aa o I 3 t Qr alo z = N m ii M - M -CU r Li% t01• a/� N M C Q • `v OO T + L iiO = °o nz M r Nf0 W M p r 3c d n cr v 3 n :a E u QU 4 tO Z m ut M 00 d RMIME to dZ ��`ppo� n A <0. �. M t0 V N d 'p FUJ - i1 ,- Q 10 LL O 2 1O. c 2 y = Q a Q Q r ,� a ° a `' o n ' m c 0 IV.-- = N s Y m o ry o vO II. Cl I 3 O O O N 1 0, lL t0 O N M Q a = a m �� .S ❑ •O C D U N a S. r Q. T C O 2 ea !v . C T T 0 Y Y UC �V = ' ' aC 'O ' <73 C C NM a M O F Q: N ) C7 > fA fn 0 hi 1 b'-' i 1\ /1L Halliburton -Sperry I-IALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 31-1-11 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:3H-11A @ 68.70ft(Nordic 3(38.7+30)) Project: Kuparuk River Unit MD Reference: Plan:3H-11A @ 68.70ft(Nordic 3(38.7+30)) Site: Kuparuk 3H Pad North Reference: True Well: 3H-11 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3H-11A Design: 3H-11A(wp10) Project Kuparuk River Unit,North Slope Alaska,United States 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 3H Pad Site Position: Northing: 6,000,110.73ft Latitude: 70°24'41.531 N From: Map Easting: 498,655.44ft Longitude: 150°0'39.416 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: -0.01 ° Well 3H-11 Well Position +N/-S 0.00 ft Northing: 6,000,425.37 ft . Latitude: 70°24'44.626 N +E/-W 0.00 ft Easting: 498,655.44 ft • Longitude: 150°0'39.418 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 38.70 ft . Wellbore Plan:3H-11A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BG G M2011 6/24/2012 20.39 80.97 57,631 Design 3H-11A(wp10) Audit Notes: Version: Phase: PLAN Tie On Depth: 3,720.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 30.00 0.00 0.00 83.00 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (0) (0) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (0) 3,720.00 44.30 103.52 3,144.67 3,075.97 -250.29 1,719.86 0.00 0.00 0.00 0.00 4,719.90 26.00 37.16 3,986.33 3,917.63 -153.29 2,211.85 4.00 -1.83 -6.64 -141.34 5,995.25 26.00 37.16 5,132.66 5,063.96 292.19 2,549.51 0.00 0.00 0.00 0.00 6,470.37 45.00 37.00 5,517.70 5,449.00 511.34 2,715.02 4.00 4.00 -0.03 -0.35 7,287.79 45.00 37.00 6,095.70 6,027.00 972.95 3,062.87 0.00 0.00 0.00 0.00 7,403.76 45.00 37.00 6,177.70 6,109.00 1,038.44 3,112.22 0.00 0.00 0.00 0.00 7,512.65 45.00 37.00 6,254.70 6,186.00 1,099.93 3,158.55 0.00 0.00 0.00 0.00 4/3/2012 2:59:26PM PORIG1Nige 2 COMPASS 2003.16 Build 69 , L -0 p e 'T' 0111011 cog t00eaN O '_11111141* �% 7 C c oo,m o M 64 Z -M ll C3 VOW',,,,'rowlimiliwimilliNitt, ` `\ NNro'NgN_NOppi •p NQ ,, ' ���' C NNN !'IN N L 2i5-' ,• L 0 2LL`0' IR ��II` I. iR ' N it U o o4ogoo U c°yc WI 111% ` X � .2,ov_ pi lila T8888888 O d EC- U gee CI PRSISE8A,7 y o_ wg0Nrnrm - eisszsz ce % Ito ^,,,,,• , ,,,,,,f' 6 as cO�iN�ggf Nof ONi Il 1111( N1 CNNojVNNZ Zm,`� .) j Ng U R 3gN�g�mg ^ ` ' w o[ Wrn�oiv�'n la3 As c Z nNUM TO �N NN n.'1h a F U NeiNryryxr e tod F' y 26rl N pNoicO L �NpNm'G N E Y iidi o O o 0 0 0 0 0 En c U i83 C O O o 0 0 0 0 — a�Y��o^� co O �n O �n O O z Pirgr �o EQ t.Am co v v Ln Ln co co N. r� T oig b ENU U N NN�Ob10 ad '7-8088 Q � W2 o �Mn fnH 0. 4;E"p 4;-CiU _$888°8 Ld o.LAL 0 0 0 0 0 0 0 0 0 rvry Yvi8 � a a'>,d7m E c'J Ln o 0 0 0 0 0 o o 2U N2 N2 OP^7 2 V V OC CC0 2go^3n o c Oo rvnm �ooo oionnV .ivWNuw-E_ C �'-NtYnnr > _ N N 4 Uo C M C N N C ce GC ',' '\mit\`�, C 15, \meq i f4 CA i ' ' "Y``\ ,` 03 .c� b O O '410. 2 11tat, <l� X111 = 111go N a 0Z Fps Q W �N • c 0 „ ��l "jiltE "ZNs ao NsQQ; `� ` `i n v b ,4,I1 _ We 1 �' C . 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((��` `- Q= M M M S 2± co 2 M m M M = = _ = = = N N S' N a b M N M Q co M Q Q co- m m m m M M Q _, CO Cn M M M ''2) N Ch c• V 4 yr V V V ( CO CO r o0 co O co- In N N N ti 0 ± 2 2 2 2 2 2 2 2 2 2 = 2 2 2 2 2 2 2 2 5 2 2 2 = 2 2 2 2 C h co co co co co co co co co co co co co co co co co co co co co co co co co co co n V O N C•1 CV N N CV C7 Ch ar V .4 .4 V V V V Ifl co- co- I� cc Cn O M M xi N N N :V 2 ± 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 ?') CO M M M M co co co co co co co co co M M co co co co co co co co co co co :7 4El) CI) + + + 4 + * it] * 444 + 1 'N I c i I I I I I I I I I 1 1 I - I I I I I Q I I Q I LO I I I I I I I I I I I I 1 I I - -- - I I o I I v = Q Oi CO O 19 — I I I Q a > . 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N = w Nl CO a M D_ CO a CO C' M Ey F I- F_ F F oOC) �+ � d 6 N , CT5, vi �. 6aa ,v a c a e a v o C) u C) 'O C) t G) t C) ZS O c 0 c 0 c V c u c C rn C N C co C ` o y CO y o CO o 0) 0 co f S xC) d C7 Oj o dt C) A m rA 0mL C•y a r y a w o n d m d r� a n m Q2o CC2a Ix 20 IXso tela E V M o C' i N U) O 9 C NO aN 0 N1- M JQ 6 r a0 tl ' rn 0 n o - 0 0 CO CC - 10 •o 40 CO 0 O- 0 O O ' 12.0 ' coa a N a . a aa a ac , " a a a a Q=a a a co O Y o N d YY o 0 Yu d :ZE uoi 414Yo C O � � N � � 9 N O " O " a. Or':9wo ORG1NAL §) f §) f ```i^ ! 4,2 k/\/)( )\}/&7 co E )\\/\LU E D—LD , « \_ R ) \ }/ f\ Cov N » \\ / \\ \ / �/ \ 0/ ) o o m co )/ U CO / / co TI o cc; co { H / H I• ` ° o \ { cai ° . \ CO • \ ; /k ■t kBa co ' o !! O o O §) § 2§ O _ _ ! 008 8 ({k�� [ !!5f(= 0 •3;9f)- 2 0 a-HH 0 ){\/(\ ocn (/) R R o !c , !— co U ! $ )\ . ; \ \ \\ \ vi \ t i co ' 2 0 2 k= ( /k: 8 « ®( , <-/ \ k < k < H H k { o k \ vi S / a $ ., C , . } U_ § kQF= F. � fƒ ` �/\ .- 0 / ƒ � , 0 ) CO { a 0. � 4 \ §# ii ai ■9 � co , ;! 2 i §a ` §2e ` §2k (JRIGtNAL _ 0 COlN O -_ t0 - O O Las N m = CU M • I a - o E£HE _ E t�. ca> d� ro `7 = O , - '% I 2 ` _\n 4 I M \ ^ \ - v yC/1 M r \ \ _ N = O '7 109 a ^ 3N- o ul \ a N i., v 3H-Al e _ v co - \ Q o tV/\ O M O 2 - v M ckc u o 1► X /' e I O :---- omN 4 , o o�n ^ w°0 /eR N --O^ ' O - \ J - O`, - N i� y �a to e _ I I N - N N \:\.\ M �' - co I a 1 r _o 0 A O N .3., d = a N N r=i __ oU �- / 3H-10 -Lo Y Y '- N ni O Z M ` �: x f = O aa. v ' -0 Y Y m c 3 PI up �a r ti d a. Sm V ,aei - o —o et; - o M —Lc )c _ I-- G `cA = I ° - o —o \k I - o —N 1 - N VI /\ _O - o O^ = N I IIII IIII IIII IIII IIII IIII IIII IIII IIII IIII IIII IIII IIII IIII IIII IIII IIII - N C O O O O O O O O O o O O O O O O O O N O N O IJ7 O O O N O In o N CV O co O O csk t") c7 N up N N N ^ N N O ^ N N N I!) ^ O U (u!M OSL)(+)41-1oN/(-)4inoS ORU3INM o > > o N D7 > O d p > > J J O N N U M N Q CO /^�++ O J J M ..-• M CO N • = ,Y > ° (-) '-. >Vo 2 > > 2 < M J •� T..':.. .5 U — — M m ; Q co M M 1 Q ` O S S �7 2 = co r 'EL.- C'-' ,..,.., N ,- C•1 O M m co Q CO CO O Z 7 7 2 S S d ...i..... L L1J S S co N N M S CO N N • N • co M J J J co J J J _ _ I I J • • W W r O O O O O m M cococoO ' _ CO CO Q �r N_ }� O J S = = S S S S 2 S S S S 3 co N - • La ! , _ co M M M M M M M M M M M _ M i ••._• e o 0 0 0 o v ri ri ri ri ri CV N � 2 .� F - co co co co M N- \I P �, a} S S = S S S S S S S 2 S S �� y M CO CO CO M M CO M CO M CO CO CO •• � ; 4) + CP + • N x o Op J / J"• 0 X 3 x = Cl):* : 0 7 / F-- ce) • r co / , _ _ , • CO 1 y CO• M • c M ` Q co 0`0 • co O • O 2 • M M a M M x c`a = a - M U = M 1 (V O d'M .. '" E O • I r Y y C = ? ' 1 I i 22'2 = r I M f0 10"'d • ' I I co Y Y m Ti • 3 n° ••=.- ae J e� o U =sm 1 I m>u CO = \e) • E as G z w • •':. • • •N • •• • • •0 •• 0 • • • • / A ORtGINAL 3H-11A Schlumberger CemCADE Preliminary Job Design 7" Intermediate Casing Rig: Nordic 3 1st Sta•e V2, WP-10) Location: Kuparuk Client: COP Revision Date: April 16,2012 Volume Calculations and Cement Systems Prepared by: Mike Martin o Location:Anchorage,AK Volumes are based on 50/o excess. The top of the tail slurry is designed to be Phone: (907)263-4207 at-5,800' MD. Mobile: (907)748-6900 email: martin13@slb.com Tail Slurry Minimum pump time: -185 min. (pump time plus 120 min.) 15.8 ppg Class G +2.0 gps D600G + 0.4% D65 + 0.15% D153 + 0.4 gps D47 + retarder as needed- 1.17ft3/sk • 0.1503 ft3/ft x(7,124'-5,800')x 1.50 (50% excess) = 299 ft3 0.2148 ft3/ft x 80' (Shoe Joint) = 17 ft3 299ft3+ 17ft3 = 316 ft3 Previous Csg. 316 ft3/1.17 ft3/sk= 270 sks < 10-3/4",45.5.#casing at 3,637'MD Round up to 280 sks BHST = 140°F, Estimated BHCT = 113°F. (BHST calculated using a gradient of-2.0°F/100 ft. below the permafrost) PUMP SCHEDULE Stage Cumulative Stage Pump Rate Volume Stage Time Time (bpm) (bbl) (min) (min) CW100 5.0 40.0 8.0 8.0 MUDPUSH II 5.0 40.0 8.0 16.0 Drop bottom plug 0.0 0.0 5.0 P1.0 GasBLOK Slurry 6.0 56.2 9.4 30.4 Drop top plug 0.0 0.0 5.0 35.4 Seawater 5.0 10.0 2.0 37.4 Switch to rig 0.0 0.0 3.0 40.4 < Top of Cement at Mud 6.0 253.5 42.3 82.7 -5,800'MD] Mud 3.0 6.0 2.0 gq 7 MUD REMOVAL < 7",26#casing Expected Mud Properties: 9.5 ppg, Pv< 14, T <25. in 8-3/4"OH Spacer Properties: 11.0 ppg MudPUSH* II, Pv=22-28, Ty= 30 - 38 TD at 7,124'MD Centralizers: As per COP program (5,980'TVD) Mark of Schlumberger 3H-11A Schlumberger CeCnCADE Preliminary Job Design 7" Intermediate Casing Rig: Nordic 3 2nd Sta•e-Tabasco V2, WP-10 Location: Kuparuk Client: COP Revision Date: April 16,2012 Volume Calculations and Cement Systems Prepared by: Mike Martin Volumes are based on 50% excess. The top of the tail slurry is designed to be Location:Anchorage,AK Phone: (907)263-4207 at-3,700' MD. Stage/Port Collar at 4,900' Mobile: (907)748-6900 email: martin13@slb.com Tail Slurry Minimum pump time: -170 min. (pump time plus 120 min.) 12.5 ppg LiteCRETE + 0.2%D46 + 0.25% D65 +0.25% D167 +0.1% D153- 1.56 ft3/sk 0.1503 ft3/ft x(4,900'-3,700')x 1.50 (50%excess) = 270 ft3 Previous Csg. 10 3/4",45.5.#casing 270 ft3/ 1.56 ft3/sk = 173 sks < at 3,637'MD Round up to 180 sks < Top of Cement at 3,700'MD BHST= 103°F, Estimated BHCT = 92°F. (BHST calculated using a gradient of-2.0 °F/100 ft. below the permafrost) PUMP SCHEDULE Stage Cumulative Stage Pump Rate Volume Stage Time Time (bpm) (bbl) (min) (min) . CW100 5.0 30.0 6.0 6.0 MUDPUSH II 5.0 30.0 6.0 12.0 LiteCRETE 5.0 48.2 9.6 21.6 Drop plug 0.0 0.0 3.0 24.6 < 7",26#casing Seawater 5.0 10.0 2.0 26.6 in 8-3/4"OH Pause 0.0 0.0 3.0 29.6 Mud 6.0 168.5 28.1 57,7 Slow for plug 3.0 9.0 3.0 60.7 MUD REMOVAL Expected Mud Properties:9.5 ppg, Pv< 20, Ty<25. Spacer Properties: 11.0 ppg MudPUSH* II, Pv=22-28,Ty= 30 - 38 i Collar at 4,900'MD (4,148'TVD) •Mark of Schlumberger ORIGINAL 3H-11A Schlumberger CemCADE Preliminary Job Design 4-1/2" Production Liner (V2, WP-10) Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Nordic 3 Volume Calculations and Cement Systems Location: Kuparuk Client:CPAi Revision Date: April 16,2012 Volumes are based on 30% excess. Displacement is calculated with a 4.0"- 15.7#drill Prepared by: Mike Martin pipe using mud. Location:Anchorage,AK Phone: (907)263-4207 Tail Slurry Minimum thickening time: -150 min. (pump time plus 120 min.) Mobile: (907)748-6900 15.8 ppg Class G +2.0 gps D600G + adds- 1.17 ft3/sk email: martin13@slb.com Annular Volume: 0.0942 ft3/ft x (7512'-7124')x 1.30 (30% excess) = 48 ft3 Lap Volume: 0.1044 ft3/ft x(7124'-6900')x 1.00 (no excess) = 23 ft3 Top of Slurry at end of pumping Cap Volume: < 6,700'MD 0.1276 ft3/ft x(7100'-6900')x 1.00 (no excess) = 26 ft3 Shoe Volume: _ < Liner Top at 0.0854 ft3/ft x 80'x 1.00 (no excess) = 7 ft3 -6,900' MD Totals: 48ft3+23ft3+26ft3+ 7ft3= 104ft3 104 ft3/ 1.17 ft3/sk = 89 sks (-95 on site) 7",26#casing at 7,124'MD BHST = 145 °F, Estimated BHCT = 115 °F. (BHST calculated using a gradient of 2.1 °F/100 ft. from surface) PUMP SCHEDULE 4-1/2",12.6#liner Stage Cumulative in 6-1/8" hole Stage Pump Rate Volume Stage Time Time (bpm) (bbl) (min) (min) CW100 5.0 15.0 3.0 3.0 MUDPUSH 11 5.0 15.0 3.0 6.0 GasBLOK Slurry 5.0 18.4 3.7 9,7 Pause 0.0 0.0 3.0 12.7 Seawater 5.0 10.0 2.0 14.7 Pause 0.0 0.0 3.0 17.7 Mud 5.0 62.5 12.5 30.2 Mud 2.0 6.0 3.0 33.2 C4 at-7,152'MD MUD REMOVAL Recommended Mud Properties: 11.5 ppg, Pv <20, Ty< 15. As thin and light as possible to aid in mud removal during cementing. TD at-7,512'MD Spacer Properties: 13.0 ppg MudPUSH* II, Pv 25- 30, Ty 35-40 (6,254'TVD) Centralizers: As per CPAi program Mark of Schlumberger ORIGINAL 3H-11A Slot Recovery Proposed Schematic 16"conductor set at 115' Schlumberger TRMAXX-CMT a SCSSV @ 1,930'MD/ 1,800'TVD 10-3/4"X 7"Arctic Pack on 12/29/87 49 bbls cement+110 bbls Arctic Pack Cement interface could be+/-2,260'. le 3-1/4"9.3#,L-80,EUE Tubing Cut/pull 7" Wash over 7"to+/-200'below 10-3/4"J-55,45.5#surface surface shoe to+/-3,840'MD casing @ 3,637'MD. 2nd TAM Port Collar @+/-3,700'MD i GLM# TVD ft MD ft Valve Type •:•: 2, UAL 1 2,500 3,027 Dummy '� 5' t�Y 2 3,700 4,450 Dummy Tabasco sand @3,950--4,300' \IP \ (J. 3 4,600 5,456 Dummy \, 4 5,281 6,375 Dummy 5 5,781 7,023 SOV(annulus to tubing shear) Note: 5 ea Camco 3-1/2"x 1-1/2" MMG 1"TAM Port collar+/-4,900'MD 100'Hi-Vis Pill @4,800'—4,900'MD Nit ;Cut&Pull plan if Cut&Pull 7"+/-4,900'MD no cement behind original 7"bridge plug+/-4,930'MD 7"Casing 1101 3 ''h"tubing Cut @+/-5,197' TOC @5,800'MD/4,957'TVD TOC in 7"&3-'/z"tubing +/- 6,789' :::::`` l t c Lower part of well to <: he abandoned by coil :'? /' `before rig move in < !:'III':::::< 3 ''/z" HES"X"selective nipple vv/ • Cement Retainer+/-7,164'MD 2.813"ID @+/-6,940'MD Baker ZXP liner top Packer@ 6,900' Q .� . MD/5,821'TVD Ii ``' 7"26#L80 BTCM casing set(topset) '` @ 7,124'MD/5,980'TVD 7" cement job on 12/28/87:450 sks lead+200 sks tail.. Theoretical TOC+/-3,716' (50%excess) No returns. —NO:;::::::::; "'oil :;:.:. 4-1/2" 12.6#L80 IBT Liner set —oil. ca 7,512'MD/6,255'TVD ' --QIN::.:::::: ......_ ORIGINAL _ 1 I 1=1 I 1/8-5000(R-35) 0 i I a I A ::iil I 4, I 0:35d- 11:i 1 I ft. 7 1/16-5000(5-46) f 1 0 I ,.A. .t1;17:71+ it .... ' -f 1 4 11111 f :i L, , .,,, ... ; . aor 1 • 1 _ -7,, .0 iiii, 54-39 t 1 Ill • —I— fr'' -I-, A 1 . p- i r 1!gy AO 1.1 . — 6 ® P 41 le 1::: —-—. -- r•i ii .171. ii •— 11-3000(H53) )I -,-- 1 -----"'"- 30D0 I 0 Liji t :'I: 1.0 1925 0 l' 1 i 1 ('4-ri 1(40r&O. 1 r iNOr/I w• A 4p- f/ I ti-- j 0 11 , r im 1 3E0 RI 1521 _ p 4)1 1 II. k-a VERTER HEAD 19-100-230I 1 .7 I ..,-- P\-tOjeD C5G r oo cso i 3 1/2 TBG ARCO ALASKA INC. (KUPARUK FIELD) 1,1941= 11111.271 01 47 1 atararilm=mp]nanxibirlimoYme u-) i wax wirruiriwil Y7: .IIVITIIIMMIIIII 0 OMINI • I/ 0 4 CREZ.311.11M i41111,1141 REF 5/4-10325 82 5 C61:1-551:154L1 MIEEMICM:011571_4&1111111111 ...VS 6 •21l110:65171.14214,11TAITD.SISFLEMIMII 0 — WELLHEAD SYSTEM= . VIC ° nua=rporr 0 1C11.14.1faISSA4TrillWant — GEN. IV KUPARUK ..n ... ..... o S si- a16'n-rwriTcsmailimran _ EQUIPMENT — ""....- .006001.1004549 MINI=1111111111•1111111111111111111111 nr? ! GI Nj A 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. TRANSMITTALLETTER CHECKLIST WELL NAME '"1/e6 311 /�- ! � PTD# Z l2 c Development Service Exploratory Stratigraphic Test Non-Conventionale-41- FIELD: ILu- cw-�k_.. /c i i"-e-41- POOL: c't / 'bre Cr) Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev:9/09/2011 a) N m O N n CO 0 U O �o m E -16 — 7 O O' E ami w • Q - b Q -@0 `� c c a)a) E as o C a) a) a) n C C o y 0 O = E coi N O =_a 2 U) O - = . 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To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. FINAL WELL REPORT MUDLOGGING DATA 3H-11A Provided by: Approved by: Mike Werner Compiled by: Justin Rosenblume B r i t t e n A d a m s Distribution: 10/29/12 T.D. Date: 10/2/2012 3H-11A 1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ................................................................................................ 2 1.1 Equipment Summary ...................................................................................................................... 2 1.2 Crew................................................................................................................................................ 2 2 WELL DETAILS ..................................................................................................................................... 3 2.1 Well Summary................................................................................................................................. 3 2.2 Hole Data ........................................................................................................................................ 3 2.3 Additional Comments ...................................................................................................................... 3 2.4 Daily Activity Summary ................................................................................................................... 4 3 GEOLOGICAL DATA ............................................................................................................................. 6 3.1 Lithostratigraphy ............................................................................................................................. 6 3.2 Mudlog Summary ............................................................................................................................ 7 3.2.1 Kick Off Point (KOP) ................................................................................................................ 7 3.2.2 Tabasco ................................................................................................................................... 9 3.2.3 C-35 ....................................................................................................................................... 12 3.2.4 C-30 ....................................................................................................................................... 14 3.2.5 K-1 Marker ............................................................................................................................. 16 3.2.6 Top of Kuparuk ...................................................................................................................... 16 3.2.7 C4 .......................................................................................................................................... 17 3.2.8 B Shale .................................................................................................................................. 18 3.2.9 A5 .......................................................................................................................................... 19 3.2.10 A3 .......................................................................................................................................... 19 3.2.11 A2 .......................................................................................................................................... 20 3.2.12 A1 .......................................................................................................................................... 20 3.2.13 Base of Kuparuk .................................................................................................................... 21 3.3 Connection Gases ........................................................................................................................ 22 3.4 Trip (Wiper) Gases........................................................................................................................ 22 3.5 Sampling Program / Sample Dispatch .......................................................................................... 23 3.6 Show Reports ............................................................................................................................... 24 4 PRESSURE/FORMATION STRENGTH DATA ................................................................................... 26 4.1 Pore Pressure Evaluation ............................................................................................................. 26 4.2 Quantitative Methods .................................................................................................................... 26 5 DRILLING DATA .................................................................................................................................. 28 5.1 Survey Data .................................................................................................................................. 28 5.2 Bit Record ..................................................................................................................................... 30 5.3 Mud Record .................................................................................................................................. 31 5.4 Abbreviations ................................................................................................................................ 31 6 DAILY REPORTS ................................................................................................................................ 32 Enclosures: 2”/100’ Formation Log (MD/TVD) 2”/100’ Drilling Dynamics Log (MD/TVD) 2”/100’ LWD / Lithology Log (MD/TVD) 2”/100’ Gas Ratio Log (MD/TVD) Final Well Data on CD/ROM 3H-11A 2 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Downtime Comments Ditch gas QGM Agitator (Mounted in possum belly) Flame ionization total gas & chromatography. 0 Effective Circulating Density (ECD) From Sperry-Sun 2731’ to TD 0 Hook Load / Weight on Bit Totco WITS Feed 2 hrs Totco data feed in and out during network interruptions Mud Flow In Derived from Strokes/Minute and Pump Output 2 hrs See above Mud Flow Out Totco WITS Feed 2 See above Mudlogging unit computer system HP Compaq Pentium 4 (X2, DML & RigWatch) 0 Mudlogging unit DAC box In-unit data collection/distribution center 0 Pit Volumes, Pit Gain/Loss Totco WITS Feed 2 hrs See above Pump Pressure Totco WITS Feed 2 hrs See above Pump stroke counters Totco WITS Feed 2 hrs See above Totco Well Monitoring Components Totco computer networked in Mudlogging Unit 2 hrs See above Rate of penetration Totco WITS Feed 2 hrs See above RPM Totco WITS Feed 2 hrs See above Torque Totco WITS Feed 2 hrs See above 1.2 Crew Unit Type : Steel Arctic Unit Number : ML056 Mudloggers Years *1 Days *2 Sample Catcher Years Days Justin Rosenblume 1 24 Mike Sherry 0 24 Britten Adams 1 24 Frank Thrailkill 0 24 *1 Years experience as Mudlogger *2 Days at wellsite between spud and total depth of well 3H-11A 3 2 WELL DETAILS 2.1 Well Summary Well: 3H-11A API Index #: 50-103-20091-01-00 Field: Kuparuk River Field Surface Coordinates: 1232’ FSL, 281’ FWL, Sec. 12, T12N, R08E Borough: North Slope Primary Target Depth: 7085’ MD/ 6050’ TVD State: Alaska TD Depth: 7375’ MD/ 6258’ TVD Rig Name / Type: Nordic 3, Arctic Triple Suspension Date: Primary Target: Kuparuk A and C Sands License: Spud Date: 18 September 2012 Ground Elevation: 38.7’ AMSL Completion Date: 4 October 2012 RT Elevation: 68.7’ AMSL Completion Status: Run 7” Liner. Secondary Target: Depth: 3750’ – 4100’ MD Classification: Kuparuk Injector TD Date: 3 October 2012 TD Formation: Kuparuk Sands Days Testing: None Days Drilling: 7 2.2 Hole Data Hole Section Maximum Depth TD Formation Mud Weigh t (ppg) Dev. (oinc) Coring Casing/ Liner Shoe Depth LOT (ppg ) MD (ft) TVDSS (ft) MD (ft) TVD (ft) 8 ¾” 6968’ 5969’ K-1 Marker 10.1 0.41 No 7”-26lb 6968’ 5969’ 11.0 6 1/8” 7375’ 6258’ Kuparuk 10.5 0.00 No 4 ½” 11.0 2.3 Additional Comments The original 3H-11 well was drilled in December 1987 as a producer in the Kuparuk A- and C- sands. There were no returns on original cement job and a CBL was run on February 15, 1988. Currently the well was shut in due to high WC since 2010. Well 3H-11A is part of a 4 well re- development concept in an area that contains many baffling and sealing faults. After initial problems with de-completion, the whip-stock was set and sidetrack was made by milling a window in the 10 ¾” casing from 2701’ to 2731’. Well was established at 2732’ MD. The well was spudded using an 8.75” tri-cone bit and continued to 4238’ MD/P3707.26’ TVD where the BHA was pulled out so that a Rotary Coring Assembly could be run in on a wire-line. Drilling continued with no major problems to a depth of 6968’ MD/5969’ TVD where 7”-26 lb/ft casing was set. TD was reached at 7375’ MD/6258’ TVD with a 6 1/8” PDC bit. A 4 ½” production liner was set at 7375’ MD/6258’ TVD. 3H-11A 4 2.4 Daily Activity Summary 9/3/2012 - 9/11/2012: Canrig Rig-Up and Set up Equipment. Work Over Operations. 9/12/2012: Pull and Cut 7” Coil Tubing Liner. Canrig on Stand-by. 9/13/2012: Milling 7” liner from 2550’ to 2750’. Canrig on Stand-by. 9/14/2012: Milling 7” liner from 2550’ to 2750’. Canrig on Stand-by. 9/15/2012: Milling 7” liner from 2550’ to 2750’. Canrig on Stand-by. 9/16/2012: RIH to set Whip-stock. Canrig on Stand-by. 9/17/2012: RIH and Mill a window. Top of window is at 2701’ and bottom at 2721’. Canrig on Stand-by. 9/18/2012: Weekly BOP Test, Clean and clear rig of unneeded tools. Set test plug, wash BOP stack, open doors to perform cavity inspection. Close BOP ram cavity doors. Conduct weekly BOP test at 250/3000 psi. Test Variable Rams and annular with 4” and 5” test joints. Complete BOP testing. Begin PU MU of BHA #1. 9/19/2012: Install Wear ring. Make up and Pick up Drilling BHA #1. Run in hole to 87’ and then download LWD Tool. Continue to RIH from 87’ to 637’ MD. Conduct shallow pulse test on BHA #1. Test is good. Continue to run in hole to 2630’. Circulate 10 barrels per minute at 870 psi. Continue to run in hole to 2730’ with pumps off. Drill ahead from 2730’ to 3007’. Drill ahead from 3007’ to 3130’. Drill ahead to 3900’. 9/20/2012: Continue to drill ahead from 3900 ft through Tabasco formation to 4238. CBU and condition OH section for logging purposes. Spot new 9.6 ppg LSND down DP at 10 bpm. Circulate surface to surface +10 bbls. Monitor well. POOH with BHA #1 from 4238 to 738 ft. Monitor well. Continue to POOH, stand back BHA. Load HES tools. RU E-line. RIH w/ HES 6 arm caliper and sit down at 2684 ft. POOH, reconfigure tool string, RIH and set down at 2681 ft. POOH, found clay on tools. Change tools to coring tools @ 22:45 hrs, RIH. Attempts failed. 9/21/2012: Set back E-Line and pull dutch riser. MU RIH w/ BHA #25 to 4238 ft. Circulate 12 bpm at 1140 psi. A lot of clay and cuttings over shakers between 1-2 bottoms up. Cleaned up after 2# bottoms up. POOH to 2750 ft. RIH w/ pumps off to 2849 ft, no indication of trouble area. Pump out of hole 2688 to 2650 ft at 12 bpm. Circulate 3X bottoms up. Clean returns. POOH w/ BHA #25. RU E-Line. RIH w/ Caliper logging tool, set down at 2714 ft. POOH remove centralizer. RIH to 4240 ft, log back to window at 2701 ft. POOH. RIH w/ coring tools and begin operations. 9/22/2012: Drill selective core logs in Tabasco interval. Core 3# wouldn’t go in chamber. POOH. Recover core from 3849’. RIH w/ mechanical sidewall coring tool. Core stuck in tube, POOH. RD primary toolstring, RU and test backup string. RIH and attempt recovery. Lost oil pressure in tool. POOH. RD e-line and dutch riser. PU Drilling BHA #26. RIH to 633’, conduct shallow pulse test. Continue RIH to 2627’. Continue RIH to 4146’. Continue to RIH to 4239’. 9/23/2012: Continue to RIH 4146’ to 4235’. Continue to drill ahead sliding and rotating as per DD from 4238’ to 5239’. Continue drilling to 5377’, circulate BU. SPR’s at 5285’ with 9.6ppg. Continue drilling to 5471’. Drill ahead to 5663’. 9/24/2012: Pump 40 bbl 12ppg weighty hi-vis sweep and circulate surface to surface @ 500gpm at 2180 psi. Monitor well. POOH on elevators to 4842’ and began pulling over by 10 to 20K to 4685’. Continue POOH back reaming up from 4713’. Circulate bottom-up 1.5X rotating 3H-11A 5 and reciprocate from 2914’ to 2819’. POOH to 2630’. BDTD, slip and cut drilling line, service top drive. RIH from 2630’ to 2688’. Continue RIH down to 5362’. Drill ahead to 5835’. 9/25/2012: Continue to slide at 5855’ to 5890’. Continue to slide and rotating per DD. At 6163’ sliding at 45 degree. At 6297’ sliding at -45 deg. At 6398 sliding at 0 deg. At 6603’ rotating. Slide from 6705’ to 6732’. Continue rotating per DD. Continue drilling to 6896’. 9/26/2012: Drilling ahead from 6895’ MD at 12.5 BPM. TD called at 6965’. Back ream up to two stands, RIH to 6965’ and shoot survey while circulating at 204 SPM 2355 SPP. Circulate hole clean at 12 BPM while rotating at 50 rpm, 2330 SPP, while reciprocating DP slowly. CBU 4X racking back one stand after each BU. POOH from 6600’. Standing back DP & maintaining proper hole full while POOH. 9/27/2012: TOOH. Orient up thru window. No problem pulling thru window. Continue TOOH; performing Torque & Drag every 10 stands. Stand back HWDP & Collars. Load Storm Packer. Drain & Clean Stack. Pull Wear Ring. RU Storm Packer Assembly. Test packer. Set Test Plug. Test BOPE w/7”. Rig down Test Equipment. 9/28/2012: MU Pulling Assembly to retrieve Storm Packer. Latch & release Storm Packer & pull to rig floor. Continue POOH laying down Drill Collars & HWDP. Change out handling equipment to run 7” CSC. MU Shoetrack with Bakerlock and RIH 7” CSC to 2611’. Circulate @ 6 BPM. Continue to RIH W/7” Casing. 9/29/2012: Circulate 7” CSC to bottom for space of cementing head. Reach TD w/7” casing completion. Swap out bails for cement head. Install cement head. Circulate hole & thin mud properties to condition mud. Begin cementing operation. Rig down cementers. Wait on cement. 9/30/2012: NU BOPE. Lower rams from 7” to VBR’s & RU riser. Perform SIS NOV derrick inspection. Load Tubing. Perform bi-weekly BOP Test. Test VBR’s & annular with 3 12”, 4” & 4 ½” Test Joints. Performed draw down test. RD testing equipment & pull Test Plug. RU circulating equipment & perform “LOT for Freeze Protection Annulus”. 10/1/2012: RU Circulate equipment & pump 200 BBL fresh water after pumping 4 BBL of 10 ppg Mud for LOT Test. Pump Freeze Protect, 100 BBL diesel down to 2000’ with LRS. Install wear ring. MU 6 1/8” drilling assembly, unload LWD, shallow pulse test-good. Load nuke sources, BDTD, continue MU BHA. RIH to 3885’. Wash down @ 2.5 BPM @ 600 psi. Tag cement @ 3955’. Drill thru and tag plug @ 3983’.Drill cement & wash 4070’. RIH to 6730’. Wash down to cement Tag @ 6767’. Perform casing integrity test. Drill cement inside 7” casing. 10/2/2012: Continue jarring operation to free stuck drilling assembly. Freed after 22 jar hits up & 6 jar hits down. CBU. Perform derrick inspection after jarring. RIH to casing shoe & continue to drill out into formation 20’. Drilled town to 6985’. 10 ppg drilling fluid contaminated. CBU. PU above shoe and monitor well while conditioning mud to 10.5 PPG. Conduct FIT/ LOT w.10.5 ppg fluid in hole. EMW 16.1 ppg. RIH to 6950’ & set drilling parameter @ 81 SPM @ 1325 SPP, rotating @ 51 Rpm, Free Rotating 125k, 4-5k WOB. Drilling ahead. 3H-11A 6 3 GEOLOGICAL DATA 3.1 Lithostratigraphy LWD tops refer to provisional picks by the ConocoPhillips geologist. FORMATION PROGNOSED LWD PICK MD (ft) TVDSS (ft) MD (ft) TVDSS (ft) Kick Off Point (KOP) 3720’ -3145’ 2701’ -2332’ Tabasco (Top) 3935’ -3238’ 3775’ -3268’ C-35 5332’ -4468’ 5225’ -4514’ C-30 6496’ -5467’ 6314’ -5439’ HRZ (Top) 6700’ -5611’ 6502’ -5574’ HRZ (Bottom) 6873’ -5734’ 6735’ -5734’ K-1 Marker 7029’ -5844’ 6891’ -5847’ 7” Casing Point 7100’ -5970’ 6965’ -5900’ Top Kuparuk D 7000’ -5921’ 7005’ -5930’ Top C4 7017’ -5931’ 7012’ -5934’ Top B Shale 7050’ -5955’ 7031’ -5951’ Top A5 7109’ -5996’ 7085’ -5987’ Top A3 7124’ -6007’ 7095’ -5995’ Top A2 7152’ -6027’ 7124’ -6013’ Top A1 7198’ -6059’ 7173’ -6047’ Base Kuparuk 7264’ -6110’ 7250’ -6103’ TD (Miluveach) 7375’ -6186’ 7375’ -6179’ 3H-11A 7 3.2 Mudlog Summary 3.2.1 Kick Off Point (KOP) 2701’ to 3774’ MD/2401’ to 3336’ TVD (2332’ to 3267’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 3019 0 182.79 9 1 5 The Kick Off Point (KOP) interval includes clay, claystone, sand, conglomerate sand, tuff and traces of siltstone. From 2701’ MD to 3774’ MD, the interval starts off as 100% sand and then becomes increasingly more clayey at depth. The interval from 3300’ to 3774’ MD is 80-90% clays. There was a weak tarry oil show from 2965’ to 3055’ MD. Sand (2730’ - 2800’) = medium gray to medium dark gray overall; quartz framework containing mafics and trace light greenish gray lithics; dominantly unconsolidated lower coarse to upper fine grained; fair to well sorted; grains are sub-rounded to sub-angular with moderate to low sphericity; bulk of sample consists of smoky quartz grains and mafics in a silica based cement; void spaces contain siliceous matrix material; sample is overall slightly calcareous; trace orangey volcanic lithic clasts; no petro odor at shakers; no visual cut, extremely faint pale light straw visual crush cut with very faint light yellow-orange fluorescence; no stain; no other petro indicators. Sand/Conglomerate Sand (2800’ - 2900’) = overall medium gray to medium dark gray in color; dominant quartz framework containing mafics and lithics in a clayey matrix material; grains range from upper fine to very coarse; fair to poor sorting; sub-angular to angular as well as sub- rounded; sub-discoidal to spherical or moderate sphericity; grains show mechanical abrasion such as impact and grind marks from the bit, also etched; still unconsolidated with a larger range of grain sizes than before; sand grains connected as more clayey nodules or curds with clayey earthy cement or interbedded clay material; sand still contains trace bright colored lithics; traces of carbonaceous or woody materials; no visual cut or visual crush cut; no odor at shakers; no stain; no free oil. Sand/Conglomerate Sand (2900’ - 3000’) = overall medium dark gray to medium gray with faint brownish gray hues; mainly a quartz framework containing mafics, lithics and traces of shales in a very clayey or ashy matrix material; grains range from very coarse to upper fine; poorly sorted, angular to sub-angular or sub-rounded grains; moderate sphericity; common impact or grinding marks on grain surfaces; dominantly unconsolidated sand grains suspended in small inconsistent nodules of clayey material; faint sheen on sample; light straw visual crush cut; light straw residual cut; no petro odor; no visible staining; trace free oil. Conglomeratic Sand (3000’ - 3100’) = medium dark gray to medium gray with traces of brownish gray hues; dominant quartz framework containing mafics and lithics with traces of feldspars and occasional shell fragments; appears to be interbedded within finer layers of light gray to medium light gray gritty to silty clayey matrix material; smoky quartz grains range from very coarse to upper and lower fine; poor sorting; sub-angular to sub-rounded rounding with sub-discoidal to discoidal sphericity; clays still lumpy and clumpy to nodular in consistency; traces of oily sheen on sample, but very faint; no petro odor; no visual cut; no free oil. 3H-11A 8 Clayey Sand/Conglomeratic Sand (3100’ - 3220’) = light gray to medium light gray with lighter grayish hues than previous samples; very cohesive to plasticy; pasty to punky or tacky consistency; flexible to elastic tenacity; earthy to no visible fracture; no visible cuttings habit; dull to earthy luster, slightly greasy or waxy luster; silty to gritty and granular texture; no visible structure; no odor or iridescent sheen in sample or at shakers; no other petro indicators. Sand/Silty Clay (3220’ - 3300’) = medium light gray to medium gray overall; cohesive and plastic; very pasty to tacky in consistency; malleable to sectile and flexible in tenacity; earthy to no visible fracture; no real cuttings habit, appears massive; dull and earthy luster; silty to very gritty texture; contains conglomeratic sand grains held together in a significant amount of clay matrix material; abundant sand and silty sized grains within the clay; overall slightly calcareous; no odor or sheen at shakers; no visual cut or crush cut; no stain; no other oil indicators. Silty Clay (3300’ - 3400’) = medium gray to medium light gray with light olive gray undertones; low to moderately low density; mushy to pasty consistency; cohesive to plastic or pliable tenacity; very soft to soft induration; structure-less cuttings habit; argillaceous fracture; dull to earthy luster; silty to gritty, occasionally smooth texture; massively bedded to interbedded within the silty sands; overall non-calcareous; no petro odor at shakers; no iridescent sheen in sample; no visual cut; no crush cut; no cut fluorescence; no bulk sample fluorescence; no other oil indicators. Conglomeratic Sandy Clay (3400’ - 3500’) = light olive gray to medium gray with shades of gray; mostly unconsolidated sand grains with trace lithified well connected sandstones and siltstones; dominant light olive gray clayey material continues throughout section; very pasty and punky to tacky in consistency; earthy fracture; common massive cuttings habit; waxy to dull and earthy luster; ranges from amorphous to silty in texture with upper coarse to lower fine sand grains; massively bedded with no visible structure; no petro odor at the shakers; no visual cut; no sheen; no staining; no other petro indicators. Claystone (3495’ - 3575’) = dominant medium dark to medium gray with occasional medium light gray and yellowish gray minerals; low to moderate density; malleable to sectile tenacity; soft to easily friable induration; structure-less to irregular blocky cutting habits; earthy fracture; dull to earthy when dry and waxy when wet luster; amorphous to matte with slight silty texture; massive bedding structure; very low traces of free oil; no oil odor in sample; no oil odor near shakers; no sample cut color; slight dull yellowish sample fluorescence cut; traces of white fluorescent minerals in sample; low HCl reaction in bulky sample; no other oil indictors. Silty Claystone (3585’ - 3660’) = medium dark gray to medium gray with occasional medium olive gray color; low to very low density; lumpy to pasty consistency; sectile to malleable tenacity; earthy to slight irregular blocky fracture; massive to nodular cutting habits; dull to earthy with occasional waxy when wet luster; silty to clayey with matte texture; thick to massive structure; no odor near shakers; no free oil; no free oil; no visible stain in visible cut; white to slight orange mineral fluorescence sample; no fluorescence cut color; no residual cut; no other oil indictors; no HCl reaction. Sand (3670’ - 3725’) = dominantly translucent to clear with occasional very pale orange and grayish yellow colors; very fine grains size; sub-rounded to rounded angularity; moderate to low sphericity; sand is dominantly quartz; well to moderate sorting; most sand is aggregated due to claystone materials; no free oil; no oil odor; no visible cut color; no fluorescence cut color; bright traces of fluorescent pops with white yellowish color; no other oil indictors. Silty Claystone (3735’ - 3810’) = dominantly medium dark gray to medium gray with olive gray color; lumpy to pasty with occasional stiff consistency; malleable to sectile tenacity; earthy fracture; nodular to massive cutting habits; dull to earthy when dry and waxy when wet luster; 3H-11A 9 colloidal to matte with slight silty texture; thin to massive structure; traces of free oil; low oil odor in sample; no odor near shakers; straw color sample cut; bright traces of white yellow minerals in sample fluorescence; milky white fluorescence cut with two white streamers; light iridescent sheen in sample. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 2900 2 587.00 0 0 0 0 0 0 3000 4.939 1242.00 0 0 0 0 0 0 3.2.2 Tabasco 3775’ to 5224’ MD/3337’ to 4582’ TVD (3268’ to 4513’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 393.4 0 142.2 108 0 8.8 The top of the Tabasco formation is marked by a significant drop in Gamma and a spike in Resistivity. Clean Conglomeratic Sands were seen over the shakers and an immediate Gas Peak of 108 units was observed and recorded. The Top of the Tabasco contains about 200’ of almost 100% sand with a moderate oil show containing some free oil. The rest of the interval is made up of 70%-80% claystone, 10%-5% tuff, and 10%-15% sand. Traces of carbonaceous shell fragments were deposit 4550’ MD to 4760’ MD. Sandstone, conglomerates sand, and siltstone have thin interbedding layers throughout this formation. Weak oil showing occurred at 4950’ MD to 4955’ MD and 5050’ MD to 5085’ MD. Within the oil showing, gas units increase to 21u. Throughout the formation the gas unit base is around 7-9 units. Sand (3820’ - 3880’) = clear to translucent with occasional light bluish gray, greenish gray, light olive brown, and very pale blue color minerals; upper fine to lower fine grain size; sub-angular to sub-rounded angularity; very low to low sphericity; poor to fair sorting; dominantly quartz with micas feldspars, and etc; free oil in sample; slight oil odor in sample; straw color sample cut; light brown to orange fluorescence visual; milky white fluorescence cut; no other oil indictors. Conglomerate Sand (3890’ - 3970’) = dominantly clear to translucent with occasional moderate olive brown, pale greenish yellow, light blue green, pale yellowish green, black, yellowish gray mineral colors; quartz dominant with feldspars; chlorite and potassium alteration; disaggregated loose sands; low to high medium grain size; moderate to poorly sorted; sub-angular to sub- rounded angularity; very low to low sphericity; very weak sample odor; no odor near shakers; light brown to straw visible cut; milky white fluorescence cut with no streamers; bright white with slight yellow visual fluorescence; no other oil indictors in sample. Conglomerate Sand (3890’ - 3970’) = dominantly clear to translucent with occasional moderate olive brown, pale greenish yellow, light blue green, pale yellowish green, black, yellowish gray mineral colors; quartz dominant with feldspars; chlorite and potassium alteration; disaggregated loose sands; low to high medium grain size; moderate to poorly sorted; sub-angular to sub- rounded angularity; very low to low sphericity; very weak sample odor; no odor near shakers; light brown to straw visible cut; milky white fluorescence cut with no streamers; bright white with slight yellow visual fluorescence; no other oil indictors in sample. 3H-11A 10 Claystone (3980’ - 4050’) = medium gray to dark gray with olive gray colors; clumpy to pasty consistency; malleable tenacity; earthy to irregular blocky fracture; massive to nodular cutting habits; dull to earthy when dry and waxy to sparking when wet luster; clayey to colloidal and silty texture; thick to massive bedding structure; no free oil in sample; no oil odor in sample; no odor near shakers; no sample cut color; pale white fluorescence cut; yellowish to slight green mineral in visual fluorescence; no residual cut rings; no other oil indictors. Sand (4060’ - 4130’) = smoky to translucent with occasional light greenish gray, light gray, grayish black, very pale orange, and pale yellowish orange mineral colors; quartz dominant with feldspars; upper fine to upper very coarse grain size; poorly sorted; angular to sub-rounded angularity; very low to low sphericity; no free oil in sample; no oil odor near shakers; no odor in sample; no iridescent sheen; yellow to bright orange minerals in sample fluorescence; very pale white fluorescence cut with no streamer; no pops; no other oil indictors in bulky sample. Claystone (4295’ - 4360’) = olive gray to medium dark gray with slight brownish gray color; low density; lumpy to clumpy consistency; cohesive to malleable tenacity; earthy fractures; nodular to massive cutting habits; waxy when wet to earthy when dry luster; clayey to colloidal with matte texture; massive to thick bedding structure; no free oil; no oil odor near shakers; no oil odor in sample; no sample cut color; no fluorescence cut color; no residual rings; no pops; no sample fluorescence color; no other oil indictors in bulky sample. Silty Claystone (4390’ - 4460’) = olive gray to olive black with slight medium dark gray color; mushy to clotted consistency; malleable tenacity; earthy to irregular blocky fracture; nodular to massive with occasional platy flaky cutting habits; dull to earthy when dry, waxy when wet luster; clayey to colloidal with slight silty texture; massive to thick structure; no visual cut or visual crush cut; extremely faint light milky white visual cut fluorescence; no residual cut or residual ring; no petro odor; no other oil indicators. Ashy Clays, Siltstone/Claystone, Sand (4460’ - 4580’) = olive gray to light olive gray with shades of brownish grays and medium grays; very cohesive and adhesive to expansive; mushy to pasty and tacky in consistency; malleable to sectile in tenacity; dominantly no fracture to earthy, but siltstones and claystones appear more mottled; clays have no visible cuttings habit, siltstones are nodular and claystones have a nodular to wedge-like cuttings habit; dull to earthy in luster; clayey to silty and gritty to abrasive texture; fine olive black to medium dark gray laminae running through claystones; trace shell fragments and a range of fine to coarse quartz and feldspathic sand grains interspersed in clays; overall slightly calcareous; no visual cut or crush cut; very faint slight milky white fluorescence; no other oil indicators. Silty/Sandy Clay, Carbonaceous Shale (4580’ - 4710’) = olive gray to brownish gray with light olive gray tones; overall very adhesive and plastic to pliable; gelatinous to mushy, pasty and punky in consistency; very sectile and elastic tenacity; earthy fracture containing some well connected grains and trace olive black blocky shales; clays have massive cuttings habit; silty and sandier grains are slightly more well lithified and trace shales have a blocky lithified platy cuttings habit; overall dull to earthy luster; bulk sample is slightly more abrasive than previous in texture; common massive structure with cuttings showing no laminations that were found at shallower depths; carbonaceous shales appear very thinly bedded; traces of shell fragments have vigorous reaction to HCl and continue through section; very faint slight milky white visual cut fluorescence continues; no other petro indicators. Sandy Clay, Sandstone (4710’ - 4800’) = olive gray to brownish gray with medium gray undertones; overall very clayey and adhesive properties; very mushy and punky in consistency; sectile and malleable; earthy fracture; massive cuttings habit; dull to earthy luster; gritty to granular in texture; massively bedded; sandstones appear grayish yellow to yellowish gray 3H-11A 11 overall; fine grained clear to translucent quartz grains connected with a yellowish gray calcareous cement; very very faint milky white fluorescence; no other oil indicators. Clay, Siltstone, Tuffaceous Sandstone (4800’ - 4910’) = light olive gray to olive gray with brownish gray shades; still dominantly clay properties but significantly more connected and grainy; much more cohesive rather than sticky and adhesive; much more curdy to clumpy in consistency; crumbly to friable or easily friable; hackly to earthy fracture; gritty to granular loose grains and connected pale yellowish orange tuffaceous sandstones that have a faint yellowish green bulk fluorescence; siltstones are much more prevalent throughout the section; overall phylloids seem much more competent rather than loose clay/ash; no visual cut or crush cut; no staining; overall spotty yellowish green bulk sample fluorescence; faint milky white visual cut fluorescence; no other indicators. Silty Clay, Sand, Sandstone (4910’ - 5000’) = olive gray to light olive gray with brownish gray tones; adhesive; gelatinous to mushy and pasty or tacky in consistency; malleable to sectile in tenacity; earthy to no fracture; overall massive cuttings habit with trace nodular silty inclusions; dull to earthy luster; clayey to slightly silty or gritty texture; massively bedded with no visible structures in cuttings; faintly calcareous overall; no visual cut, slight faint dull yellow visual cut fluorescence; no other indicators. Silty Claystones, Tuffaceous Sandstones (5000’ - 5100’) = olive gray to light olive gray with brownish grays containing pale yellowish orange specs of tuffaceous sandstones; overall very mushy and pasty to tacky; sectile and pulverulent tenacity; earthy to hackly fracture; massive cuttings habit in clay but silty claystones are platy to wedge-like or tabular; dull to earthy luster; clayey to silty or gritty texture; sandstones fluoresce a dull yellowish green in the UV box; overall bulk sample fluorescence is spotty; massively bedded clays with more thin sandstones interbedded; no visual cut or crush cut; dull moderate yellow green visual cut fluorescence; slight sheen in sample and trace bright yellow pops; no other petro indicators. Clay, Siltstone (5100’ - 5190’) = olive gray to medium gray with brownish gray undertones; cohesive to plastic; gelatinous to mushy and pasty consistency; pulverulent and malleable tenacity; earthy to no fracture; siltstones show planar to irregular fracture; massive cuttings habit overall but siltier sections appear platy to flaky; dull to earthy luster; clayey to silty and gritty in texture; siltstones have upper very fine to lower fine grains and are sub-rounded to sub-angular; sub-discoidal to sub-prismoidal sphericity; no odor or iridescent sheen at shakers; no visual cut or crush cut; no staining; very faint dull milky white visual cut fluorescence; no residual cut or residual fluorescence; no other petro indicators. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 3808 27.603 6631.96 85.860 0 0 0 0 0 3851 180 19640 280.44 20.50 0 0 0 0 3860 76 18043.67 262.46 15.07 0 0 0 0 3896 6.93 1288.69 19.91 0 0 0 0 0 4651’ 15 3823.390 38.822 0 0 0 0 0 5068’ 21 4973.330 136.493 8.843 0 0 0 0 5142’ 18 4156.232 116.518 0 0 0 0 0 3H-11A 12 3.2.3 C-35 5225’ to 6313’ MD/4583’ to 5507’ TVD (4514’ to 5438’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 347.9 1.3 106.8 80 0 20.7 C-35 interval started with 80% claystone, 10-20% siltstone from 5225’ – 5400’ MD. Around 5500’- 6200’ MD, siltstone started to become more prevalent and increased to 40-45%. Traces of shell fragments, carbonaceous tuff, sand, and sandstone were observed. Gas was base line at 10u to 30u until 6260’ MD. A spike of 80u of gas appeared with immediate petroleum showing. The oil showing had weak to moderate intensity. At the bottom of the formation 10- 30% tuff appeared with decreasing claystone. Silty Slay, Ash/Tuff (5190’ - 5285’) = brownish gray to light olive gray with hints of olive gray; cohesive to pliable and clumpy to pasty in consistency, somewhat mushy; malleable tenacity; earthy to no fracture; massive cuttings habit; resinous to waxy and earthy in luster; clayey to slightly in gritty texture; massive to no structure; trace tuffaceous silts that range from upper very fine to lower fine in size; silts have a very slight effervescence; trace spotty yellowish green bulk sample fluorescence; very faint iridescent sheen on sample; no odor on sample or at shakers; no visual cut or crush cut; extremely faint milky white visual cut fluorescence; no other oil indicators. Claystone (5305’ - 5380’) = olive black to dark gray with occasional brownish black color; mushy to lumpy with slight platy consistency; malleable to pulverulent with occasional brittle pieces tenacity; earthy fractures; nodular to massive cutting habits; waxy when wet to earthy and dull when dry luster; clayey to colloidal with some silty textures; thick to massive structure; no oil odor; no odor near shakers; no visual cut color; no free oil in sample; traces of yellowish green in sample fluorescence; slight faint milky to no color fluoresce cut sample color; very weak HCl reaction in bulky sample; no other oil indictors. Siltstone (5390’ - 5460’) = olive black to brownish black with slight olive gray colors; stiff consistency; dense to crunchy fracture; platy to tabular with irregular wedge-like bladed edges cutting habits; frosted to greasy luster; silty to sucrosic texture; thin to lenticular bedding structure; no free oil; no oil odor in sample; no oil odor near shaker; no pops; no visual cut color; traces of yellowish green minerals in fluorescence sample; no fluorescence cut color; no residual rings or iridescent sheen; no other oil indictors; no HCl reaction in bulky sample. Claystone (5470’ - 5540’) = olive black to olive gray with slight dark gray color; lumpy to mushy and pasty consistency; malleable to pulverulent tenacity; earthy to mottled fracture; massive to nodular cutting habits; dull when dry to waxy when wet luster; clayey to colloidal texture; thick to massive bedding structure; no free oil; no odor in sample; no odor near shakers; no visual cut color in sample; no pops; no fluorescence cut color; traces mineral with yellowish green in sample fluorescence; no other oil indictors; very weak HCl reaction in bulky sample. Claystone (5570’ - 5645’) = olive black to brownish black with slight dusky yellowish brown color; lumpy to mushy with pasty consistency; malleable to bit pulverulent tenacity; earthy to irregular blocky fracture; nodular to massive with occasional flaky cutting habits; dull to earthy 3H-11A 13 when dry and waxy when wet luster; clayey to colloidal texture; thick bedding structure; no oil odor in sample; no oil odor near shakers; no free oil; no fluorescence cut color; no sample cut color; traces of mineral yellowish green in sample fluorescence; no pops; no other oil indictors; no HCl reaction in bulky sample. Silty Claystone (5680’ - 5680’) = olive gray to brown gray with occasional olive black color; pasty to clumpy consistency; malleable to pulverulent with occasional brittle tenacity; earthy fracture; nodular to massive with slight tabular cuttings; dull to earthy when dry and waxy when wet luster; clayey to colloidal and slight silty to matte texture; thick to massive structure; no free oil in sample; no oil odor near shakers; no oil odor in sample; no sample cut color; no fluorescence cut color; traces of yellowish green tuff in sample fluorescence; no residual colors; no other oil indictors; no HCl reaction in bulky sample. Siltstone (5790’ - 5860’) = olive black to brownish black with slight dark gray color; weak stiff consistency; brittle to crumbly with bit pulverulent tenacity; earthy to slight hackly fracture; flaky to tabular with wedge-like edges cutting habits; earthy to frosted luster; sucrosic to silty and matte texture; thin bedding structure; no free oil; no oil odor in sample; no oil odor near shakers; no sample cut color; no fluorescence sample color; no fluorescence cut color; no residual rings; no iridescent sheen; no other oil indictors; high HCl reaction due to shell fragments. Siltstone (5870’ - 5945’) = olive black to brownish black with shades of olive grays colors; clotted to very low stiff consistency; brittle to crumbly with occasional pulverulent tenacity; slight hackly to earthy fractures; platy to tabular with wedge-like edges cutting habits; frosted to earthy luster; sucrosic to matte with silty texture; thin banded bedding structure; no free oil in sample; no oil odor in sample; no oil odor near shakers; no pops; no visual cut color; traces of yellowish green in sample fluorescence; no fluorescence cut color; high HCl reaction in bulky sample due to shell fragments. Claystone (5955’ - 6075’) = olive black to brownish black with slight brownish gray and medium gray color; pasty to slimy consistency; malleable to sectile with pulverulent tenacity; earthy to fracture; massive to nodular cutting habits; waxy when wet and dull to earthy when dry luster; colloidal to clayey with occasional clayey texture; massive to thick bedding structure; no free oil; no oil odor; no oil odor near shakers; no sample cut color; yellowish green traces in fluorescence sample; no fluorescence cut color; no other oil indictor in sample; high HCl reaction due to 20% shell fragment in bulky sample. Silty Claystone (6075’ - 6140’) = brownish gray to olive gray with medium gray hues; plastic to pliable and expansive; lumpy to clumpy and clotted in consistency; pulverulent to malleable tenacity; earthy to mottled fracture, dominantly no fracture to argillaceous; massive to nodular cuttings habit; waxy to dull and earthy luster; clayey to silty and gritty; massively bedded; strong effervescence in sample; sample contains approx 60-70% mud additives for wall cake and to help increase the mud weight; spotty yellow green bulk sample fluorescence; no odor at shakers; faint iridescent sheen on sample; milky white to dull milky white visual cut fluorescence; faint light amber visual cut; bright yellowish white residual fluorescence; no free oil; no other petro indicators. Clay, Siltstone, Sand (6140’ - 6220’) = brownish gray with olive gray to medium gray shades; much more cohesive overall properties, but still clayey; clotted to mushy, but siltstones seem more competent; clay is malleable and sectile in tenacity; earthy to irregular fracture; massive cuttings habit; greasy to waxy and dull luster; clayey to silty texture; siltstones have a more scaly to tabular and wedge-like cuttings habit; brittle to crumbly and gritty showing very fine grains; traces of very pale orange carbonates with a vigorous reaction to HCl; smooth and very fine unconsolidated marl and more lithified marlstones; no odor at shakers; no sheen; no 3H-11A 14 staining; no visual cut; very faint light milky white visual cut fluorescence; no other petro indicators. Clayey Siltstone (6220’ - 6350’) = medium gray to medium dark gray with overtones of brownish gray, subtle hints of olive gray; adhesive to plastic within a very mushy pasty clayey consistency; clayey paste contains crumbly to crunchy and slightly brittle flaky to wedge-like cuttings of siltstones; overall dull to earthy luster; smooth to clayey with silty or gritty texture; massively bedded; no visual cut; no visual crush cut; trace bright yellow-orange streamers; faint milky yellow-white fluorescence; faint bright orange tarry residual fluorescence ring and faint dull yellow residual cut fluorescence; slight sheen on sample; no odor; no other oil indicators. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 6100 48.6 9082 599 276 32 62 0 0 6281 80 12826 974 511 78 167 80 110 3.2.4 C-30 6314’ to 6501’ MD/5508’ to 5642’ TVD (5439’ to 5573’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 290.5 9.3 105.9 98.7 17.5 37.6 The C-30 interval continues with clay and claystone deposits, but siltstone becomes more abundant throughout the section, it ranges in percentage from 40-80% and appears interbedded within clays and ashy clays. Traces of sandstone and tuff have thin interbedded deposits within this section. Gas units are rising while entering this section. There is a moderate gas peak right above this interval and gas begins to rise gradually towards the bottom of this interval. Clay, Siltstone, Trace Calcareous Sands (6350’ - 6470’) = olive gray to medium gray with darker shades of gray; dominantly clayey plastic and expansive containing more well lithified cuttings of siltstones; becoming more competent overall; still in and out of mushy to pasty clays; siltstones have a platy to flaky or tabular cuttings habit and contain very fine grains within a clayey cutting; trace calcareous sands ranging from upper fine to lower medium grains held together with a strongly calcareous cement or matrix material; massively bedded; traces of marly materials; no odor at shakers; no staining; no sheen; no visual cut; trace faint dull yellow residual cut fluorescence; no other oil indicators. Silty Claystone (6455’ - 6455’) = olive gray to dark gray with slight medium dark gray color; pasty to slimy consistency; pulverulent to malleable tenacity; earthy to mottled fracture; nodular to earthy cutting habits; dull when dry and greasy to waxy when wet luster; colloid-al to clayey with silty texture; thin to soft sediment deformation bedding structure; no free oil; no oil odor near shakers; no oil odor in sample; no sample cut color; traces of yellowish orange in sample fluorescence; slight milky white color in fluorescence cut; no other oil indictors; weak HCl reaction in bulky sample. Siltstone (6540’ - 6610’) = olive black to dark gray with slight olive gray color; slightly stiff consistency; brittle to crumbly tenacity; irregular to earthy with slight hackly fracture; platy to flaky with wedge-like edges and elongated cutting habits; dull to waxy luster; silty to matte and 3H-11A 15 sucrosic texture; lenticular bedding structure; no free oil; no oil odor in sample; no oil near shakers; no visual cut color; one or two yellowish minerals in visual fluorescence; weak milky white fluorescence cut colors; no other oil indicators; weak HCl reaction in bulky sample. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 6500 98 19620.974 965.501 335.832 38.949 86.062 5.163 1.405 3.2.5 HRZ 6502’ to 6735’ MD/5643’ to 5803’ TVD (5574’ to 5734’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 448.6 8.57 150.3 125.5 40.8 76.6 The lithology of the HRZ interval is dominantly 70-80% siltstone with traces of sandstone, shell fragments, and carbonaceous tuff interbedded within this section. At the top of the HRZ, a moderate gas peak of 110 units was observed and recorded. Towards the end of the interval the gas begins to taper off. A change in color and hardness occurs in this section. The sediment becomes darker (Olive-Black) and slightly harder as it is gradationally interbedded with carbonaceous shale. Throughout the HRZ, there was a weak oil showing. A light milky white color of visual cut fluorescence was logged in this section. Siltstone (6540’ - 6610’) = olive black to dark gray with slight olive gray color; slightly stiff consistency; brittle to crumbly tenacity; irregular to earthy with slight hackly fracture; platy to flaky with wedge-like edges and elongated cutting habits; dull to waxy luster; silty to matte and sucrosic texture; lenticular bedding structure; no free oil; no oil odor in sample; no oil near shakers; no visual cut color; one or two yellowish minerals in visual fluorescence; weak milky white fluorescence cut colors; no other oil indicators; weak HCl reaction in bulky sample. Siltstone (6620’ - 6620’) = olive black to olive gray with slight grayish black color; brittle to crumbly with occasional pulverulent tenacity; slightly hackly to earthy fracture; platy to tabular with bladed wedge-like edges cutting habits; waxy to greasy with occasional dull luster; silty to matte with sucrosic texture; massive structure; no free oil; no oil odor in sample; no oil odor near shakers; no visual cut color; traces of yellowish green minerals in visual fluorescence; moderate milky white color in fluorescence cut; no other oil indictors; very weak HCl reaction in bulky sample. Clayey Siltstone (6705’ - 6785’) = olive black to dark gray with slight olive gray color; brittle to crumbly with bit pulverulent tenacity; weak hackly to earthy fracture; platy to flaky with bladed wedge-like and elongated shape cutting habits; waxy to slight greasy and dull luster; silty to sucrosic with matte texture; massive bedding structure; no free oil; no oil odor near shakers; no oil odor in sample; no sample cut color; traces of yellowish mineral in sample fluorescence; no pops; very weak milky white fluorescence cut color; no other oil indictor in sample; very weak HCl reaction in bulky test sample. Siltstone (6795’ - 6865’) = olive black to grayish black with slight brownish black color; low density to crumbly and very brittle tenacity; irregular blocky to mottled with slight earthy fracture; 3H-11A 16 tabular to platy with elongated wedge-like bladed edges cutting habits; resinous to greasy luster; silty to sucrosic matte texture; thick to massive bedding structure; no free oil; no oil odor in sample; no oil odor near shakers; no visual cut color in sample; no fluorescence visual color; weak milky white fluorescence cut color; no other oil indictors; weak HCl reaction in sample. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 6550 125.5 23727.760 1266.443 442.455 47.312 105.876 5.986 6.098 3.2.5 K-1 Marker 6891’ MD/5916’ TVD (5847’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 279.9 3.9 127.6 24.4 24 24.2 The K-1 Marker is defined by a significant spike in Gamma coupled with a spike in Resistivity. Carbonaceous Shale and “true shale” were observed at this marker. The interval was dominantly siltstone and shale with traces of carbonaceous materials. Background Gas remained high for this interval and held steady around 24 units. Weak oil was observed in this interval. The 7” Casing Point was chosen to be set right below this interval about 10’ above the Top of the Kuparuk at 6965’ MD/5969’ TVD. Carbonaceous Shale (6875’ - 6950’) = gray black to dark gray with slight dark olive gray color; stiff to crunchy tenacity; hackly to splintery fracture; elongated to tabular and platy cutting habits; resinous to greasy luster; abrasive to sucrosic texture; thin to lenticular bedding structure; no free oil; no oil odor in sample; no oil odor near shakers; no pops; no sample cut color; traces of yellowish to orange brown minerals in fluorescence sample; weak milky white with slight yellowish color in fluorescence cut sample; no other oil indictors in sample; moderate HCl reaction in bulk sample. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 6891 24.4 4357.309 203.889 81.180 6.164 19.018 0 0 3.2.6 Top of Kuparuk 7005’ to 7011’ MD (-5930’ to -5933’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 316.51 0.44 110.6 24 0 4.95 3H-11A 17 The Top of the Kuparuk mainly consists of siltstone and shale, but includes a variety of interbedded sands within it. The Kuparuk Interval contains dominantly sand with thinly interbedded with lenses of shale and siltstone. Overall the interval is approximately 60% sand, 20% siltstone, and 20% shale. There is a gradual color change from the lighter/medium gray to a dusky yellowish brown to olive gray. Shale is transitioning from friable to firm friable. Sand is still quartz dominant and becoming well-lithified but accessory minerals are decreasing in samples. Siltstone (7000’ - 7080’) = olive black to dusky yellowish brown color; brittle to crunchy with pulverulent tenacity; slight blocky to hackly with occasional earthy fracture; platy to elongated with wedge-like edges cutting habits; slight waxy to frosted luster; silty to sucrosic texture; thick to massive bedding structure; no free oil; slight to moderate oil odor in sample; no oil odor near shakers; light brown to straw sample cut; traces of greenish yellow minerals in fluorescence visual; bright milky white color in fluorescence cut sample; no other oil indictors; strong HCl reaction in bulk sample. Carbonaceous shale (7085’ - 7160’) = olive black to brownish black with slight dark gray color; tough to crunchy with dense tenacity; splintery to hackly fracture; platy to flaky with elongated wedge-like edge cutting habits; resinous to greasy luster; abrasive to sucrosic texture; lenticular bedding structure; no free oil; moderate oil odor in sample; no oil odor near shakers; iridescent sheen in cleaning water; light straw color visual cut sample; bright milky white fluorescence cut sample; traces yellowish green and brownish orange color in fluorescence sample; no other oil indictors. Sandstone (7170’ - 7240’) = dusky yellow brownish to olive gray with occasion moderate to light brown color; quartz dominant; lower to upper very fine grains size; very well to well sorting; dirty silty matrix; calcareous cement; angular to sub-angular angularity; very low sphericity; easily friable to firm friable hardness; mottling to thin structure; no free oil; moderate oil odor in sample; no oil odor near shaker; light straw color in visual cut; bright milky white fluorescence cut color; brownish orange fluorescence visual; no other oil indictors; high HCl reaction in bulk sample. Carbonaceous Shale (7255’ - 7320’) = dusky yellowish brown to olive black with brownish black color; tough to crunchy with dense tenacity; splintery to sub-hackly fracture; platy to bladed with elongated cutting habits; waxy to frosted luster; abrasive to sucrosic texture; thin to lenticular bedding structure; no free oil; slight oil odor in sample; no oil odor near shakers; no iridescent sheen; very light straw visual cut; no fluorescence sample color; bright milky white fluorescence cut color with no streamers; no other oil indicators; high HCl reaction in bulk sample. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 7060 6.274 1219.01 64.546 28.348 0 0 0 0 7111 10.248 2873.901 150.816 63.840 0 0 0 0 7157 14.483 4566.727 260.601 114.159 0 0 0 0 7238 13.385 3075.442 202.446 101.223 0 0 0 0 7301 6.326 1471.477 102.267 59.572 0 0 0 0 3.2.7 C4 7012’ to 7030’ MD (-5934’ to -5950’ TVDSS) 3H-11A 18 Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 375 17.88 196.44 7.52 0.30 2.7 C4 interval is 90% siltstone and 10-15% shale/carbonaceous shale. No oil showings are in this interval. Gas units average 2.7u. At the end of the interval sand enter with 10% deposits. The C4 Interval is defined by a drop in Gamma and a Spike in Resistivity. Mostly siltstone was observed in sample as well as 10% shale. The siltstone is olive black to dusky yellowish brown. The shale is olive black to brownish black with grayer tones. Siltstone (7000’ - 7080’) = olive black to dusky yellowish brown color; brittle to crunchy with pulverulent tenacity; slight blocky to hackly with occasional earthy fracture; platy to elongated with wedge-like edges cutting habits; slight waxy to frosted luster; silty to sucrosic texture; thick to massive bedding structure; no free oil; slight to moderate oil odor in sample; no oil odor near shakers; light brown to straw sample cut; traces of greenish yellow minerals in fluorescence visual; bright milky white color in fluorescence cut sample; no other oil indictors; strong HCl reaction in bulk sample. No Peaks were observed in this interval. 3.2.8 B Shale 7031’ to 7084’ MD (-5951’ to -5986’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 205 10.79 108.04 6 1.26 3.765 The B-Shale has sand/sandstone increasing from 20-65% in interval. Siltstone went from 70-20% in this area. Gas is base at 1u with a spike of 6u just above the oil showings. These oil showings have moderate oil odor in the sample but not near the shakers. The showings continue throughout the B- shale interval. The B Shale Interval shows no major fluctuations in Gamma or Resistivity; both measurements are relatively consistent. Dark olive black to brownish black shale with traces of siltstone and sand was observed in this interval. Carbonaceous shale (7030’ – 7080’) = olive black to brownish black with slight dark gray color; tough to crunchy with dense tenacity; splintery to hackly fracture; platy to flaky with elongated wedge-like edge cutting habits; resinous to greasy luster; abrasive to sucrosic texture; lenticular bedding structure; no free oil; moderate oil odor in sample; no oil odor near shakers; iridescent sheen in cleaning water; light straw color visual cut sample; bright milky white fluorescence cut sample; traces yellowish green and brownish orange color in fluorescence sample; no other oil indictors. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 7060 6.274 1219.01 64.546 28.348 0 0 0 0 3H-11A 19 3.2.9 A5 7085’ to 7094’ MD (-5987 to -5994 TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 84.55 23.36 53.955 0.94 0.37 0.655 A5 is composed with 10% shale, 20% siltstone, and 70% sand/sandstone. Oil showings have bright milky white fluorescence cut showing and stay constant to 7094’ MD. The gas units go from 1u-0u in this interval. Sandstone (7170’ - 7240’) = dusky yellow brownish to olive gray with occasion moderate to light brown color; quartz dominant; lower to upper very fine grains size; very well to well sorting; dirty silty matrix; calcareous cement; angular to sub-angular angularity; very low sphericity; easily friable to firm friable hardness; mottling to thin structure; no free oil; moderate oil odor in sample; no oil odor near shaker; light straw color in visual cut; bright milky white fluorescence cut color; brownish orange fluorescence visual; no other oil indictors; high HCl reaction in bulk sample. No Peaks were observed in this interval 3.2.10 A3 7095’ to 7123’ MD (-5995’ to -6012’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 375.07 17.88 196.475 10.25 0 5.125 In A3 interval, the sands decrease to 50-20%. Shale and siltstone increase to 80% with shale being the dominant rock. Gas is base at 2u and spike at 10u. Oil showing are the same as A5 interval. Sandstone (7170’ - 7240’) = dusky yellow brownish to olive gray with occasion moderate to light brown color; quartz dominant; lower to upper very fine grains size; very well to well sorting; dirty silty matrix; calcareous cement; angular to sub-angular angularity; very low sphericity; easily friable to firm friable hardness; mottling to thin structure; no free oil; moderate oil odor in 3H-11A 20 sample; no oil odor near shaker; light straw color in visual cut; bright milky white fluorescence cut color; brownish orange fluorescence visual; no other oil indictors; high HCL reaction in bulk sample. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 7111 10.248 28.901 150.816 63.840 0 0 0 0 3.2.11 A2 7124’ to 7172’ MD (-6013’ to -6046’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 383.83 9.64 196.73 14.43 0.58 6.905 A2 interval starts with a decrease in sand and a thin bedding of shale/siltstone. During this section, oil showing decrease from weak to none at 7140’ MD. Around 7157’ MD, the sand/sandstone deposit began to increase again. With this increase of sand, the gas spikes to 14.43u. Oil showing increased towards the end of the interval. Sandstone (7170’ - 7240’) = dusky yellow brownish to olive gray with occasion moderate to light brown color; quartz dominant; lower to upper very fine grains size; very well to well sorting; dirty silty matrix; calcareous cement; angular to sub-angular angularity; very low sphericity; easily friable to firm friable hardness; mottling to thin structure; no free oil; moderate oil odor in sample; no oil odor near shaker; light straw color in visual cut; bright milky white fluorescence cut color; brownish orange fluorescence visual; no other oil indictors; high HCl reaction in bulk sample. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 7157 14.483 4566.727 260.601 114.159 0 0 0 0 3.2.12 A1 7173’ to 7249’ MD (-6047’ to -6102’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 209.88 26.73 118.305 13.38 2.35 7.895 A1 interval has 80-40% sand/sandstone, 10-30% siltstone, and 10% shale (carbonaceous shale). Gas is base at 3u with a spike at 13u at 7239’ MD. Oil showing are moderate with bright milky white fluorescent cuts and odor in samples. 3H-11A 21 Sandstone (7170’ - 7240’) = dusky yellow brownish to olive gray with occasion moderate to light brown color; quartz dominant; lower to upper very fine grains size; very well to well sorting; dirty silty matrix; calcareous cement; angular to sub-angular angularity; very low sphericity; easily friable to firm friable hardness; mottling to thin structure; no free oil; moderate oil odor in sample; no oil odor near shaker; light straw color in visual cut; bright milky white fluorescence cut color; brownish orange fluorescence visual; no other oil indictors; high HCl reaction in bulk sample. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 7238 13.385 3075.442 202.446 101.223 0 0 0 0 3.2.13 Base of Kuparuk 7250’ MD (-6103’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 107.71 107.71 107.71 5.91 5.91 5.91 The Base of the Kuparuk is 10% carbonaceous shale, 20% siltstone, and 70% sandstone/sandstone. Gas is 6.32u with moderate oil showing. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 7301 6.326 1471.477 102.267 59.572 0 0 0 0 3H-11A 22 3.3 Connection Gases Minimal Connection Gases ranging from 5-10 Units were observed during the drilling of the Tabasco Sand Interval and the Kuparuk Sand Interval. Connection Gasses ranging from 5-15 Units were also observed after Coring starting at the bottom of the Tabasco Sand and continued until the Wiper Trip at 5663’. 3.4 Trip (Wiper) Gases 1unit = 0.05% Methane Equivalent Depth (feet) Trip to (feet) Gas (units) Downtime (hours) 4238’ MD 0’ Trip Out 35 16.5 5663’ MD 2701’ Window 49 12 6968’ MD 2701’ Window 664 18 6968’ MD 0’ Running Csg 275 18 3H-11A 23 3.5 Sampling Program / Sample Dispatch Samples were collected for logging purposes and one set was saved wet throughout the Tabasco Sand interval from 3700’ to 4240’. The wet samples were boxed up and stored in the refrigerator for the duration of the well. A mud sample as well as a mud additive sample were bottled and stored with the cuttings samples. This was the only section of samples that we were required to keep per the Well-site Geologist Barry Wright. Wet sample set was released to Barry Wright on 9/26/2012 at TD of intermediate section. Well-site Geologist will send Samples to: Callie Armstrong Project Coordinator Geochemical Services Group 143 Vision Park Blvd. Shenandoah, TX 77384 A Caliper Tool as well as a Rotary Coring Assembly was run into open hole on a wire-line for coring the Tabasco Sand Interval. Due to swelling clays in the bore hole and very soft expansive formation only 6 cores were recovered out of the 23 attempted, but those that were recovered were packaged and frozen for Geochemical Analysis in the lab at a later date. 3H-11A 24 3.6 Show Reports 3H-11A Ratio Plot #1 Sept. 21, 2012 Depths 3820' to 3970' 1 10 100 1000 10000 1234 DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 3H-11A 25 3H-11A Ratio Plot #2 Oct 3, 2012 Depths 7080' to 7350' 1 10 100 1000 10000 1234 DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 3H - 1 1 A 26 4 P R E S S U R E / F O R M A T I O N S T R E N G T H D A T A 4. 1 P o r e P r e s s u r e E v a l u a t i o n Fo r m a t i o n In t e r v a l Pr i m a r y Li t h o l o g y (% ) Se c o n d a r y Li t h o l o g y (% ) In t e r v a l T o p s P o r e P r e s s u r e ( M W ) Trend Indicators MD (f t ) TV D S S (f t ) Mi n (p p g ) Ma x (p p g ) Tr e n d Ki c k O f f P o i n t C l y s t 7 0 % Sd 2 0 % , S l t s t 10 % 27 0 1 ’ - 2 3 3 2 ’ 9 . 5 9 . 6 5 U p B G , C G , E C D Ta b a s c o C l y s t 6 0 % Sd 2 5 % , S l t s t 10 % , A s h 5 % 37 7 5 ’ - 3 2 6 8 ’ 9 . 6 5 9 . 5 5 D o w n B G , C G , E C D C- 3 5 C l y s t 6 0 % Sl t s t 3 0 % , S d 10 % 52 2 5 ’ - 4 5 1 4 ’ 9 . 5 5 1 0 . 0 U p B G , C G , E C D C- 3 0 C l y s t 6 0 % Sl t s t 3 5 % , S d 5% 63 1 4 ’ - 5 4 3 9 ’ 1 0 . 0 1 0 . 1 E v e n B G , C G , E C D HR Z S l t s t 7 0 % Sd 2 0 % , C l y s t 10 % 65 0 2 ’ - 5 5 7 4 ’ 1 0 . 1 1 0 . 0 D o w n B G , C G , E C D K- 1 M a r k e r S l t s t 7 0 % S h 3 0 % 6 8 9 1 ’ - 5 8 4 7 ’ 1 0 . 0 1 0 . 0 E v e n B G , C G , E C D Ku p a r u k S s t / S d 6 0 % Sl t s t 2 0 % , S h 20 % 70 0 5 ’ - 5 9 3 0 ’ 1 0 . 5 1 0 . 5 E v e n B G , C G , E C D Th e w e l l w a s d r i l l e d s l i g h t l y o v e r b a l a n c e d a s w a s i n d i c a t e d b y v e r y m i n i m a l c o n n e c t i o n g a s s e s , l o w t r i p , l o w w i p e r g a s s e s a s w e ll as mi n i m a l l o s s e s t o t h e f o r m a t i o n d u r i n g d r i l l i n g . NO T E : C l y s t = C l a y s t o n e / C l a y , S d = S a n d , S l t s t = S i l t s t o n e , S h = S h a l e , S s t = S a n d s t o n e , A s h = A s h F a l l T u f f , C S l t s t = Ca r b o n a c e o u s S i l t s t o n e 4. 2 Q u a n t i t a t i v e M e t h o d s Th e p r i m a r y i n d i c a t o r s u s e d f o r P P G e v a l u a t i o n w e r e g a s t r e n d s r e la t i v e t o m u d w e i g h t ( M W ) a n d e f f e c t i v e c i r c u l a t i n g d e n s i t y ( E CD), in c l u d i n g i n c r e a s e s i n b a c k g r o u n d g a s ( B G ) , a p p e a r a n c e a n d t r e n d s o f c o n n e c t i o n g a s ( C G ) , a n d m a g n i t u d e s o f t r i p g a s ( T G ) a n d wi p e r g a s ( W G ) . R e g i o n a l p o r e p r e s s u r e t r e n d s f r o m s o n i c d a t a , p r o v i d e d b y C o n o c o P h i l l i p s , a n d s u r f a c e m a n i f e s t a t i o n s o f h o l e co n d i t i o n s w e r e a l s o c o n s i d e r e d . 3H - 1 1 A 27 As a r e f e r e n c e , P P G i s c a l c u l a t e d i n i t i a l l y w i t h a f o r m u l a p r o v i d e d b y C a n r i g D r i l l i n g T e c hn o l o g y L T D , a n d t h e n m o d i f i e d u s i n g the in d i c a t o r s d e s c r i b e d a b o v e , D X C a n d r e s i s t i v i t y ( R E S ) d a t a . T h e f o rm u l a u s e s D X , E C D , a n d B G a s m e a s u r e d b y t o t a l d i t c h g a s : PP G = E C D – ( 0 . 6 - ( ( . 0 0 1 * T L G S U ) + ( 0 . 0 5 * D X ) ) ) Th e f o r m u l a h a s c e r t a i n l i m i t a t i o n s , s u c h t h a t i t d o e s n o t a l l o w f o r a P P G m o r e t h a n 1 p p g l e s s t h a n t h e E C D , a n d T L G S U m u s t b e di f f e r e n t i a t e d f r o m s h o w g a s a n d g a s c a r r i e d f r o m o v e r p r e s s u r e z o n e s , a n d i s d e p e n d e n t o n r e l i a b l e D X d a t a . H o w e v e r , t h e f o r m ula pr o v e d u s e f u l i n h e l p i n g f o r m u l a t e a P P G r a n g e , w h e n e s t i m a t i n g t r e n d s , a s w i t h D X C d a t a , w i t h d a t a p o i n t s i n s h a l e i n t e r v a l s . 3H-11A 28 5 DRILLING DATA 5.1 Survey Data Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (o/100ft) 2701.00 41.44 96.67 2400.82 -110.3 1037.52 1016.34 TIE-IN 2773.32 42.96 93.30 2454.31 -114.49 1085.82 1063.77 3.78 2818.69 42.35 89.28 2487.77 -115.19 1116.62 1094.26 6.14 2868.39 41.70 84.93 2524.70 -113.52 1149.84 1127.43 6.00 2916.17 39.78 86.02 2560.90 -111.05 1180.92 1158.58 4.29 2962.34 39.31 83.88 2596.50 -108.47 1210.20 1187.96 3.12 3085.36 34.96 83.54 2673.03 -102.13 1276.80 1245.91 4.54 3153.39 31.60 84.20 2752.47 -96.55 1319.64 1298.04 3.56 3247.67 29.38 81.30 2833.71 -90.55 1367.08 1345.86 2.82 3342.08 28.08 74.82 2916.54 -82.47 1411.27 1390.70 3.57 3438.49 27.11 71.95 3001.98 -69.72 1454.06 1438.73 1.71 3533.60 27.59 70.98 3086.46 -55.83 1495.49 1477.54 0.69 3628.08 27.13 70.10 3170.37 -41.36 1536.43 1519.93 0.65 3721.84 28.25 69.21 3253.39 -26.21 1577.28 1562.32 1.27 3816.98 29.56 70.57 3336.68 -10.41 1620.46 1607.11 1.54 3911.96 28.83 70.51 3419.59 5.02 1664.14 1652.35 0.77 4102.09 27.98 70.78 3586.78 35.08 1749.54 1740.78 0.52 4196.46 27.36 69.91 3670.36 49.82 1790.81 1783.54 0.78 4291.75 26.92 69.93 3755.16 64.74 1831.64 1825.88 0.46 4386.39 27.26 68.84 3839.42 79.92 1871.98 1867.76 0.64 4481.32 26.93 67.85 3923.93 95.87 1912.16 1909.59 0.59 4576.19 27.68 68.32 4008.23 112.11 1952.54 1951.64 0.82 4670.61 27.43 69.28 4091.94 127.91 1993.26 1993.99 0.54 4765.63 26.88 69.03 4176.48 143.34 2033.79 2036.09 0.59 4860.55 28.33 70.46 4260.60 158.55 2075.05 2078.91 1.68 4955.55 28.02 70.15 4344.34 173.67 2117.28 2122.66 0.36 5050.44 27.87 69.63 4428.17 188.95 2159.04 2165.97 0.30 5144.93 27.53 68.98 4511.81 204.48 2200.15 2208.67 0.45 5239.82 27.25 69.73 4596.05 219.89 2241.03 2251.12 0.50 5335.73 26.84 69.52 4681.47 235.07 2281.91 2293.55 0.44 5430.16 27.98 69.85 4765.30 250.16 2322.68 2335.85 1.22 5525.51 27.67 69.67 4849.62 265.56 2364.44 2379.18 0.34 5619.13 27.30 69.16 4932.68 280.75 2404.89 2421.17 0.47 5713.65 29.34 64.82 5015.89 298.31 2446.11 2464.23 3.07 5808.27 30.09 64.54 5098.06 318.37 2488.50 2508.76 0.81 5902.68 31.26 58.90 5179.28 341.21 2530.86 2553.58 3.29 5997.49 33.21 55.32 5259.48 368.69 2573.28 2599.03 2.88 6092.70 36.30 50.98 5337.71 401.28 2616.64 2646.04 4.16 6186.94 39.51 45.49 5412.08 439.88 2659.71 2693.49 4.94 3H-11A 29 6283.03 41.49 38.49 5485.18 486.25 2701.34 2740.47 5.16 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (o/100ft) 6329.34 41.85 36.23 5519.77 510.72 2720.02 2761.99 3.34 6376.86 43.22 36.10 5554.79 536.66 2738.98 2783.97 2.89 6472.63 46.08 36.70 5622.91 590.82 2778.92 2830.21 3.02 6567.53 45.24 35.88 5689.24 645.53 2819.10 2876.75 1.08 6662.40 44.52 35.31 5756.46 699.96 2858.06 2922.06 0.87 6757.65 44.84 36.11 5824.19 754.34 2897.15 2967.49 0.68 6852.04 45.79 36.75 5890.57 808.33 2937.01 3013.63 1.12 6921.01 45.79 36.34 5938.66 848.05 2966.45 3047.69 0.43 6977.78 45.56 36.39 5978.68 879.97 2990.77 3075.72 0.41 7071.86 44.98 36.23 6044.89 933.83 3030.35 3121.56 0.63 7165.15 46.18 36.54 6110.18 987.47 3069.87 3167.33 1.31 7261.13 45.31 36.52 6177.16 1042.70 3110.79 3214.68 0.91 7336.91 44.39 36.42 6230.89 1085.68 3142.56 3251.45 1.22 P 7375.00 44.39 36.42 6258.00 1107.12 3158.38 3269.76 0.00 3H - 1 1 A 30 5. 2 B i t R e c o r d Bi t S i z e M a k e T y p e / S # J e t s / T F A De p t h I n MD / To t a l Fo o t a g e Bi t Hr s Av g . RO P (f t / h r ) WO B (K l b s ) RP M W e a r B H A 1 8 . 7 5 ” B a k e r HC D 6 0 5 Z / 71 3 4 2 5 9 4x 1 3 , 3x 1 2 / 0. 8 4 9 8 27 3 2 ’ 1 5 0 9 ’ 1 8 . 7 1 6 0 . 8 9 . 4 1 0 3 . 2 4 - 2 - B T - N - X - 1 - W T - C P 1 2 8 . 7 5 ” B a k e r DP 6 0 6 X / 71 4 1 7 5 3 4x 1 4 , 2x 1 3 42 3 8 ’ 2 7 3 0 ’ 2 7 . 9 1 2 9 . 2 1 1 . 6 1 2 2 . 5 1 - 1 - W T - A - X - 1 - N O - T D 2 3 6 . 1 2 5 ” H D B S FX 5 5 / 11 1 7 7 9 6 7 3x 1 3 , 0. 3 8 8 9 69 6 8 ’ 4 0 7 ’ 6 . 5 1 1 0 . 6 6 . 5 8 9 . 9 1 - 1 - N O - A - X - 1 - N O - T D 3 3H - 1 1 A 31 5. 3 M u d R e c o r d Co n t r a c t o r : M I S W A C O Da t e D e p t h MW (p p g ) EC D (p p g ) VI S (s / q t ) PV Y P G e l s FL (c c ) FC So l s (% ) O/ W Ra t i o Sd (% ) pH Cl (ml/l) Ca (ml/l) 9/ 1 9 / 1 2 3 3 0 0 ’ 9 . 6 N R 4 0 8 1 8 6 / 9 / 1 1 6 . 4 1 / 5 2 / 9 3 T R 8 . 9 1 5 0 0 1 2 0 9/ 1 9 / 1 2 3 6 7 0 ’ 9 . 5 N R 4 5 1 2 2 1 8 / 1 0 / 1 2 5 . 8 1 / 5 2 / 9 3 T R 9 . 1 2 0 0 0 1 3 0 9/ 2 0 / 1 2 4 2 3 9 ’ 9 . 5 N R 4 9 1 4 2 8 1 0 / 1 7 / 2 3 4 . 9 1 / 6 2 / 9 2 T R 9 . 4 2 1 0 0 1 4 0 9/ 2 1 / 1 2 4 2 3 9 ’ 9 . 5 N R 5 2 1 7 2 8 9 / 1 3 / 1 5 4 . 4 1 / 6 2 / 9 2 T R 9 . 1 2 5 0 0 1 5 0 9/ 2 2 / 1 2 4 2 3 9 ’ 9 . 5 N R 5 2 1 7 2 8 1 0 / 1 7 / 2 3 4 . 4 1 / 6 2 / 9 2 T R 9 . 1 2 5 0 0 1 5 0 9/ 2 3 / 1 2 5 4 7 8 ’ 9 . 7 N R 6 0 2 0 3 4 1 4 / 2 0 / 2 6 3 . 8 1 / 7 3 / 9 0 T R 9 . 2 4 8 0 0 1 6 0 9/ 2 4 / 1 2 5 6 7 0 ’ 9 . 8 N R 9 2 2 3 3 9 1 6 / 2 5 / 2 9 3 . 1 1 / 8 4 / 8 8 T R 9 . 3 4 4 0 0 1 2 0 9/ 2 5 / 1 2 6 8 0 3 ’ 1 0 . 0 N R 5 6 2 0 2 8 1 2 / 1 8 / 2 4 3 . 2 1 / 8 4 / 8 8 T R 9 . 1 4 0 0 0 1 2 0 9/ 2 6 / 1 2 6 9 6 8 ’ 1 0 . 0 N R 5 3 2 3 2 4 1 0 / 1 4 / 1 6 3 . 2 1 / 1 0 4 / 8 6 T R 9 . 2 4 0 0 0 1 2 0 9/ 2 7 / 1 2 6 9 6 8 ’ 1 0 . 0 N R 5 7 1 3 2 2 8 / 1 0 / 1 3 3 . 1 1 / 8 4 / 8 8 T R 9 . 1 4 2 0 0 1 2 0 9/ 2 8 / 1 2 6 9 6 8 ’ 1 0 . 0 N R 6 3 1 5 2 8 1 0 / 1 2 / 1 4 3 . 1 1 / 8 4 / 8 8 T R 9 . 2 4 2 0 0 1 2 0 9/ 2 9 / 1 2 6 9 6 8 ’ 1 0 . 0 N R 5 9 1 5 2 0 7 / 1 0 / 1 2 3 1 / 8 4 / 8 8 T R 9 . 3 4 2 0 0 1 2 0 9/ 3 0 / 1 2 6 9 6 8 ’ 1 0 . 0 N R 5 7 1 7 2 1 9 / 1 1 / 1 3 3 . 0 5 1 / 1 8 4 / 8 8 T R 9 . 0 4 0 0 0 1 2 0 10 / 1 / 1 2 6 9 6 8 ’ 1 0 . 0 N R 5 9 1 6 2 2 8 / 9 / 1 3 0 . 0 1 / 8 4 / 8 8 T R 9 . 0 4 1 0 0 1 2 0 10 / 2 / 1 2 7 1 0 5 1 0 . 5 N R 5 4 1 8 2 2 7 / 8 / 9 0 . 0 1 / 1 0 3 / 8 7 - 9 . 5 3 6 0 0 1 2 0 5. 4 A b b r e v i a t i o n s MW = M u d W e i g h t G e l s = G e l S t r e n g t h S d = S a n d c o n t e n t E C D = E f f e c t i v e C i r c u l a t i n g D e n s i t y WL = W a t e r o r F i l t r a t e L o s s C l = C h l o r i d e s V I S = F u n n e l V i s c o s i t y F C = F i l t e r C a k e Ca = H a r d n e s s C a l c i u m P V = P l a s t i c V i s c o s i t y S o l s = S o l i d s O / W = O i l t o W a t e r r a t i o YP = Y i e l d P o i n t N C = N o t R e p o r t e d 32 6 DAILY REPORTS ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Dale Rowell Date: 9-3-12 Time: 12:00am Current Depth (MD): Current Depth (TVD): Current Operations: Decomplete 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cl -: Ca ++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Calibrations: none Failures: None Daily Cost:$3075.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Dale Rowell Date: 9-4-12 Time: 12:00am Current Depth (MD): Current Depth (TVD): Current Operations: Decomplete 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cl -: Ca ++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Calibrations: None Failures: None Daily Cost:$2775.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Dale Rowell Date: 9-5-12 Time: 12:00am Current Depth (MD): Current Depth (TVD): Current Operations: Decomplete 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cl -: Ca ++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Calibrations: THA Failures: None Daily Cost:$5275.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Dale Rowell Date: 9-6-12 Time: 12:00am Current Depth (MD): Current Depth (TVD): Current Operations: Continue to milling. 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cl -: Ca ++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Calibrations: THA Failures: None Daily Cost:$2910.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Dale Rowell Date: 9-7-12 Time: 12:00am Current Depth (MD): Current Depth (TVD): Current Operations: Continue to milling. 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cl -: Ca ++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Milling and washing hole. Calibrations: THA Failures: None Daily Cost:$2910.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Dale Rowell Date: 9-8-12 Time: 12:00am Current Depth (MD): Current Depth (TVD): Current Operations: Continue to milling. 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cl -: Ca ++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Milling Calibrations: THA Failures: None Daily Cost:$2960.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Dale Rowell Date: 9-9-12 Time: 12:00am Current Depth (MD): Current Depth (TVD): Current Operations: Continue to milling. 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cl -: Ca ++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Milling and washing hole. Calibrations: THA Failures: None Daily Cost:$3060.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Dale Rowell Date: 9-10- 12 Time: 12:00am Current Depth (MD): Current Depth (TVD): Current Operations: POOH 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cl -: Ca ++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: POOH Calibrations: THA Failures: None Daily Cost:$3160.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Dale Rowell Date: 9-11- 12 Time: 12:00am Current Depth (MD): W/O Current Depth (TVD): Current Operations: Standby 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cl -: Ca ++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Calibrations: THA Failures: None Daily Cost:$2960.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Dale Rowell Date: 9-12- 12 Time: 12:00am Current Depth (MD): Current Depth (TVD): Current Operations: Standby 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cl -: Ca ++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Calibrations: THA Failures: None Daily Cost:$1990.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Dale Rowell Date: 9-13- 12 Time: 12:00am Current Depth (MD): Current Depth (TVD): Current Operations: Standby 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cl -: Ca ++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Calibrations: THA Failures: None Daily Cost:$1990.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Dale Rowell Date: 9-14- 12 Time: 12:00am Current Depth (MD): Current Depth (TVD): Current Operations: Standby 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cl -: Ca ++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Calibrations: THA Failures: None Daily Cost:$1990.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Dale Rowell Date: 9-15- 12 Time: 12:00am Current Depth (MD): W/O Current Depth (TVD): Current Operations: Standby 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cl -: Ca ++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Calibrations: THA Failures: None Daily Cost:$1990.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Dale Rowell Date: 9-16- 12 Time: 12:00am Current Depth (MD): W/O Current Depth (TVD): Current Operations: Standby 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cl -: Ca ++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Calibrations: THA Failures: None Daily Cost:$1990.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Dale Rowell Date: 9-17- 12 Time: 12:00am Current Depth (MD): W/O Current Depth (TVD): Current Operations: Set Whipstock 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cl -: Ca ++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Set whipstock and mill window. Calibrations: THA Failures: None Daily Cost:$1990.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Brandon Boehme/Randy Dolcater Date: 9-18- 12 Time: 12:00am Current Depth (MD): 2732’ Current Depth (TVD): N/A Current Operations: Drilling Ahead 24 hr Footage (MD): N/A Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cl -: Ca ++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Cleaning hole and preparing the drill ahead in the Tabasco Sands. Calibrations: THA Failures: None Daily Cost:$2960.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Brandon Boehme/Randy Dolcater Date: 9-19- 12 Time: 12:00am Current Depth (MD): 3960’ Current Depth (TVD): 2732’ Current Operations: Drilling Ahead 24 hr Footage (MD): 1228’ Drilling Parameters ROP: Current: 0 Max: 3019 Torque: Current: N/A Max: N/A WOB: Current 72 Max: 15000 RPM: Current: 0 Max: PP: Current: 0 Max: 1510 Lag: Strokes: N/A Time: N/A Surf-Surf: Strokes: N/A Time: N/A ECD: Current: Max: Mud Properties @ MW: 9.5 FV: 45 PV: 12 YP: 21 FL: 5.8 Gels: 8/10/12 Sol: 5 pH: 9.1 Cl -: 2000 Ca ++: 130 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 2u 90u 3850 MD Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases 2959 MD C1 C2 C3 C4I C4N C5I C5N None 879.238 0 0 0 0 0 0 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 2 2900 MD 2 587.00 0 0 0 0 0 0 3 3000 MD 4.939 1242.00 0 0 0 0 0 0 7 3200 MD 4.021 944.00 0 0 0 0 0 0 18 3808.00 27.603 6631.96 85.860 0 0 0 0 0 Lithologies: Current: Dominant clay with interbedding sands. Last 24 hrs: N/A Operational Summary: Install Wear ring. Make up and Pick up Drilling BHA #1. Run in hole to 87’ and then download LWD Tool. Continue to RIH from 87’ to 637’ MD. Conduct shallow pulse test on BHA #1. Test is good. Continue to run in hole to 2630’. Circulate 10 barrels per minute at 870 psi. Continue to run in hole to 2730’ with pumps off. Drill ahead from 2730’ to 3007’. Drill ahead from 3007’ to 3130’. Drill ahead to 3900’. Calibrations: THA Failures: None Daily Cost:$3160.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Brandon Boehme/Randy Dolcater Date: 9-20- 12 Time: 12:00am Current Depth (MD): 4240’ Current Depth (TVD): 3960’’ Current Operations: E-Line and E-Logging 24 hr Footage (MD): 280’ Drilling Parameters ROP: Current: 0 Max: 281 Torque: Current: 0 Max: 3800 WOB: Current 0 Max: 29 RPM: Current: N/A Max: N/A PP: Current: 0 Max: 1706 Lag: Strokes: N/A Time: N/A Surf-Surf: Strokes: N/A Time: N/A ECD: Current: Max: Mud Properties @ MW: 9.5 FV: 49 PV: 14 YP: 28 FL: 4.9 Gels: 10/17/23 Sol: 6 pH: 9.4 Cl -: 2100 Ca ++: 140 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 0u 4u 3960’ Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases 3973’ MD C1 C2 C3 C4I C4N C5I C5N None 723.129 2.193 0 0 0 0 0 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 22 3992’ MD 3.041 893.750 0.093 0 0 0 0 0 23 4048’ MD 2.019 547.57 0 0 0 0 0 0 24 4147’ MD 2.0 689.73 0 0 0 0 0 0 25 4185’ MD 2.0 448.409 0 0 0 0 0 0 Lithologies: Current: N/A Last 24 hrs: Dominant clay with interbedding sands. Operational Summary: Can't to drill ahead from 3900 ft through Tabasco formation to 4238. CBU and condition OH section for logging purposes. Spot new 9.6 ppg LSND down DP at 10 bpm. Circulate surface to surface +10 bbls. Monitor well. POOH with BHA #1 from 4238 to 738 ft. Monitor well. Can't POOH, stand back BHA. Load HES tools. RU E-line. RIH w/ HES 6 arm caliper and sit down at 2684 ft. POOH, reconfigure tool string, RIH and set down at 2681 ft. POOH, found clay on tools. Change tools to coring tools @ 22:45 hrs, RIH. Attempts failed. Calibrations: THA Failures: None Daily Cost:$3335.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Brandon Boehme/Randy Dolcater Date: 9-21- 12 Time: 12:00am Current Depth (MD): 4240’ Current Depth (TVD): 4240’’ Current Operations: RIH with coring tools 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: 9.5 FV: 52 PV: 17 YP: 28 FL: 4.4 Gels: 9/13/15 Sol: 6 pH: 9.1 Cl -: 2500 Ca ++: 150 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: N/A Last 24 hrs: N/A Operational Summary: Set back E-Line and pull dutch riser. MU RIH w/ BHA #25 to 4238 ft. Circulate 12 bpm at 1140 psi. A lot of clay and cuttings over shakers between 1-2 bottoms up. Cleaned up after 2# bottoms up. POOH to 2750 ft. RIH w/ pumps off to 2849 ft, no indication of trouble area. Pump out of hole 2688 to 2650 ft at 12 bpm. Circulate 3X bottoms up. Clean returns. POOH w/ BHA #25. RU E-Line. RIH w/ Caliper logging tool, set down at 2714 ft. POOH remove centralizer. RIH to 4240 ft, log back to window at 2701 ft. POOH. RIH w/ coring tools and begin operations. Calibrations: THA Failures: None Daily Cost:$3335.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Brandon Boehme/Randy Dolcater Date: 9-22- 12 Time: 12:00am Current Depth (MD): 4240’ Current Depth (TVD): 4240’’ Current Operations: RIH to 4240’ 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: 9.5 FV: 52 PV: 17 YP: 28 FL: 4.4 Gels: 10/17/23 Sol: 6 pH: 9.1 Cl -: 2500 Ca ++: 150 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: N/A Last 24 hrs: N/A Operational Summary: Drill selective core logs in Tabasco interval. Core 3 wouldn't go in chamber. POOH. Recover core from 3849'. RIH w/ mechanical sidewall coring tool. Core stuck in tube, POOH. RD primary toolstring, RU and test backup string. RIH and attempt recovery. Lost oil pressure in tool. POOH. RD e-line and dutch riser. PU Drilling BHA #26. RIH to 633', conduct shallow pulse test. Continue RIH to 2627'. Continue RIH to 4146'. Continue to RIH to 4239'. Calibrations: THA Failures: None Daily Cost:$3335.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Brandon Boehme/Randy Dolcater Date: 9-23- 12 Time: 12:00am Current Depth (MD): 5662’ Current Depth (TVD): 4240’ Current Operations: Drill to 5663’ MD. 24 hr Footage (MD): 1422’ Drilling Parameters ROP: Current: 0 Max: 393 Torque: Current: 0 Max: 2600 WOB: Current 16.7 Max: 31 RPM: Current: 0 Max: 111 PP: Current: 1783 Max: 2670 Lag: Strokes: N/A Time: N/A Surf-Surf: Strokes: N/A Time: N/A ECD: Current: N/A Max: N/A Mud Properties @ MW: 9.5 FV: 52 PV: 17 YP: 28 FL: 4.4 Gels: 10/17/23 Sol: 6 pH: 9.1 Cl -: 2500 Ca ++: 150 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 0 37 5611’ MD Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases 15u C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 72 5290’ 20.472 4195.000 207.000 31.000 0 0 0 0 73 5310.’ 19.875 4108.000 207.000 36.000 0 0 0 0 74 5330’ 26.644 5575.000 254.000 48.000 0 0 0 0 75 5420’ 27.985 5724.000 307.940 78.550 0 0 0 0 Lithologies: Current: 70% Claystone, 10% Tuff, 10% Siltstone. Last 24 hrs: N/A Operational Summary: Continue to RIH 4146' to 4235'. Continue to drill ahead sliding and rotating as per DD from 4238' to 5239'. Continue drilling to 5377', circulate BU. SPR's at 5285' with 9.6ppg. Continue drilling to 5471'. Drill ahead to 5663'. Calibrations: THA Failures: None Daily Cost:$3335.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Brandon Boehme/Randy Dolcater Date: 9-24- 12 Time: 12:00am Current Depth (MD): 5842’ Current Depth (TVD): Current Operations: Drilling Ahead. 24 hr Footage (MD): 179’ Drilling Parameters ROP: Current: 0 Max: 347.9 Torque: Current: 0 Max: 0 WOB: Current 13 Max: 14 RPM: Current: 0 Max: 0 PP: Current: 1802 Max: 2670 Lag: Strokes: N/A Time: N/A Surf-Surf: Strokes: N/A Time: N/A ECD: Current: N/A Max: N/A Mud Properties @ MW: 9.8 FV: 92 PV: 23 YP: 39 FL: 3.1 Gels: 16/25/29 Sol: 8 pH: 9.3 Cl -: 4400 Ca ++: 120 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 13 20 5663’ MD Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases None C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 85 5680’ 15 3026.070 156.790 54.530 0 0 0 0 88 5825’ 11 2556.666 131.480 45.960 0 0 0 0 89 5840’ 5 1181.660 72.870 28.960 0 0 0 0 Lithologies: Current: 10% Tuff, 20% Siltstone, 80% Claystone. Last 24 hrs: 70% Claystone, 10% Tuff, 10% Siltstone. Operational Summary: Continue to RIH 4146' to 4235'. Continue to drill ahead sliding and rotating as per DD from 4238' to 5239'. Continue drilling to 5377' MD, circulate BU. SPR's at 5285' with 9.6ppg. Continue drilling to 5471'. Drill ahead to 5663'. Calibrations: THA Failures: None Daily Cost:$3335.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Brandon Boehme/Randy Dolcater Date: 9-25- 12 Time: 12:00am Current Depth (MD): 6970’ Current Depth (TVD): Current Operations: Drilling Ahead. 24 hr Footage (MD): 1128’ Drilling Parameters ROP: Current: 0 Max: 448.6 Torque: Current: 0 Max: N/A WOB: Current 0 Max: 26 RPM: Current: 0 Max: N/A PP: Current: 1753 Max: 3189 Lag: Strokes: N/A Time: N/A Surf-Surf: Strokes: N/A Time: N/A ECD: Current: N/A Max: N/A Mud Properties @ MW: 10 FV: 56 PV: 20 YP: 28 FL: 3.2 Gels: 12/18/24 Sol: 8 pH: 9.1 Cl -: 4000 Ca ++: 120 MW Change: Depth: 5670’ From: 6803’ To: 10 Reason: Add 0.5 ever 1500 ft. Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 13 20 5663’ MD Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases None C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 114 6690’ 64 11582 624.928 235.706 29.966 64.504 94.470 0 115 6720’ 40 7711.666 322.306 115.061 9.192 35.444 44.636 116 6770’ 65 12759.804 547.023 183.000 21.890 44.255 66.144 Lithologies: Current: 20% carbonaceous Shale, 80% Siltstone. Last 24 hrs: 10% Tuff, 20% Siltstone, 80% Claystone. Operational Summary: Continue to slide at 5855' to 5890'. Continue to slide and rotating per DD. At 6163' sliding at 45 degree. At 6297' sliding at -45 deg. At 6398 sliding at 0 deg. At 6603' rotating. Slide from 6705' to 6732'. Continue rotating per DD. Continue drilling to 6896'. Calibrations: THA Failures: None Daily Cost:$3335.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Brandon Boehme/Randy Dolcater Date: 9-26- 12 Time: 12:00am Current Depth (MD): 6970’ Current Depth (TVD): Current Operations: POOH. 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: 10 FV: 53 PV: 23 YP: 24 FL: 0 Gels: 10/14/16 Sol: 10 pH: 9.2 Cl -: 4000 Ca ++: 120 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases None C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: 20% carbonaceous Shale, 80% Siltstone. Operational Summary: Drilling ahead from 6895' MD at 12.5 BPM. TD called at 6965'. Back ream up to two stands, RIH to 6965' and shoot survey while circulating at 204 SPM 2355 SPP. Circulate hole clean at 12 BPM while rotating at 50 rpm, 2330 SPP, while reciprocating DP slowly. CBU 4X racking back one stand after each BU. POOH from 6600'. Standing back DP & maintaining proper hole full while POOH Calibrations: THA Failures: None Daily Cost:$3335.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Brandon Boehme/Randy Dolcater Date: 9-27- 12 Time: 12:00am Current Depth (MD): 6970’ Current Depth (TVD): Current Operations: Rig down test equipment. 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: 10 FV: 57 PV: 13 YP: 22 FL: 0 Gels: 8/10/13 Sol: 8 pH: 28 Cl -: 4200 Ca ++: 0 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases None C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: TOOH. Orient up thru window. No problem pulling thru window. Continue TOOH; performing Torque & Drag every 10 stands. Stand back HWDP & Collars. Load Storm Packer. Drain & Clean Stack. Pull Wear Ring. RU Storm Packer Assembly. Test packer. Set Test Plug. Test BOPE w/7". Rig down Test Equipment. Calibrations: THA Failures: None Daily Cost:$3335.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Brandon Boehme/Randy Dolcater Date: 9-28- 12 Time: 12:00am Current Depth (MD): 6970’ Current Depth (TVD): Current Operations: Continue to RIH with 7” casing. 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: 10 FV: 63 PV: 15 YP: 28 FL: 0 Gels: 10/12/14 Sol: 8 pH: 9.2 Cl -: 4200 Ca ++: 120 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases None C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: MU Pulling Assembly to retrieve Storm Packer. Latch & release Storm Packer & pull to rig floor. Continue POOH laying down Drill Collars & HWDP. Change out handling equipment to run 7" CSC. MU Shoetrack with Bakerlock and RIH 7" CSC to 2611'. Circulate @ 6 BPM. Continue to RIH W/7" Casing. Calibrations: THA Failures: None Daily Cost:$3335.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Brandon Boehme/Randy Dolcater Date: 9-29- 12 Time: 12:00am Current Depth (MD): 6970’ Current Depth (TVD): Current Operations: Waiting cement to dry. 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: 10 FV: 59 PV: 15 YP: 20 FL: 3 Gels: 7/10/12 Sol: 8 pH: 9.3@96 Cl -: 4200 Ca ++: 120 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas 273u Connection Gases None C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Circulate 7" CSC to bottom for space of cementing head. Reach TD w/7" casing completion. Swap out bails for cement head. Install cement head. Circulate hole & thin mud properties to condition mud. Begin cementing operation. Rig down cementers. Wait on cement. Calibrations: THA Failures: None Daily Cost:$3335.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Brandon Boehme/Randy Dolcater Date: 9-30- 12 Time: 12:00am Current Depth (MD): 6970’ Current Depth (TVD): Current Operations: RU circulating equipment & perform “LOT for Freeze Protection Annulus”. 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: 10 FV: 57 PV: 17 YP: 21 FL: 3.05 Gels: 911/13 Sol: 8 pH: 9.0@88 Cl -: 4000 Ca ++: 120 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases None C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: NU BOPE. Lower rams from 7" to VBR's & RU riser. Perform SIS NOV derrick inspection. Load Tubing. Perform bi-weekly BOP Test. Test VBR's & annular with 3 12", 4" & 4 1/2" Test Joints. Performed draw down test. RD testing equipment & pull Test Plug. RU circulating equipment & perform “LOT for Freeze Protection Annulus”. Calibrations: THA Failures: None Daily Cost:$3335.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Brandon Boehme/Randy Dolcater Date: 10-1- 12 Time: 12:00am Current Depth (MD): 6970’ Current Depth (TVD): Current Operations: Perform casing integrity test. Drill cement inside 7" casing. 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: 10 FV: 59 PV: 16 YP: 22 FL: 3.1 Gels: 8/9/13 Sol: 8 pH: 9 Cl -: 120 Ca ++: 0 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases None C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: RU Circulate equipment & pump 200 BBL fresh water after pumping 4 BBL of 10 ppg Mud for LOT Test. Pump Freeze Protect, 100 BBL diesel down to 2000' with LRS. Install wear ring. MU 6 1/8" drilling assembly, unload LWD, shallow pulse test-good. Load nuke sources, BDTD, continue MU BHA. RIH to 3885'. Wash down @ 2.5 BPM @ 600 psi. Tag cement @ 3955'. Drill thru and tag plug @ 3983'.Drill cement & wash 4070'. RIH to 6730'. Wash down to cement Tag @ 6767'. Perform casing integrity test. Drill cement inside 7" casing. Calibrations: THA Failures: None Daily Cost:$3335.00 ConocoPhillips Alaska Inc. 3H-11A Daily Report Report for: Brandon Boehme/Randy Dolcater Date: 10-2- 12 Time: 12:00am Current Depth (MD): 6970’ Current Depth (TVD): Current Operations: Clean out Hole. 24 hr Footage (MD): 407 Drilling Parameters ROP: Current: 0 Max: 393 Torque: Current: 190 Max: 6402 WOB: Current 0 Max: 83 RPM: Current: 0 Max: 102 PP: Current: 1335 Max: 2892 Lag: Strokes: 0 Time: 0 Surf-Surf: Strokes: 0 Time: 0 ECD: Current: Max: Mud Properties @ MW: 10 FV: 54 PV: 18 YP: 22 FL: 2.9 Gels: 7/8/9 Sol: 10 pH: 9.5@94 Cl -: 3600 Ca ++: 120 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 0 24 6968’ MD Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas 0 Connection Gases 6u C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 130 7030 3 838.834 46.043 20.676 131 7110 4 1078.592 56.743 24.943 132 7132 3 1507.404 86.690 33.132 133 7184 3 813.320 46.340 23.013 Lithologies: Current: 40% Carbonaceous Shale, 10% Sandstone, 50% Siltstone. Last 24 hrs: Operational Summary: Continue jarring operation to free stuck drilling assembly. Freed after 22 jar hits up & 6 jar hits down. CBU. Perform derrick inspection after jarring. RIH to casing shoe & continue to drill out into formation 20'. Drilled town to 6985'. 10 ppg drilling fluid contaminated. CBU. PU above shoe and monitor well while conditioning mud to 10.5 PPG. Conduct FIT/ LOT w.10.5 ppg fluid in hole. EMW 16.1 ppg. RIH to 6950' & set drilling parameter @ 81 SPM @ 1325 SPP, rotating @ 51 Rpm, Free Rotating 125k, 4-5k WOB. Drilling ahead Calibrations: THA Failures: None Daily Cost:$3335.00
