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211-151
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable b direct inspection of the file. 4 4 - 1 Si Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RES N: OVERSIZED: NOTES: Col r Items: ❑ Maps' rayscale Items: ogs: R iii A-1-.10A) ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: ASO Date: • /s/ Project Proofing BY: MOD Date: 4111 ` Is/ u , Scanning Preparation 3 x 30 = gO + 9 = TOTAL PAGES g 7. (Count does not include cover sheet BY: Maria Date: 9' � /s/ )� Production Scanning Stage 1 Page Count from Scanned File: /c20 (Count does include cover'sheet) Page Count Matches Number in Scanning Preparation: V YES NO BY: dep Date: �q, Is! oqp 1 Stage 1 If NO in stage 1, page(s)discrepancies w re found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: NO TOTAL PAGES:3( r� Digital version appended by: Meredith 6Michal it \k Date: Is! Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: 1 340 Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc 9 C cT) C) o j +bb N O 0 . O_ 0 } 9 N o J U U Q' LL •V N o CO▪ Z 0 O O o .0 Jo J cs C W W W~ C O m O O T _• U N a) y, E C O 0 O '- T 0 W C C m 0 CLL a) O-IL N a)I c 0 g U m O C7 w O a)u_ CCOLL o `m E E W U E c rn a a LL N a) a) �+ o U w o o aa>i g E _1 (i 0 n3 fi (i C7 O D >O a U U f°4_1 a o a Z = o U 2 2 2 F- 2 0 2 ~ Li g et 0 0 m w et FI: U) C J WU` rLJ �0 a_co 0 Q Too v O N N N N N N N N N N N N N N N N N 0 o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 J N h O N N N N N N N N N N N N N N N N N CD a. (D CO CO CO CD (O CD CO CO CO N N N N N N M U 2 Q J N N N N N N N N N N N N N N N N CV Z E N N N N N N 2 cc C C C C C C cc C C C C O U) U) Iii C = = a a a a a a a 0. a a a a a a (No co (Na Q x OU 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 -Jce • C co 2 co a O O O O O O O O O O O M 0 CO CO V 0 (,) d CO o V V V V V VV V . V a0 V O O f� .. O) 0) O 0) O O) O O O) i 0) v (D 0) o co 0 a. 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O cn • = N d d Z Z 0 ano, ., a w� 2 Z li 0 V 1 W o Z9 d d N U 0H Z • �' d Ce o Q s oc j Cl)NO J � ' co a 0) o E M o N p 0 N O E m II Q N w 0. 0 I— H o N — z N o j cC /y� C• \) d W a' C > 0 a) -t a o U) Q d 0 Y g Q o. EcoI E 01-1 z c d s I '- N j2 c v o ° co 0 'a Z E o p E O T 7 cDO Q0 m rn N C 2 d N re 3 a) N E Ea a) � ce E 0 O N z a 0- w :12 Z ! l9 a_ O 0 p N p E U ~ U 0 >,..,,,,u E E 0 0 0 >a) a a 2 w 3 a > 0 < 0 1 U WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 4, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT): 1E-24B Run Date: 9/29/2012 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 1E-24B Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-20857-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND 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: \ \2 Signed: I v'�(J'(��,�n. 2A\-151 ZVSq°I DATA LOGGED WELL LOG TRANSMITTAL t of tozo .M K BENDER To: Alaska Oil and Gas Conservation Comm. September 27, 2013 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 4,4 : rv ` RE: Gas Lift Survey: 1E-24B Run Date: 9/20/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook,Halliburton Wireline&Perforating, 6900 Arctic Blvd.,Anchorage,AK 99518 matthew.cook@halliburton.com 1E-24B Digital Data in LAS format,Digital Log Image file 1 CD Rom 50-029-20857-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: \oleo 1%3 Signed: �.� Zt1- t WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 3, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting and Perforating Records: 1E-24B Run Date: 12/13/2011 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 1E-24B Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20857-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND 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: 4lic, l Signed: YWA l ae.14 2-L1-i5\ X300 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 30, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log: 1E-24B Run Date: 1/29/2012 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 1E-24B Data in LAS format, Digital Log Image files 1 CD Rom 50-029-20857-02 Cement Bond Log 1 Color Log 50-029-20857-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND 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: 4(1/%1 Signed: Nkt14:11 6-ea1�( RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 3 0 7ill? WELL COMPLETION OR RECOMPLETION RFs� E .Ic,& Sidh la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned❑ Suspended ❑✓ lb.We C;... ,e 20AAC 25.105 20AAC 25.110 Development 111 Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska,Inc. orAband.: December 31,2011 211-151 / 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 December 16,2011 50-029-20857-02 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 171'FSL,226'FEL,Sec. 16,T11N,R10E, UM December 26,2011 1E-24B Top of Productive Horizon: 8.KB(ft above MSL): 94'RKB 15.Field/Pool(s): 1430'FNL,477'FWL,Sec.22,T11N,R10E,UM GL(ft above MSL): 66.7'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 1535'FNL,458'FWL,Sec.22,T11N,R10E, UM 6839'MD/6326'ND Kuparuk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-550301 y- 5959761 Zone-4 6940'MD/6411'TVD ADL 25651 TPI: x-551018 y- 5958164 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit Total Depth: x-551000 y- 5958059 Zone-4 1785'MD/1785'ND 469 18.Directional Survey: Yes ❑✓ No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MDrI VD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1465'MD/1465'ND 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res 4913'MD/4630'ND 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" 65# H-40 35' 112' 35' 112' 24" 326 sx AS II 10.75" 45.5# K-55 33' 2398' 33' 2398' 13.5" 1400 sx AS III,250 sx AS I 7" 26# K-55 32' 7395' 32' 6095' 8.75" 700 sx Class G,250 sx I 5.5" 15.5# L-80 4679' 6458' 4430' 6007' 7" 179 sx Class G 3.5" 9.3# L-80 6263' 6937' 5844' 6409' 4.75" 72 sx Class G 24.Open to production or injection? Yes ❑ No Q 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" 6274' 6263'MD/5844'ND L ,.. .Jik_; not perforated `'') 16. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED ROTARY SET-UP FOR COILED TUBING DRILLING or tleiiii a 1 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) not ready for production Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period-> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. psi 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑✓ Sidewall Cores Acquired? Yes ❑ No ❑✓ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE R8®MS JAN 312011Q (" Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only 28. GEOLOGIC MARKERS(List all formations and r, s encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes ❑✓ No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1465' 1465' needed,and submit detailed test information per 20 AAC 25.071. Kuparuk A 6739' 6241' N/A Formation at total depth: Kuparuk A 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Nugent @ 263-4228 Printed Name /� G.Alvord Title: Alaska Drilling Manager Signature /�_C em Phone 263-4021 Date I(Z1/Z-912-- INSTRUCTIONS Z-9fLINSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23:If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 KUP 1E-24B v.-- v ConocoPhillips ° Well Attributes Max Angle&MD TO Alaska,Inc • Wellbore APl/UWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ftKB) Conrx,,,,,,ps 500292085702 KUPARUK RIVER UNIT PROD 37.04 3,894.82 Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date "' SSSV:TRDP 90 9/15/2010 Last WO: 32.30 12/13/1982 Well Conficr-1E-24B 11520122 50.02 PM Schemaf-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:RKB 5,307.0 12/3/2011 Rev Reason:ADD SIDETRACK ninam 1/5/2012 HANGER.23- Casing Strings Casing Description (String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD).. String Wt...String... String Top Thrd ,1ltttr 5.5 LINER 5 1/2 4.950 4,679.2 6,458.0 6,006.5 15.50 L-80 HYD563 Liner Details Top Depth (ND) Top not Nomi... Top(RKB) (RKB) (°) Rem Description Comment ID(in) 4,679.2 4,433.5 31.99 TIEBACK TIW X-PACK TIE BACK EXPANDER 4.940 4,683.4 4,437.0 32.01 HANGER TIW X-PACK LINER HANGER 4.875 4,688.8 4,441.7 32.03 NIPPLE TIW SPACE NIPPLE 4.906 I - 4,693.4 4,445.6 32.05 NIPPLE TIW SPACE NIPPLE 4.906 Casing Description String 0... String ID...Top(ftKB) Set Depth(/...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR, 3.5 LINER 3 1/2 2.992 6,262.8 6,937.0 6,408.8 9.20 L-80 HYD511 35-112 Liner Details Top Depth I (TVD) Top Incl Noml... 1 Top(RKB) (RKB) (°) Item Description Comment ID(in) SAFETY VLV, o I 6,262.8 5,844.1 32.72 PACKER BAKER HR ZXP LINER TOP PACKER 3.000 1.705 6,288.5 5,865.5 33.22 HANGER BAKER FLEX LOCK LINER HANGER 2.980 Tubing Strings SURFACE, Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd 33-2'39e TUBING 31/2 2.992 22.6 6,274.0 5,853.5 9.30 L-80 EUE8rdABMOD Ell Completion Details GAS LIFT, 2,504 Top Depth _ (ND) Top IndNoel. Top(ftKB) (RKB) (°) Rem Description Comment ID(in) 22.6 22.6 -0.03 HANGER FMC TUBING HANGER 3.500 1,785.2 1,785.1 0.72 SAFETY VLV SCHLUMBERGER TRMAXX-CMT-5SR SAFETY VALVE 2.813 6,215.0 5,803.7 31.80 NIPPLE -CAMCO XNIPPLE 2.813 GAS_11-0 6,257.5 5,839.7 32.62 LOCATOR BAKER LOCATING COLLAR 2.970 370 6258.0 5,840.1 32.63 SEAL ASSY SEAL ASSEMBLY FOR BOT 80-40 SEAL BORE EXTENSION HALF 3.010 MUILE SHOE r GAS LIFT, 4,772 • WHIPSTOCK -. 4,913T, CEMENT, 4,080NT. 8. GAS LIFT, 5,449 GAS LIFT, 8,001il : NIPPLE.6.215 I SEAL ASSY, )-. 8,258 .5.5 67LINER,58 �' 3.5 LINER, 3.S LINER, D(I E-248). TD(1 E-7.395 6.940 .8 t/C ^ PRODUCTION, x �y Je%J\//L//'//�/�/,f 32-7.395 ' all IIIII . 5j 1 lilt al a P 1 tri �1 1 IMO Mandrel Details Top Depth 1 Top Port (ND) IndOD Valve Latch Size TRO Run Stn Top(RKB) (ftKB) 1°) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 2,504.1 2,504.0 0.99 CAMCO KBG-2-9 1 GAS LIFT DMY DK-1 0.000 0.0 12/29/2011 2 3,709.3 3,638.6 31.73 CAMCO KBG-2-9 1 GAS LIFT DMY DK-1 0.000 0.0 12/29/2011 U, 3`L 3 4,772.1 4,512.1 32.71 CAMCO KBG-2-9 1 GAS LIFT DMY DK-1 0.000 0.0 12/29/2011 1 4 5,448.9 5,092.9:19.50 CAMCO KBG-2-9 1 GAS LIFT DMY DK-1 0.000 0.0 12129/2011 ��y5 6,001.0 5,615.3 25.40 CAMCO KBG-2-9 1 GAS LIFT SOV DCK-3 0.000 0.0 12/29/2011 l< ,mm it 1 1 z 6 i l'11 1 51 ConocoPhillips(Alaska) Inc. Kuparuk River Unit IN t k;,, Kuparuk 1E Pad 11 1E-24B I I g 61 Sperry Drilling Definitive Survey Report 1 03 January, 2012 E ill f Eo 4 Ii F 14 r 5 441 , yr .4.i Et, :4 [ , [.,, limmumm HALLIBURTON .moi Sperry Drilling =` ConocoPhillips(Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 1 E-24 Project: Kuparuk River Unit TVD Reference: 1E-24B @ 93.80ft(D141(26.8+67)) Site: Kuparuk 1 E Pad MD Reference: 1E-24B @ 93.80ft(D141(26.8+67)) Well: 1 E-24 North Reference: True Wellbore: 1 E-24B Survey Calculation Method: Minimum Curvature Design: 1E-24B 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 1 E-24 Well Position +NI-S 0.00 ft Northing: 5,959,760.73 ft Latitude: 70°18'2.999 N +E/-W 0.00 ft Easting: 550,300.55 ft Longitude: 149°35'33.373 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 67.00 ft Wellbore 1E-24B Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 12/7/2011 20.85 80.92 57,638 Design 1E-24B Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 4,894.80 Vertical Section: Depth From(TVD) +NI-S +E/-W Direction (ft) (ft) (ft) r) 26.80 0.00 0.00 144.06 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 69.80 4,894.80 1E-24 Gyro(1E-24) GYD-CT-CMS Gyrodata cont.casing m/s 3/28/2011 12:00 4,913.00 5,864.75 1E-24B MWD R200(1E-24B) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/17/2011 12:0 5,960.94 6,429.99 1E-24B MWD R400(1E-24B) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/19/2011 12:01 6,480.45 6,907.84 1E-24B MWD R500(1E-24B) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/25/2011 12:0 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 26.80 0.00 0.00 26.80 -67.00 0.00 0.00 5,959,760.73 550,300.55 0.00 0.00 UNDEFINED 69.80 0.35 198.71 69.80 -24.00 -0.12 -0.04 5,959,760.61 550,300.51 0.81 0.08 GYD-CT-CMS(1) 94.80 0.12 35524 94.80 1.00 -0.17 -0.07 5,959,760.56 550,300.48 1.85 0.10 GYD-CT-CMS(1) 119.80 0.15 149.31 119.80 26.00 -0.17 -0.05 5,959,760.56 550,300.50 1.05 0.11 GYD-CT-CMS(1) 144.80 0.50 111.15 144.80 51.00 -0.24 0.06 5,959,760.49 550,300.62 1.57 0.23 GYD-CT-CMS(1) 169.80 0.43 103.75 169.80 76.00 -0.30 0.26 5,959,760.43 550,300.81 0.37 0.40 GYD-CT-CMS(1) 194.80 0.66 97.89 194.80 101.00 -0.34 0.49 5,959,760.39 550,301.04 0.95 0.57 GYD-CT-CMS(1) 219.80 0.76 83.87 219.80 126.00 -0.35 0.80 5,959,760.39 550,301.35 0.80 0.75 GYD-CT-CMS(1) 244.80 0.77 94.95 244.79 150.99 -0.34 1.13 5,959,760.39 550,301.68 0.59 0.94 GYD-CT-CMS(1) 269.80 0.53 119.62 269.79 175.99 -0.41 1.40 5,959,760.33 550,301.95 1.45 1.16 GYD-CT-CMS(1) 294.80 0.38 102.89 294.79 200.99 -0.49 1.58 5,959,760.25 550,302.13 0.80 1.32 GYD-CT-CMS(1) 1/3/2012 10:51:57AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips(Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 1E-24 Project: Kuparuk River Unit TVD Reference: 1E-24B @ 93.80ft(D141(26.8+67)) Site: Kuparuk 1 E Pad MD Reference: 1 E-24B @ 93.80ft(D141(26.8+67)) Well: 1E-24 North Reference: True Wellbore: 1E-248 Survey Calculation Method: Minimum Curvature Design: 1E-248 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (°) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 319.80 0.74 85.35 319.79 225.99 -0.50 1.82 5,959,760.25 550,302.37 1.58 1.47 GYD-CT-CMS(1) 344.80 0.52 102.49 344.79 250.99 -0.51 2.09 5,959,760.24 550,302.65 1.15 1.64 GYD-CT-CMS(1) 369.80 0.44 58.81 369.79 275.99 -0.48 2.29 5,959,760.26 550,302.84 1.46 1.73 GYD-CT-CMS(1) 394.80 0.41 61.51 394.79 300.99 -0.39 2.45 5,959,760.36 550,303.00 0.14 1.75 GYD-CT-CMS(1) 419.80 0.33 71.94 419.79 325.99 -0.32 2.59 5,959,760.42 550,303.15 0.42 1.78 GYD-CT-CMS(1) 444.80 0.25 39,28 444.79 350.99 -0.26 2.70 5,959,760.49 550,303.25 0.72 1.79 GYD-CT-CMS(1) 469.80 0.29 102.06 469.79 375.99 -0.23 2.79 5,959,760.52 550,303.34 1.13 1.83 GYD-CT-CMS(1) 494.80 0.47 62.98 494.79 400.99 -0.20 2.95 5,959,760.55 550,303.50 1.22 1.89 GYD-CT-CMS(1) 519.80 0.25 12.78 519.78 425.98 -0.10 3.05 5,959,760.65 550,303.60 1.46 1.87 GYD-CT-CMS(1) 544.80 0.23 94.24 544.78 450.98 -0.05 3.11 5,959,760.70 550,303.66 1.25 1.87 GYD-CT-CMS(1) 569.80 0.20 123.93 569.78 475.98 -0.08 3.20 5,959,760.68 550,303.75 0.46 1.94 GYD-CT-CMS(1) 594.80 0.33 119.06 594.78 500.98 -0.14 3.30 5,959,760.62 550,303.85 0.53 2.05 GYD-CT-CMS(1) 619.80 0.14 50.14 619.78 525.98 -0.15 3.38 5,959,760.60 550,303.93 1.23 2.11 GYD-CT-CMS(1) 644.80 0.15 51.74 644.78 550.98 -0.11 3.43 5,959,760.64 550,303.98 0.04 2.10 GYD-CT-CMS(1) 669.80 0.23 0.35 669.78 575.98 -0.04 3.46 5,959,760.71 550,304.01 0.72 2.06 GYD-CT-CMS(1) 694.80 0.22 327.46 694.78 600.98 0.05 3.43 5,959,760.80 550,303.98 0.51 1.97 GYD-CT-CMS(1) 719.80 0.22 133.38 719.78 625.98 0.06 3.44 5,959,760.81 550,303.99 1.75 1.97 GYD-CT-CMS(1) 744.80 0.28 174.19 744.78 650.98 -0.04 3.48 5,959,760.72 550,304.03 0.73 2.07 GYD-CT-CMS(1) 769.80 0.08 246.28 769.78 675.98 -0.10 3.47 5,959,760.65 550,304.02 1.07 2.12 GYD-CT-CMS(1) 794.80 0.03 192.03 794.78 700.98 -0.12 3.46 5,959,760.64 550,304.01 0.27 2.12 GYD-CT-CMS(1) 819.80 0.25 11.59 819.78 725.98 -0.07 3.47 5,959,760.68 550,304.02 1.12 2.09 GYD-CT-CMS(1) 844.80 0.06 207.84 844.78 750.98 -0.03 3.47 5,959,760.72 550,304.02 1.23 2.06 GYD-CT-CMS(1) 869.80 0.32 67.39 869.78 775.98 -0.01 3.53 5,959,760.74 550,304.08 1,47 2.08 GYD-CT-CMS(1) 894.80 0.11 150.50 894.78 800.98 -0.01 3.61 5,959,760.75 550,304.15 1.30 2.12 GYD-CT-CMS(1) 919.80 0.20 93.99 919.78 825.98 -0.03 3.66 5,959,760.72 550,304.21 0.67 2.17 GYD-CT-CMS(1) 944.80 0.31 66.51 944.78 850.98 -0.01 3.77 5,959,760.75 550,304.32 0.65 2.22 GYD-CT-CMS(1) 969.80 0.04 308.23 969,78 875.98 0.02 3.82 5,959,760.78 550,304.37 1.32 2.22 GYD-CT-CMS(1) 994.80 0.36 134.98 994.78 900.98 -0.03 3.87 5,959,760.73 550,304.42 1.60 2.29 GYD-CT-CMS(1) 1,019.80 0.11 182.27 1,019.78 925.98 -0.10 3.92 5,959,760.65 550,304.47 1.19 2.39 GY0-CT-CMS(1) 1,044.80 0.21 268.70 1,044.78 950.98 -0.13 3.88 5,959,760.63 550,304.43 0.92 2.38 GYD-CT-CMS(1) 1,069.80 0.24 215.48 1,069.78 975.98 -0.17 3.80 5,959,760.58 550,304.35 0.81 2.37 GYD-CT-CMS(1) 1,094.80 0,16 198.84 1,094.78 1,000.98 -0.25 3.76 5,959,760.51 550,304.31 0.39 2,41 GYD-CT-CMS(1) 1,119.80 0.38 218.18 1,119.78 1,025.98 -0.35 3.70 5,959,760.41 550,304.25 0.94 2.45 GYD-CT-CMS(1) 1,144.80 0.42 185.93 1,144.78 1,050.98 -0.50 3.64 5,959,760.25 550,304.19 0.90 2.54 GYD-CT-CMS(1) 1,169.80 0.11 153.57 1,169.78 1,075.98 -0.62 3.64 5,959,760.14 550,304.19 1.33 2.63 GYD-CT-CMS(1) 1,194.80 0.07 217.69 1,194.78 1,100.98 -0.65 3.64 5,959,760.10 550,304.19 0.41 2.66 GYD-CT-CMS(1) 1,219.80 0.35 174.77 1,219.78 1,125.98 -0.74 3.64 5,959,760.02 550,304.19 1.21 2.73 GYD-CT-CMS(1) 1,244.80 0.07 199.21 1,244.78 1,150.98 -0.83 3.64 5,959,759.93 550,304.19 1.15 2.81 GYD-CT-CMS(1) 1,269.80 0.32 189.69 1,269.78 1,175.98 -0.91 3.62 5,959,759.84 550,304.18 1.00 2.86 GYD-CT-CMS(1) 1,294.80 0.28 185.47 1,294.78 1,200.98 -1.04 3.60 5,959,759.71 550,304.16 0.18 2.96 GYD-CT-CMS(1) 1/3/2012 10:51:57AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 1E-24 Project: Kuparuk River Unit TVD Reference: 1 E-24B @ 93.80ft(D141(26.8+67)) Site: Kuparuk 1E Pad MD Reference: 1 E-24B @ 93.80ft(D141(26.8+67)) Well: 1E-24 North Reference: True Wellbore: 1E-24B Survey Calculation Method: Minimum Curvature Design: 1E-24B Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0/100') (ft) Survey Tool Name 1,319.80 0.13 231.08 1,319.78 1,225.98 -1.12 3.58 5,959,759.63 550,304.13 0.84 3.01 GYD-CT-CMS(1) 1,344.80 0.36 172.93 1,344.78 1,250.98 -1.22 3.56 5,959,759.54 550,304.12 1.25 3.08 GYD-CT-CMS(1) 1,369.80 0.47 202.26 1,369.78 1,275.98 -1.39 3.54 5,959,759.37 550,304.09 0.94 3.20 GYD-CT-CMS(1) 1,394.80 0.22 178.74 1,394.78 1,300.98 -1.53 3.50 5,959,759.22 550,304.06 1.13 3.29 GYD-CT-CMS(1) 1,419.80 0.54 174.14 1,419.78 1,325.98 -1.70 3.51 5,959,759.06 550,304.07 1.28 3.43 GYD-CT-CMS(1) 1,444.80 0.49 201.41 1,444.78 1,350.98 -1.91 3.48 5,959,758.84 550,304.05 0.99 3.59 GYD-CT-CMS(1) 1,469.80 0.13 160.32 1,469.78 1,375.98 -2.04 3.45 5,959,758.71 550,304.02 1.60 3.68 GYD-CT-CMS(1) 1,494.80 0.27 155.49 1,494.78 1,400.98 -2.12 3.49 5,959,758.63 550,304.05 0.56 3.76 GYD-CT-CMS(1) 1,519.80 0.60 168.48 1,519.78 1,425.98 -2.30 3.54 5,959,758.45 550,304.10 1.37 3.94 GYD-CT-CMS(1) 1,544.80 0.51 94.61 1,544.77 1,450.97 -2.44 3.68 5,959,758.32 550,304.24 2.68 4.13 GYD-CT-CMS(1) 1,569.80 0.08 19.45 1,569.77 1,475.97 -2.43 3.79 5,959,758.32 550,304.36 1.98 4.19 GYD-CT-CMS(1) 1,594.80 0.47 259.54 1,594.77 1,500.97 -2.43 3.70 5,959,758.32 550,304.26 2.06 4.14 GYD-CT-CMS(1) 1,619.80 0.42 158.74 1,619.77 1,525.97 -2.54 3.63 5,959,758.22 550,304.20 2.75 4.18 GYD-CT-CMS(1) 1,644.80 0.29 118.56 1,644.77 1,550.97 -2.65 3.72 5,959,758.10 550,304.29 1.09 4.33 GYD-CT-CMS(1) 1,669.80 0.51 211.39 1,669.77 1,575.97 -2.78 3.72 5,959,757.98 550,304.28 2.40 4.43 GYD-CT-CMS(1) 1,694.80 0.82 248.68 1,694.77 1,600.97 -2.94 3.49 5,959,757.82 550,304.06 2.07 4.43 GYD-CT-CMS(1) 1,719.80 0.53 336.99 1,719.77 1,625.97 -2.90 3.28 5,959,757.86 550,303.85 3.85 4.27 GYD-CT-CMS(1) 1,744.80 0.81 61.04 1,744.77 1,650.97 -2.70 3.39 5,959,758.05 550,303.96 3.68 4.18 GYD-CT-CMS(1) 1,769.80 0.58 137.34 1,769.77 1,675.97 -2.71 3.63 5,959,758.04 550,304.20 3.51 4.33 GYD-CT-CMS(1) 1,794.80 0.67 239.65 1,794.77 1,700.97 -2.88 3.59 5,959,757.88 550,304.16 3.90 4.44 GYD-CT-CMS(1) 1,819.80 0.54 338.95 1,819.77 1,725.97 -2.84 3.42 5,959,757.91 550,303.99 3.70 4.31 GYD-CT-CMS(1) 1,844.80 0.56 99.30 1,844.76 1,750.96 -2.75 3.50 5,959,758.00 550,304.07 3.82 4.28 GYD-CT-CMS(1) 1,869.80 0.50 162.62 1,869.76 1,775.96 -2.88 3.65 5,959,757.88 550,304.22 2.23 4.47 GYD-CT-CMS(1) 1,894.80 0.80 283.93 1,894.76 1,800.96 -2.94 3.52 5,959,757.82 550,304.08 4.57 4.44 GYD-CT-CMS(1) 1,919.80 0.82 343.35 1,919.76 1,825.96 -2.73 3.29 5,959,758.03 550,303.86 3.21 4.14 GYD-CT-CMS(1) 1,944.80 0.54 80.96 1,944.76 1,850.96 -2.54 3.36 5,959,758.22 550,303.93 4.16 4.02 GYD-CT-CMS(1) 1,969.80 0.37 174.40 1,969.76 1,875.96 -2.60 3.48 5,959,758.16 550,304.05 2.69 4.15 GYD-CT-CMS(1) 1,994.80 0.31 243.84 1,994.76 1,900.96 -2.71 3.43 5,959,758.05 550,304.00 1.56 4.21 GYD-CT-CMS(1) 2,019.80 0.53 198.70 2,019.76 1,925.96 -2.85 3.33 5,959,757.91 550,303.90 1.52 4.26 GYD-CT-CMS(1) ' 2,044.80 0.50 128.34 2,044.76 1,950.96 -3.02 3.38 5,959,757.73 550,303.95 2.38 4.43 GYD-CT-CMS(1) 2,069.80 0.09 315.32 2,069.76 1,975.96 -3.08 3.45 5,959,757.68 550,304.02 2.36 4.52 GYD-CT-CMS(1) 2,094.80 0.49 180.19 2,094.76 2,000.96 -3.17 3.44 5,959,757.58 550,304.01 2.23 4.59 GYD-CT-CMS(1) 2,119.80 0.54 138.60 2,119.76 2,025.96 -3.37 3.52 5,959,757.39 550,304.09 1.47 4.79 GYD-CT-CMS(1) 2,144.80 0.22 133.58 2,144.76 2,050.96 -3.49 3.63 5,959,757.27 550,304.20 1.29 4.95 GYD-CT-CMS(1) 2,169.80 0.57 198.32 2,169.75 2,075.95 -3.64 3.63 5,959,757.12 550,304.20 2.06 5.07 GYD-CT-CMS(1) 2,194.80 0.45 122.81 2,194.75 2,100.95 -3.81 3.67 5,959,756.95 550,304.24 2.53 5.24 GYD-CT-CMS(1) 2,219.80 0.86 156.14 2,219.75 2,125.95 -4.03 3.83 5,959,756.72 550,304.40 2.17 5.51 GYD-CT-CMS(1) 2,244.80 0.34 167.33 2,244.75 2,150.95 -4.28 3.92 5,959,756.48 550,304.50 2.12 5.76 GYD-CT-CMS(1) 2,269.80 0.40 101.76 2,269.75 2,175.95 -4.37 4.02 5,959,756.39 550,304.60 1.62 5.90 GYD-CT-CMS(1) 2,294.80 0.68 146.22 2,294.75 2,200.95 -4.51 4.19 5,959,756.25 550,304.77 1.94 6.11 GYD-CT-CMS(1) 1/3/2012 10:51:57AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 1E-24 Project: Kuparuk River Unit TVD Reference: 1E-24B @ 93.80ft(D141(26.8+67)) Site: Kuparuk 1E Pad MD Reference: 1E-24B @ 93.80ft(D141(26.8+67)) Well: 1E-24 North Reference: True Wellbore: 1E-24B Survey Calculation Method: Minimum Curvature Design: 1E-249 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (1 (ft) (ft) (ft) (ft) (ft) (ft) (°I100') (ft) Survey Tool Name 2,319.80 0.11 191.31 2,319.75 2,225.95 -4.66 4.27 5,959,756.10 550,304.85 2.43 6.27 GYD-CT-CMS(1) 2,344.80 0.65 81.42 2,344.75 2,250.95 -4.66 4.40 5,959,756.10 550,304.98 2.78 6.36 GYD-CT-CMS(1) 2,369.80 0.66 103.15 2,369.75 2,275.95 -4.67 4.68 5,959,756.09 550,305.26 0.99 6.53 GYD-CT-CMS(1) 2,394.80 0.95 123.83 2,394.74 2,300.94 -4.82 4.99 5,959,755.95 550,305.58 1.62 6.83 GYD-CT-CMS(1) 2,419.80 1.49 86.44 2,419.74 2,325.94 -4.91 5.49 5,959,755.85 550,306.07 3.74 7.20 GYD-CT-CMS(1) 2,444.80 0.83 108.16 2,444.73 2,350.93 -4.95 5.99 5,959,755.82 550,306.57 3.13 7.52 GYD-CT-CMS(1) 2,469.80 1.33 107.55 2,469.73 2,375.93 -5.09 6.44 5,959,755.68 550,307.02 2.00 7.90 GYD-CT-CMS(1) 2,494.80 1.04 88.88 2,494.72 2,400.92 -5.18 6.94 5,959,755.60 550,307.52 1.92 8.27 GYD-CT-CMS(1) 2,519.80 0.91 118.78 2,519.72 2,425.92 -5.27 7.34 5,959,755.51 550,307.93 2.07 8.57 GYD-CT-CMS(1) 2,544.80 1.84 94.45 2,544.71 2,450.91 -5.40 7.92 5,959,755.39 550,308.50 4.31 9.01 GYD-CT-CMS(1) 2,569.80 1.24 111.68 2,569.70 2,475.90 -5.53 8.57 5,959,755.26 550,309.15 3.01 9.50 GYD-CT-CMS(1) 2,594.80 2.52 114.43 2,594.69 2,500.89 -5.85 9.32 5,959,754.94 550,309.91 5.13 10.21 GYD-CT-CMS(1) 2,619.80 4.12 113.92 2,619.65 2,525.85 -6.44 10.64 5,959,754.36 550,311.23 6.40 11.46 GYD-CT-CMS(1) 2,644.80 5.96 118.44 2,644.55 2,550.75 -7.43 12.60 5,959,753.39 550,313.20 7.52 13.41 GYD-CT-CMS(1) 2,669.80 6.92 123.97 2,669.39 2,575.59 -8.89 14.99 5,959,751.94 550,315.60 4.57 15.99 GYD-CT-CMS(1) 2,694.80 8.20 126.64 2,694.17 2,600.37 -10.79 17.67 5,959,750.06 550,318.29 5.31 19.11 GYD-CT-CMS(1) 2,719.80 9.36 129.27 2,718.88 2,625.08 -13.14 20.68 5,959,747.73 550,321.31 4.91 22.78 GYD-CT-CMS(1) 2,744.80 10.66 126.90 2,743.50 2,649.70 -15.82 24.10 5,959,745.07 550,324.75 5.45 26.95 GYD-CT-CMS(1) 2,769.80 12.12 128.92 2,768.01 2,674.21 -18.86 27.99 5,959,742.06 550,328.66 6.05 31.70 GYD-CT-CMS(1) 2,794.80 13.57 129.48 2,792.38 2,698.58 -22.37 32.30 5,959,738.58 550,332.99 5.82 37.07 GYD-CT-CMS(1) 2,819.80 14.17 130.13 2,816.65 2,722.85 -26.21 36.90 5,959,734.77 550,337.62 2.48 42.88 GYD-CT-CMS(1) 2,844.80 14.95 132.46 2,840.85 2,747.05 -30.36 41.62 5,959,730.66 550,342.37 3.90 49.01 GYD-CT-CMS(1) 2,869.80 15.81 133.63 2,864.95 2,771.15 -34.88 46.46 5,959,726.16 550,347.24 3.66 55.51 GYD-CT-CMS(1) 2,894.80 17.13 138.02 2,888.93 2,795.13 -39.97 51.39 5,959,721.11 550,352.20 7.25 62.52 GYD-CT-CMS(1) 2,919.80 17.65 135.59 2,912.79 2,818.99 -45.41 56.51 5,959,715.70 550,357.35 3.57 69.93 GYD-CT-CMS(1) 2,944.80 17.86 136.99 2,936.59 2,842.79 -50.93 61.77 5,959,710.22 550,362.66 1.90 77.49 GYD-CT-CMS(1) 2,969.80 18.24 137.95 2,960.36 2,866.56 -56.63 67.01 5,959,704.55 550,367.93 1.93 85.18 GYD-CT-CMS(1) 2,994.80 18.96 136.10 2,984.06 2,890.26 -62.47 72.45 5,959,698.76 550,373.41 3.72 93.10 GYD-CT-CMS(1) 3,019.80 18.84 139.33 3,007.71 2,913.91 -68.45 77.89 5,959,692.81 550,378.89 4.21 101.14 GYD-CT-CMS(1) 3,044.80 19.53 136.83 3,031.32 2,937.52 -74.56 83.38 5,959,686.73 550,384.42 4.29 109.31 GYD-CT-CMS(1) • 3,069.80 19.63 139.34 3,054.88 2,961.08 -80.80 88.98 5,959,680.54 550,390.06 3.39 117.64 GYD-CT-CMS(1) 3,094.80 20.38 138.35 3,078.37 2,984.57 -87.24 94.61 5,959,674.14 550,395.73 3.29 126.16 GYD-CT-CMS(1) 3,119.80 19.99 139.84 3,101.83 3,008.03 -93.75 100.26 5,959,667.66 550,401.42 2.58 134.75 GYD-CT-CMS(1) 3,144.80 21.26 140.15 3,125.23 3,031.43 -100.50 105.92 5,959,660.95 550,407.13 5.10 143.53 GYD-CT-CMS(1) 3,169.80 19.86 139.91 3,148.64 3,054.84 -10723 111.56 5,959,654.26 550,412.81 5.61 152.29 GYD-CT-CMS(1) 3,194.80 20.55 140.86 3,172.10 3,078.30 -113.88 117.06 5,959,647.65 550,418.36 3.06 160.91 GYD-CT-CMS(1) 3,219.80 20.18 141.41 3,195.54 3,101.74 -120.65 122.52 5,959,640.91 550,423.86 1.67 169.60 GYD-CT-CMS(1) 3,244.80 20.78 143.89 3,218.96 3,125.16 -127.61 127.82 5,959,633.99 550,429.21 4.22 178.34 GYD-CT-CMS(1) 3,269.80 20.51 140.41 3,242.35 3,148.55 -134.57 133.23 5,959,627.07 550,434.66 5.02 187.15 GYD-CT-CMS(1) 3,294.80 21.46 144.20 3,265.70 3,171.90 -141.65 138.69 5,959,820.03 550,440.18 6.63 196.09 GYD-CT-CMS(1) 1/3/2012 10:51:57AM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 1E-24 Project: Kuparuk River Unit TVD Reference: 1 E-24B©93.80ft(D141(26.8+67)) Site: Kuparuk 1E Pad MD Reference: 1E-24B©93.80ft(D141(26.8+67)) Well: 1E-24 North Reference: True Wellbore: 1E-24B Survey Calculation Method: Minimum Curvature Design: 1E-24B Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) 0100') (ft) Survey Tool Name 3,319.80 21.31 143.33 3,288.97 3,195.17 -149.00 144.08 5,959,612.71 550,445.61 1.40 205.21 GYD-CT-CMS(1) 3,344.80 21.73 144.94 3,312.23 3,218.43 -156.44 149.45 5,959,605.31 550,451.03 2.90 214.37 GYD-CT-CMS(1) 3,369.80 22.17 142.95 3,335.42 3,241.62 -163.99 154.95 5,959,597.80 550,456.58 3.46 223.72 GYD-CT-CMS(1) 3,394.80 22.10 146.06 3,358.58 3,264.78 -171.65 160.42 5,959,590.17 550,462.10 4.70 233.13 GYD-CT-CMS(1) 3,419.80 22.98 144.72 3,381.67 3,287.87 -179.54 165.87 5,959,582.32 550,467.60 4.08 242.71 GYD-CT-CMS(1) 3,444.80 23.78 144.26 3,404.62 3,310.82 -187.62 171.63 5,959,574.29 550,473.41 3.28 252.64 GYD-CT-CMS(1) 3,469.80 24.39 143.38 3,427.44 3,333.64 -195.85 177.65 5,959,566.09 550,479.49 2.83 262.84 GYD-CT-CMS(1) 3,494.80 24.93 144.73 3,450.16 3,356.36 -204.29 183.77 5,959,557.69 550,485.67 3.12 273.27 GYD-CT-CMS(1) 3,519.80 25.35 141.25 3,472.79 3,378.99 -212.77 190.17 5,959,549.26 550,492.12 6.15 283.88 GYD-CT-CMS(1) 3,544.80 26.46 143.11 3,495.28 3,401.48 -221.40 196.86 5,959,540.68 550,498.87 5.50 294.80 GYD-CT-CMS(1) 3,569.80 27.67 143.49 3,517.54 3,423.74 -230.52 203.66 5,959,531.60 550,505.73 4.89 306.17 GYD-CT-CMS(1) 3,594.80 28.08 142.74 3,539.64 3,445.84 -239.87 210.67 5,959,522.30 550,512.80 2.16 317.86 GYD-CT-CMS(1) 3,619.80 29.08 142.67 3,561.59 3,467.79 -249.38 217.92 5,959,512.84 550,520.11 4.00 329.81 GYD-CT-CMS(1) 3,644.80 29.98 141.26 3,583.35 3,489.55 -259.09 225.51 5,959,503.19 550,527.77 4.55 342.13 GYD-CT-CMS(1) 3,669.80 30.85 140.29 3,604.91 3,511.11 -268.89 233.52 5,959,493.44 550,535.84 4.00 354.76 GYD-CT-CMS(1) 3,694.80 31.57 140.21 3,626.29 3,532.49 -278.85 241.80 5,959,483.53 550,544.19 2.88 367.69 GYD-CT-CMS(1) 3,719.80 32.13 138.94 3,647.52 3,553.72 -288.89 250.36 5,959,473.55 550,552.81 3.49 380.84 GYD-CT-CMS(1) 3,744.80 33.08 138.02 3,668.58 3,574.78 -298.97 259.29 5,959,463.53 550,561.81 4.29 394.24 GYD-CT-CMS(1) 3,769.80 34.43 136.59 3,689.37 3,595.57 -309.18 268.71 5,959,453.38 550,571.29 6.27 408.04 GYD-CT-CMS(1) 3,794.80 34.88 138.73 3,709.94 3,616.14 -319.69 278.28 5,959,442.94 550,580.94 5.19 422.16 GYD-CT-CMS(1) 3,819.80 36.12 138.08 3,730.29 3,636.49 -330.54 287.92 5,959,432.15 550,590.65 5.18 436.61 GYD-CT-CMS(1) 3,844.80 36.08 140.42 3,750.49 3,656.69 -341.70 297.53 5,959,421.06 550,600.33 5.52 451.29 GYD-CT-CMS(1) 3,869.80 36.12 138.36 3,770.69 3,676.89 -352.88 307.12 5,959,409.95 550,609.99 4.86 465.96 GYD-CT-CMS(1) 3,894.80 37.04 140.27 3,790.77 3,696.97 -364.18 316.83 5,959,398.71 550,619.78 5.85 480.81 GYD-CT-CMS(1) 3,919.80 35.54 138.94 3,810.92 3,717.12 -375.45 326.41 5,959,387.51 550,629.44 6.78 495.56 GYD-CT-CMS(1) 3,944.80 36.62 140.19 3,831.12 3,737.32 -386.66 335.96 5,959,376.37 550,639.06 5.23 510.24 GYD-CT-CMS(1) 3,969.80 36.01 138.52 3,851.27 3,757.47 -397.89 345.60 5,959,365.20 550,648.77 4.65 524.99 GYD-CT-CMS(1) 3,994.80 36.12 140.69 3,871.47 3,777.67 -409.10 355.14 5,959,354.06 550,658.38 5.13 539.66 GYD-CT-CMS(1) 4,019.80 36.39 138.78 3,891.64 3,797.84 -420.38 364.69 5,959,342.84 550,668.01 4.65 554.40 GYD-CT-CMS(1) 4,044.80 35.84 140.16 3,911.83 3,818.03 -431.58 374.27 5,959,331.71 550,677.66 3.93 569.09 GYD-CT-CMS(1) 4,069.80 36.36 139.85 3,932.03 3,838.23 -442.86 383.74 5,959,320.49 550,687.21 2.20 583.78 GYD-CT-CMS(1) 4,094.80 35.19 139.84 3,952.31 3,858.51 -454.02 393.18 5,959,309.40 550,696.72 4.71 598.36 GYD-CT-CMS(1) 4,119.80 36.11 140.18 3,972.63 3,878.83 -465.16 402.56 5,959,298.32 550,706.18 3.89 612.89 GYD-CT-CMS(1) 4,144.80 35.76 138.46 3,992.87 3,899.07 -476.29 412.13 5,959,287.26 550,715.81 4.27 627.51 GYD-CT-CMS(1) 4,169.80 35.20 140.85 4,013.23 3,919.43 -487.34 421.52 5,959,276.27 550,725.28 5.98 641.98 GYD-CT-CMS(1) 4,194.80 35.38 138.90 4,033.64 3,939.84 -498.39 430.83 5,959,265.29 550,734.66 4.56 656.38 GYD-CT-CMS(1) 4,219.80 35.60 140.71 4,053.99 3,960.19 -509.47 440.19 5,959,254.26 550,744.10 4.29 670.85 GYD-CT-CMS(1) 4,244.80 34.93 139.25 4,074.41 3,980.61 -520.53 449.47 5,959,243.27 550,753.45 4.31 685.25 GYD-CT-CMS(1) 4,269.80 35.56 141.07 4,094.82 4,001.02 -531.60 458.71 5,959,232.26 550,762.77 4.90 699.64 GYD-CT-CMS(1) 4,294.80 34.97 139.46 4,115.24 4,021.44 -542.70 467.94 5,959,221.22 550,772.06 4.40 714.04 GYD-CT-CMS(1) 1/3/2012 10:51:57AM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 1E-24 Project: Kuparuk River Unit TVD Reference: 1E-24B @ 93.80ft(D141(26.8+67)) Site: Kuparuk 1E Pad MD Reference: 1 E-24B©93.80ft(D141(26.8+67)) Well: 1E-24 North Reference: True Wellbore: 1E-24B Survey Calculation Method: Minimum Curvature Design: 1E-24B Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0/1001 (ft) Survey Tool Name 4,319.80 35.08 140.39 4,135.71 4,041.91 -553.68 477.17 5,959,210.31 550,781.37 2.18 728.35 GYD-CT-CMS(1) 4,344.80 36.16 140.13 4,156.03 4,062.23 -564.88 486.48 5,959,199.18 550,790.76 4.36 742.88 GYD-CT-CMS(1) 4,369.80 33.58 140.28 4,176.54 4,082.74 -575.86 495.63 5,959,188.26 550,799.98 10.33 757.14 GYD-CT-CMS(1) 4,394.80 35.63 139.75 4,197.12 4,103.32 -586.74 504.76 5,959,177.44 550,809.17 8.29 771.30 GYD-CT-CMS(1) 4,419.80 34.26 141.09 4,217.61 4,123.81 -597.77 513.88 5,959,166.47 550,818.37 6.28 785.59 GYD-CT-CMS(1) 4,444.80 35.26 140.22 4,238.15 4,144.35 -608.79 522.92 5,959,155.51 550,827.48 4.46 799.82 GYD-CT-CMS(1) 4,469.80 33.80 140.86 4,258.74 4,164.94 -619.73 531.92 5,959,144.63 550,836.56 6.02 813.96 GYD-CT-CMS(1) 4,494.80 34.84 139.96 4,279.39 4,185.59 -630.59 540.91 5,959,133.83 550,845.61 4.63 828.03 GYD-CT-CMS(1) 4,519.80 33.52 142.42 4,300.07 4,206.27 -641.53 549.71 5,959,122.96 550,854.49 7.64 842.05 GYD-CT-CMS(1) 4,544.80 33.55 139.70 4,320.91 4,227.11 -652.27 558.39 5,959,112.27 550,863.24 6.01 855.84 GYD-CT-CMS(1) 4,569.80 33.46 142.06 4,341.76 4,247.96 -662.98 567.10 5,959,101.63 550,872.02 5.22 869.62 GYD-CT-CMS(1) 4,594.80 33.27 140.06 4,362.64 4,268.84 -673.67 575.74 5,959,091.00 550,880.73 4.46 883.35 GYD-CT-CMS(1) 4,619.80 32.96 142.42 4,383.58 4,289.78 -684.32 584.29 5,959,080.41 550,889.35 5.30 896.99 GYD-CT-CMS(1) 4,644.80 32.95 139.77 4,404.56 4,310.76 -694.90 592.83 5,959,069.88 550,897.96 5.77 910.56 GYD-CT-CMS(1) 4,669.80 32.43 142.98 4,425.60 4,331.80 -705.44 601.25 5,959,059.40 550,906.45 7.24 924.05 GYD-CT-CMS(1) 4,694.80 32.06 140.16 4,446.74 4,352.94 -715.89 609.54 5,959,049.01 550,914.81 6.20 937.37 GYD-CT-CMS(1) 4,719.80 32.18 141.20 4,467.92 4,374.12 -726.17 617.96 5,959,038.78 550,923.30 2.26 950.64 GYD-CT-CMS(1) 4,744.80 32.06 143.25 4,489.09 4,395.29 -736.68 626.11 5,959,028.33 550,931.51 4.39 963.92 GYD-CT-CMS(1) 4,769.80 32.81 140.27 4,510.19 4,416.39 -747.20 634.41 5,959,017.86 550,939.88 7.06 977.32 GYD-CT-CMS(1) I 4,794.80 32.81 142.25 4,531.21 4,437.41 -757.77 642.88 5,959,007.36 550,948.43 4.29 990.84 GYD-CT-CMS(1) 4,819.80 32.92 140.42 4,552.21 4,458.41 -768.36 651.36 5,958,996.82 550,956.97 4.00 1,004.39 GYD-CT-CMS(1) 4,844.80 33.69 142.63 4,573.10 4,479.30 -779.11 659.89 5,958,986.13 550,965.58 5.75 1,018.11 GYD-CT-CMS(1) 4,869.80 33.78 139.76 4,593.89 4,500.09 -789.92 668.59 5,958,975.38 550,974.35 6.39 1,031.97 GYD-CT-CMS(1) 4,894.80 33.95 142.23 4,614.65 4,520.85 -800.75 677.36 5,958,964.61 550,983.19 5.55 1,045.88 GYD-CT-CMS(1) 4,913.00 34.31 141.27 4,629.72 4,535.92 -808.77 683.68 5,958,956.64 550,989.56 3.56 1,056.08 MWD+IFR-AK-CAZ-SC(2) 4,927.59 34.91 142.02 4,641.73 4,547.93 -815.26 688.82 5,958,950.17 550,994.75 5.04 1,064.36 MWD+IFR-AK-CAZ-SC(2) 5,018.91 36.41 148.43 4,715.95 4,622.15 -858.97 719.10 5,958,906.68 551,025.32 4.41 1,117.52 MWD+IFR-AK-CAZ-SC(2) 5,113.70 33.62 150.00 4,793.57 4,699.77 -905.67 746.96 5,958,860.16 551,053.48 3.09 1,171.68 MWD+IFR-AK-CAZ-SC(2) 5,208.53 29.15 154.29 4,874.52 4,780.72 -949.25 770.12 5,958,816.75 551,076.93 5.27 1,220.55 MWD+IFR-AK-CAZ-SC(2) 5,255.40 27.93 154.86 4,915.69 4,821.89 -969.47 779.74 5,958,796.60 551,086.68 2.67 1,242.57 MWD+IFR-AK-CAZ-SC(2) 5,303.24 25.44 160.02 4,958.44 4,864.64 -989.27 788.01 5,958,776.85 551,095.09 7.11 1,263.46 MWD+IFR-AK-CAZ-SC(2) 5,353.98 23.72 163.34 5,004.58 4,910.78 -1,009.30 794.66 5,958,756.87 551,101.87 4.35 1,283.57 MWD+IFR-AK-CAZ-SC(2) 5,397.26 21.53 170.42 5,044.54 4,950.74 -1,025.47 798.48 5,958,740.73 551,105.80 8.07 1,298.91 MWD+IFR-AK-CAZ-SC(2) 5,444.54 19.67 175.79 5,088.79 4,994.99 -1,041.97 800.51 5,958,724.25 551,107.94 5.60 1,313.46 MWD+IFR-AK-CAZ-SC(2) 5,490.54 17.84 182.24 5,132.35 5,038.55 -1,056.73 800.80 5,958,709.49 551,108.33 6.01 1,325.58 MWD+IFR-AK-CAZ-SC(2) 5,539.97 16.52 185.04 5,179.58 5,085.78 -1,071.30 799.89 5,958,694.92 551,107.51 3.15 1,336.84 MWD+IFR-AK-CAZ-SC(2) I 5,584.45 15.97 189.71 5,222.28 5,128.48 -1,083.63 798.30 5,958,682.57 551,106.01 3.19 1,345.89 MWD+IFR-AK-CAZ-SC(2) 5,674.64 15.87 192.03 5,309.02 5,215.22 -1,107.92 793.64 5,958,658.26 551,101.51 0.71 1,362.82 MWD+IFR-AK-CAZ-SC(2) 5,771.72 17.26 189.60 5,402.07 5,308.27 -1,135.10 788.47 5,958,631.04 551,096.52 1.60 1,381.80 MWD+IFR-AK-CAZ-SC(2) 5,864.75 20.11 188.71 5,490.18 5,396.38 -1,164.53 783.74 5,958,601.59 551,091.99 3.08 1,402.85 MWD+IFR-AK-CAZ-SC(2) 1/3/2012 10:51:57AM Page 7 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 1 E-24 Project: Kuparuk River Unit TVD Reference: 1E-24B @ 93.80ft(D141(26.8+67)) Site: Kuparuk 1 E Pad MD Reference: 1 E-24B @ 93.80ft(D141(26.8+67)) Well: 1E-24 North Reference: True Wellbore: 1E-24B Survey Calculation Method: Minimum Curvature Design: 1E-24B Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (') (°) (ft) (ft) : (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 5,960.94 24.32 189.69 5,579.21 5,485.41 -1,200.41 777.90 5,958,56567 551,086.39 4.39 1,428.47 MWD+IFR-AK-CAZ-SC(3) 6,053.71 26.86 190.34 5,662.88 5,569.08 -1,239.87 770.92 5,958,526.17 551,079.68 2.75 1,456.32 MWD+IFR-AK-CAZ-SC(3) 6,148.95 29.50 190.55 5,746.82 5,653.02 -1,284.09 762.77 5,958,481.90 551,071.82 2.77 1,487.34 MWD+IFR-AK-CAZ-SC(3) 6,242.45 32.33 190.24 5,827.03 5,733.23 -1,331.34 754.11 5,958,434.60 551,063.48 3.03 1,520.51 MWD+IFR-AK-CAZ-SC(3) 6,335.15 34.12 189.51 5,904.57 5,810.77 -1,381.38 745.40 5,958,384.51 551,055.11 1.98 1,555.91 MWD+IFR-AK-CAZ-SC(3) 6,429.99 33.88 189.34 5,983.20 5,889.40 -1,433.69 736.72 5,958,332.14 551,046.78 0.27 1,593.17 MWD+IFR-AK-CAZ-SC(3) 6,480.45 33.52 189.02 6,025.18 5,931.38 -1,461.33 732.25 5,958,304.47 551,042.49 0.80 1,612.93 MWD+IFR-AK-CAZ-SC(4) 6,574.95 33.66 190.15 6,103.90 6,010.10 -1,512.88 723.54 5,958,252.87 551,034.13 0.68 1,649.55 MWD+IFR-AK-CAZ-SC(4) 6,670.05 33.30 191.22 6,183.22 6,089.42 -1,564.43 713.82 5,958,201.26 551,024 76 0.73 1,685.58 MWD+IFR-AK-CAZ-SC(4) 6,763.52 32.45 190.11 6,261.72 6,167.92 -1,614.29 704.43 5,958,151.35 551,015.70 1.11 1,720.43 MWD+IFR-AK-CAZ-SC(4) 6,855.88 32.04 189.18 6,339.84 6,246.04 -1,662.87 696.17 5,958,102.72 551,007.77 0.70 1,754.92 MWD+IFR-AK-CAZ-SC(4) 6,907.84 31.75 190.96 6,383.95 6,290.15 -1,689.90 691.37 5,958,075.66 551,003.15 1.89 1,773.99 MWD+IFR-AK-CAZ-SC(4) 6,940.00 31.75 190.96 6,411.30 6,317.50 -1,706.51 688.15 5,958,059.03 551,000.04 0.00 1,785.55 PROJECTED to TD 1/3/2012 10:51:57AM Page 8 COMPASS 2003.16 Build 69 w tY - .O .t• o Eo co w'u Aa —00 .'LO g;En 0t - SN c > oo - a ❑a `o .� 30 0 _ Z, o a c« _ n x v 3 c, uW - D w 3 -o - o _o " o.rn w w co oC' X 0 O O d W 0.- 0 - a N Z oL - o OO t L co = L E 7,t O 6 3 0 >'; - NL W - c a 0+ ar - o o ELi0`o —o y N .L. a r - 3 L Tr_ _ 0 � L='3 0 _ N in 0 O V >y ?i.' 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Z N0 (00 C N O (O V N 1 !(fl y N Ladea jeo!Pan awl v `° ti a d o ,S21,1; ConocoPhillips Time Log & Summary Wenview Web Reporting Report Well Name: 1E-24 Rig Name: DOYON 141 Job Type: DRILLING SIDETRACK Rig Accept: 12/11/2011 3:00:00 AM Rig Release: 12/31/2011 2:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/10/2011 24 hr Summary Rig Released from well 3G-22 @ 0400 HRS. Blow down all lines.Move Boiler, Motors, Pump&Pit complexes to 1 E-pad. MOve pipe sheds. Pull Sub structure off of well 3G-22.Move sub to 1 E pad. SPot over well 1E-24. Spot all complexes. Spot rockwasher&pipe sheds.Trucks back to 3G to move rig camp. Work on rig acceptance checklist. 04:00 12:00 8.00 0 0 MIRU MOVE MOB P Rig released from 3G-22 at 0400 HRS. Prep rig to move. Blow down steam,water, air lines. Disconnect all interconnects.Move pipe sheds. Move rockwasher. Load rig modules with PEAK. Move rig from 3G-22 to 1E-24B 12:00 15:30 3.50 0 0 MIRU MOVE MOB P Move Sub base, Pipe Sheds, & Rockwasher from 3G-22 to 1 E-24B 15:30 18:00 2.50 0 0 MIRU MOVE PSIT P Spot sub base over well 1E-24. 18:00 21:00 3.00 0 0 MIRU MOVE PSIT P Spot power pack complexes.Spot rockwasher,and pipe sheds. 21:00 00:00 3.00 0 0 MIRU MOVE MOB P Mobilize trucks to 3G Pad to get rig camp,sewer plant&truck shop. Work on rig acceptance checklist. 12/11/2011 Continue work on Rig acceptance checklist. Move rig camp to 1 E pad. Spot and rig up same. Rig accepted at 0300 HRS.Take on seawater. Rig up bleed tank&lines. RU lines in cellar.test lines to 2000 PSI. Pull BPV w/Lubricator. Pump down tubing taking returns to bleed tank, 185 BBLS. Monitor well-static.Set BPV. Nipple down tree. NU BOP's. Rig up and test BOP's.Witness of test waived by AOGCC rep John Crisp. 00:00 03:00 3.00 0 0 MIRU MOVE MOB P Continue work on rig acceptance checklist.Move rig camp from 3G- 1E pad.Set stairs,and build berms. Spot and rig up same. Rig accepted at 0300 HRS. 03:00 05:00 2.00 0 0 SLOT DRILL RURD P Take on 580 BBLS of seawater to pits.Set bleed tank. Rig up lines _ from cellar to tank. 05:00 08:15 3.25 0 0 SLOT DRILL RURD P Rig up lubricator as per FMC rep. Test Lub to 5K-5 minutes. Pull BPV. Observed no pressure under BPV. Rig down Lubricator. 08:15 08:30 0.25 0 0 SLOT DRILL SFTY P Held PJSM with crew. Discuss safety&hazard recognition issues. Discuss procedure to tets lines, kill well, pumping diesel returns to bleed tank. Page 1 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 11:30 3.00 0 0 SLOT DRILL KLWL P Pump down tubing at 3 BPM-800 PSI, returns(diesel)to bleed tank. Observed"packing off'when attempting to pump 4 BPM. Pressure stabilized at 1500 PSI with 1.2 BPM. Pumped a total of 185 BBLS> 11:30 12:00 0.50 0 0 SLOT DRILL OWFF P Monitor well-static. Blow diown lines to bleed tank. Crew Change 12:00 12:45 0.75 0 0 SLOT DRILL CIRC P Line up to take returns to rockwashewr,and pump to verify down hole packoff at 2.5 BPM-1600 PSI. Pump a total of 20 BBLS. Monitor well-static. 12:45 13:00 0.25 0 0 SLOT DRILL RURD P Blow down all lines. Rig down lines in cellar and to tank. 13:00 13:30 0.50 0 0 SLOT WHDBO NUND P Install BPV. Held PJSM-ND Tree. 13:30 16:00 2.50 0 0 SLOT WHDBO NUND P Nipple down tree as per FMC rep. Observe orientatioin of tree for future reference. Install blanking plug for test. Nipple up double studded adapter flange. 16:00 18:30 2.50 0 0 SLOT WHDBO NUND P Nipple up BOP stack,choke&kill lines. 18:30 19:00 0.50 0 0 SLOT WHDBO BOPE P Rig up to test BOP's. Load system with water. 19:00 22:45 3.75 0 0 SLOT WHDBO BOPE P Test BOP's. Several attempts made for initial test,without success, observed that the blanking plug leaking. Install solid joint,and by remove test joint. Re test,with same f result. Pull blanking plug, change out ball seat in blanking plug. Install 3 1/2"test joint.Test to 3500,for good initial test. 22:45 00:00 1.25 0 0 SLOT WHDBO BOPE P Continue test BOP's.Test choke manifold and all valves.Test choke& kill lines manual valves and NCR's. Test Upper and lower rams,and IBOP.All test 250/3500 PSI as per permit.All tests recorded on chart. Witness of test waived by AOGCC rep John Crisp.Crew Change 12/12/2011 Continue test BOP's.All test 250/3500 PSI, recorded on chart. Perform Koomey test.Observed initial 200 PSI increase in 37 Seconds,full 3000 PSI gained in 192 Seconds. 5 Nitrogen bottles with an avg PSI of 2100. Witness of test waived by AOGCC rep John Crisp. Pull&lay down 3 1/2"tbg.Set test plug, and test BOP's with 4"test joint. Make up BHA#1, Mill&scraper run,TIH picking up 4"DP singles from shed.Tag up at 4947'. Page 2 of 30 7 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:15 3.25 0 0 SLOT WHDBO BOPE P Continue test BOP's. Utilize 3 1/2" test joint.All test 250/3500 PSI, recorded on chart. Perform Koomey test. Observed initial 200 PSI gained in 37 seconds. Full 3000 PSI obtained in 192 seconds.Observed 5 Nitrogen bottles iwth an avg PSI of 2100.Witness of test waived by AOGCC rep John Crisp. 03:15 05:00 1.75 0 0 SLOT WHDBO BOPE P Rig down test equipment. Drain stack,and pull blanking plug. 05:00 05:30 0.50 0 0 SLOT DRILL PULD P Break floor valves. Blow down choke &kill lines. Pull tools to rig floor. 05:30 05:45 0.25 0 0 SLOT DRILL SFTY P Held PJSM with crew and Doyon casing rep. Discuss safety&hazard recognition issues. Discuss procedure to rig up and pull 3 1/2" tubing. 05:45 06:45 1.00 0 0 SLOT DRILL RURD P Pull tools to rig floor. Make up power tongs,prep to pull 3 1/2"tubing. Make up landing joint with pups. is BOLDS. 06:45 07:00 0.25 0 0 SLOT DRILL PULL P Pull on3 1/2"tbg,hanger&tbg_free movement. UP WT=70K. 07:00 12:00 5.00 0 0 SLOT DRILL PULL P Breakout&lay down hanger, and landing joint. Install stripping rubbers. Pull and lay down 136 joints of 3 1/2" tbg.Observed proper displacement. Crew Change 12:00 13:15 1.25 0 0 SLOT DRILL PULL P Continue POOH lay down 3 1/2" tubing.Total laid down=158 jnts,3 GLM's, 2 pups and a cut off joint= 15.58'.Cut looked good.Strapped tubing&jewelry laid down-total- 4945.43' 13:15 14:30 1.25 0 0 SLOT DRILL RURD P Rig down handling equipment.Clean &clear rig floor. 14:30 17:30 3.00 0 0 SLOT WHDBO BOPE P Held PJSM. RU test equipment,set test plug with 4"test joint.Test BOP's to 250/3500 PSI, record on chart. RD test equipment, pull test plug. 17:30 18:00 0.50 0 0 SLOT DRILL RURD P .Install wear bushing. RILDS 18:00 18:15 0.25 0 0 SLOT DRILL SFTY P Held PJSM with crew. Discuss safety&hazard recognition issues. Discuss procedure to make up BHA, and TIH picking up DP from shed. 18:15 00:00 5.75 0 4,947 SLOT DRILL TRIP P Make up BHA 31,6.125"Mill and scraper assembly.Trip in hole picking up 4" DP singles from shed. Tag up at 4947' DPM.Crew Change 12/13/2011 Pumps on, Rotate 60 RPM's to wash down 21'to 4968'DPM.Confirm DP depth. Hard tag with 15K set down, and wouldn't mill off.Circulate Safe surf& Hi Visc sweeps, until clean. POOH Page 3 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 4,947 4,968 SLOT DRILL IWASH P Pumps on, UP WT 105K,SO WT 87K. ROT 60 RPM's pumps at 5 BPM-450 PSI.Wash down through the tight spot at 4947'DPM, mill fell through, continue wash down and tag up at 4968'.Attempt to mill through tight spot with 10-15K, no success. Straight hard tag with 15K set down weight. Discuss options with town engineer. 01:00 03:15 2.25 4,968 4,968 SLOT DRILL CIRC P Reciprocate drill string while pump safe surf sweep,followed with High visc sweep.Circulate until clean as planned with pumps at 6 BPM-450 PSI. Note: OA pressure=475 PSI. Bleed pressure to bleed tank. 03:15 03:30 0.25 4,968 4,968 SLOT DRILL OWFF P Monitor well.Static. Blow down top drive. 03:30 05:30 2.00 4,968 9 SLOT DRILL TRIP P Trip out of the hole with the scraper assembly from 4968'to 9.30'. 05:30 05:45 0.25 9 0 SLOT DRILL PULD P Lay down BHA#1 casing scraper. 05:45 06:15 0.50 0 0 SLOT PERF RURD P Clear and clean rig floor, in preparation for peforating. 06:15 11:00 4.75 0 0 SLOT PERF RURD P PJSM, Remove bell nipple and bell nipple adaptor. Install shooting flange on top of annular. 11:00 12:00 1.00 0 0 SLOT PERF RURD P Pick up E-Line from beaver slide. Rig up Halliburton E-Line 12:00 13:15 1.25 0 0 SLOT PERF RURD P PJSM with Halliburton E Line crew and rig crew. Continue to rig up electric line equipment. Nipple up E- Line BOPE stack with pump in sub, make up riser and grease head, make up perf gun and nipple up to stump. Flood kill line. 13:15 13:30 0.25 0 0 SLOT PERF PRTS P Pressure test lubricator through kill line to 1000 PSI, Held for 5 mins. No leaks. Bleed off pressure, monitor returns to trip tank. 13:30 14:15 0.75 0 5,075 SLOT PERF ELOG P Run in hole with perforation gun on E Line @ 175 FPM to 5075WLM__ Correlate and fire guns from 4978'to 4988'WLM depths. 14:15 15:00 0.75 5,075 0 SLOT PERF ELOG P Pull out of the hole with E-Line. 15:00 16:30 1.50 0 0 SLOT PERF RURD P Rig down riser, remove spent perforation gun, monitor well, static, SIMOPS: nipple down E-Line BOP stack, make up short riser to grease head, make up cement retainer to E -Line and make up to stump. 16:30 17:45 1.25 0 4,968 SLOT PERF MPSP P Run in the hole with Baker Cement Retainer on E-Line. 150 FPM. Set @ 4968'WLM 17:45 19:00 1.25 4,968 0 SLOT PERF TRIP P Pull out of the hole with E-Line Page 4 of 30 Time Logs Date From To Dur S. Depth E.Death Phase Code Subcode T Comment 19:00 19:45 0.75 0 0 SLOT PERF RURD P Rig down Halliburton E-Line equipment 19:45 21:15 1.50 0 0 SLOT PERF NUND P Nipple down shooting flange. 21:15 22:30 1.25 0 0 SLOT PERF NUND P Nipple up bell nipple and riser. 22:30 00:00 1.50 0 1,383 SLOT CEMEN'TRIP P PJSM,Trip in the hole with stand#1. Make up head pin to top single,and lay down in pipe shed. Pick up the double and make up the cement. stinger assembly.Trip in the hole to 1383. Disp=7.5 BBLs.Actual 8.1 BBIs. 12/14/2011 Pump cement squeeze job. POOH to 20 stands. P/U Storm Packer,set Packer 75 feet down. Nipple down BOP. 10"growth. Spear 7"casing. Set slips with 80K.Cut casing. 00:00 01:00 1.00 1,383 4,952 SLOT CEMEN-TRIP P PJSM,Continue to trip in the hole from 1383'to 4952'.Tag up on retainer.Actual displacement=28.25, _ Calculated displacement=28.5 01:00 01:30 0.50 4,952 4,952 SLOT CEMEN'CIRC P Pick up single, Rig up to circulate and pump cement with SLB. 01:30 02:00 0.50 4,952 4,952 SLOT CEMEN'CIRC P Obtain parameters @ 2 BPM=100 PSI,3 BPM= 125 PSI. Close Super choke to 7/8th's and record 200 PSI annular pressure with 3 BPM. Mark gauge. Up Wt=100k, Dn Wt=90k 02:00 02:15 0.25 4,952 4,952 SLOT CEMEN'CIRC P Verified retainer depth.4952'DPM. Set 10k down, P/U to 9K over to unsnap. Repeat 3x's. 02:15 03:00 0.75 4,952 4,952 SLOT CEMEN-PRTS P Pressure test retainer to 1000 PSI for 5 mins.Charted. Perform injectivity test.Stage pump up to 1 BPM. 10 strokes 1 BBUmin 800PSI 20 1 1300 30 1 1300 40 1 1300 50 1.5 BBUmin 1300 60 1.5 1250 70 1.5 1250 80 2.0 1300 90 2.0 1300 100 2.0 1300 120 3.0 1300 130 3.0 1300 140 3.0 1300 150 3.0 1300 Pumped away 15 barrels.2.5 barrels bleed back in 20 mins. 03:00 03:15 0.25 4,952 4,952 SLOT CEMEN'PRTS P Bleed off all pressure. Line back up to go through Super Choke. 03:15 03:30 0.25 4,952 4,952 SLOT CEMEN-SFTY P Prejob safety meeting with all crews for Cement Job. 03:30 04:30 1.00 4,952 4,952 SLOT CEMEN'PRTS P Prime up cement truck pumps, lines equipment. Pressure test lines to 3500 PSI. Good. Page 5 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 06:30 2.00 4,952 4,952 SLOT CEMEN"CMNT P Batched up 15.8 PPG cement. ( Pump 10 BBLs water,20 BBLs Al-- Cement,6 BBLs water, 16 BBLs S seawater. Holding 200 PSI on backside. Shut down pumps.Sting into retainer. Close super choke. Close choke side HCR. Place 1000 PSI in annulus. Pump 41 BBLs seawater to displace. Unsting. Drop foam drill pipe wiping ball. Circulate bottoms up 2x's.6.5 BPM,650 PSI. 2 barrels of cement seen at the _ shakers. 06:30 07:00 0.50 4,952 4,952 SLOT CEMEN-PRTS P Pressure test casing to 3500 PSI. 30 mins. Charted.good. 07:00 07:30 0.50 4,952 4,952 SLOT DRILL TRIP P Lay down single. Blow down choke and kill lines. Monitor well Static. 07:30 09:15 1.75 4,952 1,856 SLOT DRILL TRIP P POOH from 4952'to 1856'.Actual fill=19 BBLS.Calculated fill= 17.2BBLS. 09:15 10:30 1.25 1,856 1,856 SLOT WHDBO PACK P Pick up Baker Storm Packer.Set 75' down. P/U wt=60k, 5/0 wt=58k. Lay down Packer running tool.Test Packer to 500 PSI for 5 mins.good. 10:30 12:00 1.50 1,856 1,856 SLOT WHDBO NUND P PJSM. Drain stack. Nipple down BOPE stack 12:00 13:00 1.00 1,856 1,856 SLOT WHDBO NUND P Continue to nipple down stack and double studed adapter flange. 13:00 14:00 1.00 1,856 1,856 SLOT WHDBO NUND P Break all nuts on tubing spool. Observed growth of casing. 14:00 14:45 0.75 1,856 1,856 SLOT WHDBO NUND P Disassemble tubing spool. 14:45 18:30 3.75 1,856 1,856 SLOT WHDBO NUND P Rig up hydratight tools, SIMOPS: load pipe shed with 16 jts.4"DP. Grow casing in controlled manner with hydratight tool. 10.5"growth. Rig down hydratight. 18:30 19:30 1.00 1,856 1,856 SLOT WHDBO NUND P Pull 7"Pack off,Pick up Baker spear.SIMOPS:stage tubing spool in cellar. 19:30 22:00 2.50 1,856 1,856 SLOT WHDBO FISH P Make up spear assembly to top drive. Engage 7"casing with spear. Pick up to 100k over block and string weight. Set slips per FMC reps. Set 80k weight on slips. Release spear and lay down. 22:00 00:00 2.00 1,856 1,856 SLOT WHDBOCPBO P Prepare casing head,make up WACHS cutter to stump. SIMOPS: load pipe shed with 9-4%"DC's, 14 -4"HWDP. Cut off casing stump 7" casing+Hanger 7 1/4"for a total of 14 1/4". 12/15/2011 Install new packoff and tubing spool. N/U BOPE.Test. Retrieve storm packer. POOH to cement stinger. UD.P/U whipstock.TIH. Begin Milling to 4922'MD. 9 feet.Stop to treat milling fluid. Page 6 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:00 3.00 1,856 1,856 SLOT WHDBO NUND P PJSM, Install new pack off as per FMC rep. Pick up and make up new tubing spool.Test to 3000 PSI form 10 mins. Good 03:00 05:30 2.50 1,856 1,856 SLOT WHDBO NUND P Nipple up double studded adapter flange and BOPE stack 05:30 06:15 0.75 1,856 1,856 SLOT WHDBO BOPE P Rig up to test. 06:15 06:30 0.25 1,856 1,856 SLOT WHDBO BOPE P Test choke line and block flange,_ tubing head flange.250 PSI low/ 3500 PSI high for 5 mins. 06:30 07:00 0.50 1,856 1,856 SLOT WHDBO BOPE P Rig down test equipment,drain stack,blow down lines. 07:00 07:30 0.50 1,856 1,856 SLOT WHDBO PULD P Install wear ring and short mousehole. 07:30 08:30 1.00 1,856 1,856 SLOT DRILL TRIP P Pick up storm packer retrieval tool and make up to stand. RIH 75'. Latch up to storm packer. Pull storm packer. Monitor well. Static. POOH with packer.Monitor well.Static. 08:30 09:45 1.25 1,856 0 SLOT DRILL TRIP P Trip out of the hole from 1856 to surface. Lay_down cement stinger. Actual fill=11.25 BBLS. Calculated fill 10.8 BBLS 09:45 10:00 0.25 0 0 SLOT DRILL PULD P Clear and clean rig floor. 10:00 12:00 2.00 0 0 SLOT WHPST WPST P PJSM.Pick up whipstock and make up 17'spacer joint of bottom of trip anchor,along with two cross overs. (Baker). Lay down ramp. Pick up joint of HWDP and milling assembly. Make up whipstock to mills. 12:00 14:00 2.00 0 420 SLOT WHPST WPST P PJSM.Continue to make up milling assembly(BHA#1, Orient MWD to face of ramp.Make up 9-43/4"spiral drill collars, 9 joints of HWDP. 14:00 14:15 0.25 420 420 SLOT WHPST DHEQ P Shallow pulse test MWD 7 BPM/ 750 PSI 14:15 17:15 3.00 420 4,888 SLOT WHPST TRIP P TIH from 420'to 4888'. Pick up single from pipe shed.and make up to top drive. P/U Wt= 100k, S/O Wt=100k. Displacement=33 BBLS. Calculated=34.1 BBLS. 17:15 18:00 0.75 4,888 4,913 SLOT WHPST WPST P Break circulation @ 7 BPM. 1100 PSI. Orient whipstock to 43 right of high side. Make up to next stand from derrick. Confirm tool face orientation and tag up on cement retainer @ 4950'. Set down 15k. observe anchor set. Pick up with 10k over pull to verify anchor set.Slack off to shear bolt with 35k. Pick up 10 feet to clear whipstock face. Page 7 of 30 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 18:00 20:30 2.50 4,913 4,913 SLOT WHPST CIRC P PJSM, Displace well to 9.8 PPG Drill Plex milling fluid @ 1 BPM 1100 PSI due to high vis and high YP of mud system. Pressure increased dramatically to 3300 PSI with 4.5 BPM. Isolate active system to pit#5. Attempt to shear out the mud system Stage pumps up to 5.5 BPM.3200 PSI.TOW=4913', BOW=4926'. 20:30 21:00 0.50 4,913 4,913 SLOT WHPST CIRC P Obtain slow pump rates.#1@20 • SPM 1840 PSI, 30 SPM 2200 PSI. #2@ 20 SPM 1960 PSI, 30 SPM 2460 PSI. MD=4913'/TVD=4640'. MW=9.7 PPG. P/U Wt=115k,S/O Wt=74k, Rot Wt=80k.TQ off=3k. Mud Vis 300+/YP 159. 21:00 23:00 2.00 4,913 4,922 SLOT WHPST MILL P Mill window as per Baker Rep.from top of window 4913'to 4922'.W/2 to 3k WOB,80 RPM,4.5 BPM, 3000 PSI. V 23:00 00:00 1.00 4,922 4,922 SLOT WHPST CIRC T Hole taking fluid. Excessive YP of 1 fj 200+,VIS 1000. Pick up off bottom I\, and slow pump to 3 BPM,evaluate (70 situation. 12/16/2011 Displace Drill Plex mud out to LSND. Mill Window and 20 feet of new hole to 4946'. Perform FIT to 12.5 PPG / L\ EMW. POOH. RIH with magnets to bottom. POOH for Sperry BHA. 1V 00:00 04:00 4.00 4,922 4,922 SLOT WHPST CIRC T Continue to circ,and attempt to condition milling fluid. No go. Prepare to change out to LSND.Clean pits, take on LSND.290 BBLS.(Pump rate 1 BPM= 1700 PSI w/Drill Plex.) 04:00 04:45 0.75 4,922 4,922 SLOT WHPST CIRC P Pump Spacer pill.30 BBLS. Displace out Drill Plex to LSND.205 barrels in. 205 barrels to the rock washer.Stage pump up to 6 BPM as the LSND rounded the corner,from 3 BPM. ICP=2000 PSI @ 3 BPM. FCP= 1100 PSI@6bpm. 04:45 05:15 0.50 4,922 4,922 SLOT WHPST CIRC P Clean under shakers and possum belly.Obtain new SPR's 05:15 07:00 1.75 4,922 4,946 SLOT WHPST MILL P Milling the window from 4922'to 4946'.20 feet of new hole.90 RPM/ 5-8k TQ/275 GPM/1450 PSI. TOW=4913. BOW=4926. Retrieved 200LB's of metal. Expected 200 LB's. 07:00 08:15 1.25 4,946 4,946 SLOT WHPST CIRC P Work mills across ramp,window area. Observed increase in pump pressure @ 4926'when working across the ramp.Went back and forth a few more times and it cleaned up. Pumped High Vis sweep. 70 SPM/1475 PSI/100 RPM. Good returns. Minor amount of metal. Page 8 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:15 08:30 0.25 4,946 4,946 SLOT WHPST OWFF P Monitor well.Static. Rack back stand#46. Blow down top-drive. 08:30 09:30 1.00 4,946 4,946 SLOT WHPST FIT P Rig up to perform FIT.Test to 12.5 PPG EMW. Rig down test equipment. 09:30 09:45 0.25 4,946 4,854 SLOT WHPST TRIP P Trip out of hole with Milling assembly.Saw 2 BBL gain.Tripped back in 2 stands to 4854'. 09:45 10:00 0.25 4,854 4,854 SLOT WHPST OWFF P Monitor well for flow. Static. Mud slightly aired up. 10:00 12:00 2.00 4,854 1,566 SLOT WHPST TRIP P POOH with Milling Assembly. From 4854'to 1566'.Actual fill=21.08 BBLS. Calculated fill 18.90 BBLS. 12:00 12:15 0.25 1,566 1,566 SLOT WHPST SFTY P Crew change. PJSM.Tripping Pipe 12:15 12:30 0.25 1,566 663 SLOT WHPST OWFF P POOH to 663'.Top of HWDP. Monitor well. Static. 12:30 13:45 1.25 663 0 SLOT WHPST TRIP P Stand back 3 stands HWDP,one stand DC's. UD 6 drill collars. Lay down MWD. Mills. Upper mill full gauge.6.125". 13:45 14:00 0.25 0 0 SLOT DRILL RURD P Clear and clean rig floor. 14:00 14:15 0.25 0 0 SLOT DRILL PULD P PJSM. Pick up BHA#2. Magnet Run 14:15 15:15 1.00 0 0 SLOT DRILL PULD P Pick up BHA#2 Magnet Run. 15:15 16:30 1.25 0 1,250 SLOT DRILL TRIP P Single in the hole out of the pipe shed.42 joints. 16:30 18:15 1.75 1,250 4,895 SLOT DRILL TRIP P Trip in the hole out of the derrick.UD top single on stand#48 to eliminate making connection.Cal Displacement=28.85.Actual Displacement=36.36 18:15 19:30 1.25 4,895 4,946 SLOT DRILL CIRC P Screw into stand#49.TIH to 4913'. P/U Wt=103k. S/O Wt=96k. Rot Wt=96k. Establish circulation @ 2 BPM.300 PSI. RIH to 4949'no rotation. Increased pump rate to 6 BPM, 500 PSI,20 RPM, 2-3k Tq. Slow ream to bottom. Increase in torque seen. Slight pack off as the magnets crossed over the ramp. Bled off pressure,pulled free to top of ramp with 21k over pull.slide back to bottom one more time. Pull out to top of whipstock ramp @ 4913'. CBU. 19:30 19:45 0.25 4,946 4,913 SLOT DRILL OWFF P Blow down top drive. Monitor well. Static. 19:45 21:30 1.75 4,913 412 SLOT DRILL TRIP P POOH from 4913'to 412'.Top of HWDP. Stop. Monitor well. Static. 21:30 23:00 1.50 412 0 SLOT DRILL TRIP P Stand back 3 stands of HWDP. UD 3 collars. Pull up to and clean magnets. retrieve 25 lbs of metal. (Total of 225 lbs of metal from the magnets and the milling run.) Page 9 of 30 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 0 0 SLOT DRILL PULD P L/D magnets.Clear and clean rig floor.Calculated hole fill=32.64 BBLS.Actual fill=29.93 BBLS. 12/17/2011 Flush stack. P/U BHA#3. Sperry motor run with bi-center bit. Begin drilling Intermediate hole. 00:00 01:30 1.50 0 0 SLOT DRILL PULD P PJSM. Pull wear ring. Flush stack. 01:30 02:15 0.75 0 0 INTRM1 DRILL PULD P Remove Baker tools from rig floor. P/U Sperry tools. 02:15 04:30 2.25 0 120 INTRM1 DRILL PULD P PJSM. Pick Up Sperry BHA#3 as per DD/MWD. 04:30 05:30 1.00 90 90 INTRM1 DRILL PULD P Up load MWD tool string. 05:30 05:45 0.25 90 90 INTRM1 DRILL CIRC P Pulse check MWD tools.290 GPM. 750 PSI. 05:45 07:15 1.50 90 90 INTRM1 DRILL PULD P Blow down top drive. Make up bit, pick up BHA to the HWDP as per DD. 07:15 09:00 1.75 90 4,913 INTRM1 DRILL TRIP P Trip in the hole. Fill every 20 stands. Trip to the toip of the window.4913' MD. Displacement=31.66 BBLS. Calculated displacement=31.45 BBLS. 09:00 09:30 0.50 4,913 4,913 INTRM1 DRILL CIRC P Make up top drive,fill pipe,shut down pumps. 09:30 12:00 2.50 4,913 4,941 INTRM1 DRILL DDRL P With pumps off,slide to bottom of whipstock. Flow 345 GPM,2100 PSI.Slide to 4936'.Observed pressure increase,400 PSI.Work to bottom with Bi-Center bit. Slide from 4928 to 4941'. P/U Wt=105k, S/O Wt=90k. 12:00 13:30 1.50 4,941 4,990 INTRM1 DRILL DDRL P Slide from 4941'to 4990'MD. 13:30 18:00 4.50 4,990 5,195 INTRM1 DRILL DDRL P Drill from 4990'to 5195'MD.4898' TVD.ART=1.90 hrs.AST=3.22 hrs. ADT=5.12 hrs.WOB=2-5k, RPM=60, 350 GPM,2500 PSI. 18:00 19:00 1.00 5,195 5,250 INTRM1 DRILL DDRL P Drill from 5195'MD to 5250'MD. Pump Hi Vis sweep. No appreciable increase in cuttings. 19:00 00:00 5.00 5,250 5,424 INTRM1 DRILL DDRL P Drill from 5250'MD to to 5424'MD. 5072'ND.ART=2.65 hrs,AST=3.39 hrs,ADT=4.14 hrs,Total bit hrs=9.26.Total jar hrs=21.82, P/U Wt=111 k, S/O Wt=97k,TQ on=2.5k, TQ off=2k, ECD=10.93 12/18/2011 Directional Drill from 5424'MD to 5896'MD. Build rate insufficient to hit target,TOOH to turn motor bend up to 1.76°from 1.50°. 00:00 06:00 6.00 5,424 5,592 INTRM1 DRILL DDRL P Directional Drill from 5424'MD to 5592'MD. 5229'ND.ART=1.5 hrs, AST=4.37 hrs,ADT=5.42 hrs,total bit hrs=14.68,total jar hrs=25.24, P/U Wt=115k, S/O Wt=102k, ROT Wt=110k,TQ ON=3k,TQ OFF=2k, ECD=10.74 ppg,WOB=5k, GPM=345,2300 PSI. Max gas=113 units. Page 10 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 5,592 5,708 INTRM1 DRILL DDRL P Directional Drill from 5592'to 5708' MD. 5340'TVD.ART=1.40 hrs, AST=1.93 hrs,ADT=3.33 hrs,Total bit hrs= 18.01,Total jar hrs.=28.57, P/U Wt=116k,S/O Wt=105k, ROT Wt=112k,TQ On=3k,TQ Off=2k, ECD=10.72,WOB=6k,GPM=345, 2400 PSI.Max gas=111 units. 12:00 16:00 4.00 5,708 5,896 INTRM1 DRILL DDRL P Directional Drill from 5708'MD to 5896'MD, 5519'TVD.ART=.25 hrs, AST=3.09 hrs,ADT=3.34 hrs,Total bit hrs=21.35,Total jar hrs.=31.91, P/U Wt=116k,S/O Wt=105k, ROT Wt=112k,TQ On=3k,TQ Off=2k, ECD=10.72,WOB=6k,GPM=345, 2400 PSI. Max gas=196 units. 16:00 18:30 2.50 5,896 5,896 INTRM1 DRILL CIRC T Pump High Vis sweep while circculating bottoms up. Prepare to POOH for motor adjustment.(Not getting needed build rate).Weight up from 9.6 ppg to 9.8 ppg in one circulation.Weight up from 9.8 ppg to 10.0 ppg during the second surface to surface circulation. Perform SPR's with 10.0 PPG.Pump#1 20 SPM=470 PSI,30 SPM=660 PSI. Pump#2 20 SPM=520 PSI,30 SPM=670 PSI. 18:30 18:45 0.25 5,896 5,896 INTRM1 DRILL OWFF T Observe well for flow.Static. Blow down top drive. 10 ppg mud weight in and out. 18:45 19:30 0.75 5,896 5,330 INTRM1 DRILL TRIP T POOH from 5896'MD to 5330'MD. Check for proper hole fill.2.7 BBLS equaled calculated. Pump dry job. 19:30 20:15 0.75 5,330 4,850 INTRM1 DRILL TRIP T POOH from 5330'MD to 4850'MD. Inside window.Monitor well. Static. 20:15 22:15 2.00 4,850 449 INTRM1 DRILL TRIP T Trip out of hole from 4850'MD to 449'.Top of HWDP. 22:15 22:30 0.25 449 449 INTRM1 DRILL OWFF T Monitor well.Static 22:30 23:15 0.75 449 93 INTRM1 DRILL TRIP T Rack back HWDP,one stand of flex collars. 23:15 00:00 0.75 93 0 INTRM1 DRILL PULD T Pull up to MWD,plug in and down load. Calculated displacement=35.3 BBLS.Actual displacement=38.1 BBLS 12/19/2011 P/U new bit,MWD system,set motor bend to 1.76°.TIH. Finish curve. Directional drill 7"hole f/5896'to 6413'(5970'TVD). 00:00 00:15 0.25 0 0 INTRM1 DRILL PULD T PJSM. Down load MWD tool string. 00:15 01:15 1.00 0 0 INTRM1 DRILL PULD T Lay down MWD tools. Break off bit. 01:15 01:30 0.25 0 0 INTRM1 DRILL RURD T Clear and clean rig floor. 01:30 02:00 0.50 0 93 INTRM1 DRILL PULD T Adjust bend in 5"motor from 1.5°to 1.76°. 02:00 03:00 1.00 93 93 INTRM1 DRILL PULD T Make up BHA#4 as per DD/MWD reps. Halliburton. Page 11 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 03:45 0.75 93 93 INTRMI DRILL PULD T Up Load MWD tool string. 03:45 04:00 0.25 93 93 INTRM1 DRILL PULD T Orient Motor to MWD. 04:00 04:15 0.25 93 93 INTRM1 DRILL CIRC T Pulse test MWD tools. 300 GPM, 900 PSI. 04:15 05:00 0.75 93 93 INTRM1 DRILL PULD T Blow down top drive and make up bit. 05:00 05:30 0.50 93 449 INTRM1 DRILL PULD T Pick up BHA to top of top drive. 05:30 08:00 2.50 449 4,913 INTRMI DRILL TRIP T TIH with 4"XT 39 DO out of the derrick. From 449'to 4913'Top of the window. Fill pipe every 20 stands. 08:00 08:45 0.75 4,913 5,804 INTRM1 DRILL TRIP T Slide through window. No problems. TIH to 5804'MD. 08:45 09:00 0.25 5,804 5,896 INTRM1 DRILL REAM T Wash and ream to bottom.5896'MD. No fill. 09:00 12:00 3.00 5,896 5,991 INTRM1 DRILL DDRL P Perform SPR's. Directional Drill from 5896'to 5991'MD. 5606'TVD. ART=.94 hrs,AST=1.05 hrs, ADT=1.99 hrs.Total bit hrs=1.99 hrs. Total jar hrs=33.90. P/U Wt=120k, S/O Wt=94k, ROT WT=105k,TQ on=3k,TQ off=2k, ECD 11.26 ppg, WOB=3-5k, RPM=50, PP=1950 PSI off.Max gas 470 units. 12:00 18:00 6.00 5,991 6,265 INTRM1 DRILL DDRL P Directional Drill from 5991'MD to 6265'MD.5864'TVD.Bring mud weight up from 10.0 ppg to 10.4 ppg. Increasing connection gas seen. ART=2.07 hrs,AST=3.05,ADT=5.12 hrs.Total bir hrs=7.11,Total jar hrs=39.02, P/U Wt=124k,S/O Wt=108k, ROT Wt=114k,TQ on and off=2.5k, ECD=11.49 ppg. 18:00 00:00 6.00 6,265 6,413 INTRM1 DRILL DDRL P Directional Drill from 6265'MDto 6413'(5970'TVD).Bring mud weight up from 10.4 ppg to 10.6 ppg. Increasing connection gas was seen (up to 1133 max). Drill w/2-5k WOB, Rotate 50 rpm w/2.5k ft lbs of torque on and off bottom.ART=2.88 hrs,AST=.76,ADT=3.64 hrs.Total bit hrs=10.75,Total jar hrs=42.66, P/U Wt=125k, S/O Wt=109k, ROT Wt=115k, ECD=11.77 ppg. 12/20/2011 Directional drill 7"hole f/6413'to TD @ 6460'(6008'TVD).TD well w/10.6 ppg mud wt,final ECD's 11.77 ppg while pumping 336 gpm w/2500 psi.Weight up mud system to 10.9 ppg,stand back a stand,continue to circ w/bottom's up gas readings of 1632 units,weight up to 11.1,circ, perform tests to determine correct MW prior to trip, perform short trip to 5420',circ once back on bottom, increase mw to 11.3+ppg, monitor well-static, pump out to 4960', pull to 4866',monitor well static,continue to POOH slow on trip tank f/4866' to 1577'@ midnight. Hole taking proper fill. Page 12 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:45 0.75 6,413 6,460 INTRMI DRILL DDRL P Directional drill 7"hole f/6413'to TD @ 6460'(6008'TVD). TD well w/ 10.6 ppg mud wt,final ECD's 11.77 ppg while pumping 336 gpm w/2500 psi. Drill w/2-5k WOB, Rotate 50 rpm w/2.5k ft lbs of torque on and off bottom.ART=1.15 hrs,AST=0, ADT=1.15 hrs.Total bit hrs=11.9, Total jar hrs=43.81, P/U Wt=125k, S/O Wt=109k, ROT Wt=115k, ECD=11.77 ppg.Max gas 1450 units. 00:45 01:30 0.75 6,460 6,460 INTRMI DRILL CIRC P Circulate bottom's up.obtain SPR's. Continue to circ BU. 1802 units of gas on bottoms from lower ECD's while taking SPR's w/10.6 ppg mud in the hole. 01:30 03:30 2.00 6,460 6,460 INTRM1 DRILL CIRC P Increase mud weight f/10.6 to 10.9 ppg. Pumping 280 gpm w/1950 psi, 35%Totco flow out. 03:30 03:45 0.25 6,460 6,367 INTRM1 DRILL TRIP P Stand back a stand f/6460'to 6367'. Monitor well-appears static after making a top drive connection. 03:45 06:15 2.50 6,367 6,367 INTRM1 DRILL CIRC P Circ 254 gpm w/1750 psi. On bottom's up from pumps off-bottom's up gas readings of 1632 units,weight up to 11.1.After weighted up, background gas around 40 units. Obtain SPR's. 06:15 07:15 1.00 6,367 6,367 INTRM1 DRILL CIRC P Pumps off f/10 minutes,then circ BU pumping 254 gpm w/1675 psi.- -1647 units on bottom's up. 07:15 10:45 3.50 6,367 6,367 INTRM1 DRILL CIRC P Shut down pumps f/14 min,circ pumping 203 gpm w/1280 psi, V ECD's 12.05 ppg, Reciprocate f/ 6367'to 6275', rotate 50 rpm w/2.5k ft lbs of torque.-BU gas 1431 units, repeat above 3 times(20 minutes pumps off and again w/20 minutes pumps off- BU gas 965 units the last time. Monitor well-very slight flow to static. 10:45 12:15 1.50 6,367 5,420 INTRM1 DRILL WPRT P Pump out f/6367'to 5420'. Pumping 148 gpm w/825 psi. 12:15 12:30 0.25 5,420 5,420 INTRM1 DRILL OWFF P Monitorwell-static. 12:30 13:30 1.00 5,420 6,460 INTRM1 DRILL WPRT P Trip in the hole f/5420'to 6360'. Make a top drive connection.Then wash last stand down f/6360'to 6460'(6008'TVD). 13:30 13:45 0.25 6,460 6,460 INTRM1 DRILL OWFF P Monitorwell-static. 13:45 15:45 2.00 6,460 6,460 INTRM1 DRILL CIRC P Circulate BU, pumping 200 gpm w/ 1300 psi.On bottom's up the gas reading was 1540 units. Decision to weight up from 11.1 to 11.3+ppg. 15:45 16:00 0.25 6,460 6,460 INTRM1 DRILL OWFF P Shutdown pumps, monitor well- static. Page 13 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 16:15 0.25 6,460 6,460 INTRM1 DRILL CIRC P SPR's w/MW 11.3+@ 6450'MD (6008'TVD) .#1 Mp 20 spm w/530 psi 30 spm w/750 psi. #2 Mp 20 spm w/530 psi 30 spm w.760 psi 16:15 17:15 1.00 6,460 6,460 INTRM1 DRILL CIRC P Circulate bottom's up. Max gas on BU was 324 units. 17:15 20:00 2.75 6,460 4,860 INTRM1 DRILL TRIP P Pump out of the hole f/6450'to 4960'. Pumping 147 gpm w/825 psi. Pull w/o pumping f/4960'to 4860'. Calculated displacment 8.1 bbls, actual 9.8 bbls. 20:00 20:30 0.50 4,860 4,860 INTRM1 DRILL OWFF P Monitor well f/30 minutes-static. 20:30 22:30 2.00 4,860 2,502 INTRM1 DRILL TRIP P Pull out of the hole slow on elevators f/4860'to 2502'. Hole taking proper fill. 22:30 22:45 0.25 2,502 2,502 INTRM1 DRILL OWFF P Monitor hole for 10 minutes-static. 22:45 00:00 1.25 2,502 1,577 INTRM1 DRILL TRIP P Continue to pull out of the hole f/ 2502'to 1577'. Monitor well on the trip tank.While on trip tank:Calc fill 18.9 bbls,actual 18.75 bbls. 12/21/2011 Monitor well-static,continue to POOH slow on trip tank f/1577'to 449', lay down BHA,test annular and top pipe w/5.5"test joint(250/3500 psi), RU to run 5.5"15.5 ppf L-80 Hyd 563 liner, PJSM, run liner to 6460', circulate and condditon mud f/cement, PJSM on cementing. 00:00 00:15 0.25 1,577 1,577 INTRM1 DRILL OWFF P Monitor well f/10 minutes-static. 00:15 00:30 0.25 1,577 449 INTRM1 DRILL TRIP P Continue trip out of the hole f/1577' to 449'. 00:30 01:30 1.00 449 82 INTRM1 DRILL PULD P Lay down 4"HWDP,jars and Sperry Sun Flex collars to 82'. Break off bit. 01:30 02:15 0.75 82 82 INTRM1 DRILL PULD P Plug into MWD,download MWD. 02:15 03:00 0.75 82 0 INTRM1 DRILL PULD P Continue to lay down the BHA. Calculated fill 31.3 bbls,actual 31.25 bbls for trip f/the 7"window. 03:00 03:15 0.25 0 INTRM1 DRILL PULD P Clean and clear rig floor. 03:15 04:00 0.75 INTRM1 WHDBO BOPE P Rig up to test top pipe rams and annular w/5.5"test joint. Drain stack,pull FMC 6-3/8"wear bushing, install test plug. 04:00 04:30 0.50 INTRM1 WHDBO BOPE P Test the annular to 250 psi low and 3500 psi high.Test top pipe rams (3-1/2"x 6"VBR's)to 250 psi low and 3500 psi high. Hold each test 5 minutes.Chart tests. _ 04:30 05:15 0.75 INTRM1 WHDBO BOPE P Rig down testing equipment,drain stack, install 6.375"ID FMC wear bushing. 05:15 07:30 2.25 INTRMI CASING RURD P Rig up to run 5.5"15.5ppf L-80 Hyd 563 liner. 07:30 07:45 0.25 INTRM1 CASING SFTY P PJSM on running liner. Page 14 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:45 11:00 3.25 0 1,760 INTRM1 CASING RUNL P PU/MU/RIH w/ 5.5" 15.5ppf L-80 Hyd 563 liner:MU Weatherford model 303 float shoe joint,TIW float collar joint,TIW landing collar joint, then joint#4.All of these joints were baker locked. Centralizers installed per plan. Check floats, continue w/ liner.Total of 16 Weatherford 5.5"x 6-1/8"solid centralizers were run. Continue to run 5.5"to jt#42 in the hole.Total length to 1760.91'. Torqued Hyd 563 to 9500 ft lbs. Used Jet lube SealGuard dope. 11:00 12:00 1.00 1,760 1,811 INTRM1 CASING RUNL P Make up TIW"X"-Pak liner hanger and tie back expander per TIW rep. 12:00 16:15 4.25 1,811 4,821 INTRM1 CASING RUNL P Run in the hole w/5.5"15.5 ppf L-80 Hyd 563 liner on Weatherford 4" S-135 dp f/1811'to 4821'. Fill every 10 stands,pumping 2 bpm w/625 psi.At 4821': PU wt 96k,SO wt 87k. Rotate @ 5 rpm w/1.5k ft lbs of torque. MU TIW cement head w/5'and 10' pup joint,then lay back down to the pipe shed. 16:15 19:15 3.00 4,821 6,460 INTRM1 CASING RUNL P Continue run in the hole w/5.5"15.5 ppf L-80 Hyd 563 liner on Weatherford 4"S-135 dp f/4821'to 6412'. Fill every 10 stands.Wash down stand#50 from 6412'to 6460', pumping 3 bpm w/650 psi. PU wt 115k, SO wt 95k.Calculated displacment 37.1 bbls, actual 30.25 bbls. 19:15 21:00 1.75 6,460 6,460 INTRM1 CASING CIRC P Circulate bottom's up while recip pipe / f/6460'to 6442'(18').Max gas 1977 V units.Circulate 312 bbls until MW in and out 11.3 ppg. Circulate @ 3 bpm w/650 psi. 21:00 21:30 0.50 6,460 6,460 INTRM1 CEMEN-RUNL P Shut down pumps.Stand back stand #50. Pick up a single of 4"drill pipe from the pipe shed. Make up TIW cement head,then tag bottom of the hole @ 6460'while pumping 3 bpm w/650 psi. 21:30 22:45 1.25 6,460 6,460 INTRM1 CEMEN-CIRCP Continue to circulate while conditioning mud for cement job. Stage pumps up to 4 bpm w/850 psi w/no losses. Circulated 222 bbls at 4 bpm,then staged up to 5 bpm w/ 1050 psi.Saw a 10 bbl loss in 10 minutes,decided to reduce pump rate to 4.5 bpm w/950 psi.Saw a 5 bbl loss,so slowed pumps back to 4 bpm 850 psi with no losses. Continued to circulate and condition pumping 4 bpm. Reciprocated pipe. PU wt 112k, SO 93k. Page 15 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:45 23:00 0.25 6,460 6,460 INTRM1 CEMEN-SFTY P Pre job meeting on cement job while continuing to condition mud. 23:00 00:00 1.00 6,460 6,460 INTRM1 CEMEN"CIRC P Continue to circulate and reciprocate 6460'to 6442'(18') while Dowell cementers prepare for batch mixing 37 bbls of 15.8 ppg cement, preparing MudPush @ 12 ppg and CW100 @ 8.35 ppg. Circulate a total of 980 bbls prior to the cement job. Properties before: MW 11.3+, MW out 10.6 ppg,Vis 55, PV/YP: 18/32, 10 min gels 11. Mud properties after:MW in and out 11.4 ppg,vis 50, PV/YP:18/27, 10 min gels 10. 12/22/2011 Circ prior to cement,cement 5.5"liner,set TIW"X-Pak"liner hanger,expand liner top, test,circ out CW100 and MudPush II,monitor well,fix air boot, L/D 54 joints of 4"dp, POOH w/TIW running tool, LID tool,change top pipe rams to 2-7/8"x 5", RU, perform 14 day Full BOPE test w/2-7/8", 3-1/2",and 4"test joints.Witness of test waived by AOGCC insp Bob Noble. 00:00 00:15 0.25 6,460 6,460 INTRM1 CEMEN'CIRC P Continue to circulate and reciprocate 6460'to 6442'(18') while Dowell cementers prepare for batch mixing 37 bbls of 15.8 ppg cement, preparing MudPush @ 12 ppg and CW100 @ 8.35 ppg. Circulate a total of 980 bbls prior to the cement job. PU wt 112k, SO 93k. Properties before:MW 11.3+, MW out 10.6 ppg,Vis 55, PV/YP: 18/32, 10 min gels 11. Mud properties after: MW in and out 11.4 ppg,vis 50, PV/YP:18/27, 10 min gels 10. Shut down, line up dowel)to pump. 00:15 00:45 0.50 6,460 6,460 INTRM1 CEMEN"PUCM P Dowell pumped entire cement job including displacement: Pumped 5 bbls CW100,tested lines to 5000 0 �+ psi-good, con't pumping CW100 @ 02/ 3.5 bpm w/1000 psi f/total of 20.3 bbls, pumped 20.2 bbls of 12 ppg MudPush II @ 3.6 bpm w/1070 psi, follow w/30.5 bbls of UniSlurry(15.8 IAljt/ ppg,yield 1.16 cuft/sx,5.093 gal/sx water).Cement was pumped @ 3.5 bpm w/1300 to 330 psi final. Page 16 of 30 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:45 01:15 0.50 6,460 6,458 INTRM1 CEMEN"DISP P Drop TIW DP wiper plug. Dowell follow w/10 bbls of water, pumping 2.4 bpm w/87 to 73 psi,then Dowell continued displacing w/11.3 ppg mud.Started displacement @ 4 bpm w/700 psi,slowed rate to 2 bpm prior to latch up of the liner wiper plug. Saw pressure increase f/200 psi to 1100 psi @ latch up. Increased rate to 3.4 bpm w/460 psi initial. Slowed to 2.1 bpm 7.2 bbls prior to bumping plug.Quit reciprocating pipe once at 2 bpm. Final pressure was 800 psi, bumped j plug w/1700 psi.CIP @ 0121 hrs V 12-22-2011. Held f/3 minutes. Bleed off pressure to check floats.bled back.5 bbls. Floats holding. 01:15 01:45 0.50 6,458 6,458 INTRMI CEMEN'OTHR P Follow TIW procedure to set liner hanger a expand liner top: Do II pumping m w shear ring shift with pressure drop f/2700 psi to 2000 psi, kept pumping to reach 4500 psi.Stopped and held 4500 psi f/10 minutes. Bled off pressure(bled back 1.4 bbls). Pulled 50k over(pulled to 163k)to ensure hanger was set. 01:45 02:00 0.25 6,458 6,458 INTRM1 CEMEN-PRTS P Test annulus w/top pipe rams to 1000 psi f/5 minutes-good.Took 1 bbl to pressure up. 02:00 02:30 0.50 6,458 6,458 INTRM1 CEMEN-OTHR P Remove TIW cement head, lay down same.Make a top drive connection. Put pipe in neutral weight,pull 5k over. Rotate 20 rounds with 1k ftlbs of torque.Slack off 2'and wait 5 minutes to allow fluid in tool to vent and stroke downward.Apply 200 psi while picking up and observe pressure drop when tool clears liner top. Good indication. Pick 20'while pumping. PU wt 90k. 02:30 03:15 0.75 6,458 4,659 INTRM1 CEMEN'CIRC P Start off pumping 11.3 ppg mud @ 8 bpm w/980 psi for 50 bbls,then slow rate to 3 bpm w/290 psi,while watching shakers for CW100(8.35 ppg)and MudPush II (12 ppg)and cement(15.8 ppg). Saw CW100 and MudPush II circulated from the hole. / Did not see any cement circulated out. Dumped 47 bbls to the rock washer. Once a bottom's up+was circulated, increased rate back to 8 bpm w/1050 psi for another bottom's up. Pumped 212 bbls total. 03:15 03:30 0.25 4,659 4,659 INTRMI DRILL PRTS P Test 5.5"liner and 7"casing to 1500 psi f/5 minutes.Good test. Page 17 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 04:00 0.50 4,659 4,659 INTRM1 DRILL OWFF P Observe well to be static f/15 minutes prior to pulling out of the hole. Blow down top drive. 04:00 04:30 0.50 4,659 4,649 INTRM1 DRILL PULD P Lay down a single and two 4"pup joints(5'&10'). 04:30 05:30 1.00 4,649 4,649 INTRM1 RIGMN7 RGRP T Repair/replace air boot on riser to flow line.Air boot had leaked 2.5 gallons of mud.into cellar area of rig because of leak. Notifications were made, PIR issued. 05:30 06:45 1.25 4,649 2,967 INTRM1 DRILL PULD P POOH f/4659'to 2967', Laying down 54 joints of Weatherford 4"drill pipe 06:45 08:00 1.25 2,967 31 INTRM1 DRILL TRIP P Stand back 31 stands of 4"drill pipe. 08:00 08:15 0.25 31 0 INTRM1 DRILL PULD P Lay down TIW running tools. 08:15 08:30 0.25 0 0 INTRM1 DRILL OTHR P Clear and clean rig floor. 08:30 09:00 0.50 0 0 INTRM1 CEMEN-PULD P Pick up,then break and lay down a single and two 4"pup joints(5'& 10'). Make up stack washing tool. 09:00 09:45 0.75 0 0 INTRM1 WHDBO OTHR P Pull FMC wear bushing. Flush stack. Blow down the top drive,kill line and choke liine. 09:45 10:00 0.25 0 INTRM1 WHDBO OTHR P Install FMC test plug. 10:00 10:15 0.25 INTRM1 WHDBO SFTY P Pre job safety meeting on changing top pipe rams f/3.5"x 6"to 2-7/8"x 5". 10:15 12:00 1.75 INTRM1 WHDBO NUND P Change top pipe rams to 2-7/8"x 5" VBR's. 12:00 12:15 0.25 INTRM1 WHDBO SFTY P Pre job safety meeting on changing top pipe rams f/3.5"x 6"to 2-7/8"x 5". 12:15 13:00 0.75 INTRM1 WHDBO NUND P Finish changing top pipe rams to 2-7/8"x 5"VBR's. 6? 13:00 13:45 0.75 INTRM1 WHDBO RURD P Riq up to test BOPE.Will perform ,`✓� two week test.Test w/2-7/8",3-1/2" 1-6; and 4"test joints.AOGCC rep Bob Noble waived witness of test. 13:45 18:00 4.25 INTRM1 WHDBO BOPE P Test BOPE.Witness of test waived by AOGCC inspector Bob Noble.Test w/4"test joint first,testing all kill line valves,choke line valves, and choke manifold, Demco mud line valve,floor safety valve, IBOP, upper and lower IBOP on top drive.Tested to 250 psi low and 3500 psi high. Tested annular to 250 psi low and 2500 psi high. Held each test 5 minutes. Chart tests. 18:00 18:30 0.50 ' INTRM1 WHDBO BOPE P Change out the 4"test joint. Install 2-7/8"test joint.Test annular to 250 psi low and 2500 psi. Held each test 5 minutes. Charted test.Attempt to test upper 2-7/8"x 5"VBR's-no test. Functioned three times,still not closing on test joint. Decision to open doors and check ram rubbers. Page 18 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 21:30 3.00 INTRM1 WHDBO BOPE T Open doors on the top pipe rams- looked good, brand new packers. Correct 2-7/8"x 5"size.Close doors,functioned on 2-7/8"test joint several times.Attempted to test,still leaking. Decision to continue testing bottom pipe rams 250 psi low and 3500 psi high. 21:30 23:00 1.50 INTRM1 WHDBO BOPE P Change out test joint f/2-7/8"to 3.5". With 3-1/2"test joint,test annular to 250 psi low and 3500 psi high,test bottom pipe rams,2-7/8"IBOP and floor safety valve to 250 psi low and 3500psi. Held each test 5 minutes, chart tests. 23:00 00:00 1.00 INTRM1 WHDBO BOPE P Break down 2-7/8"floor valves and drain BOP stack. 12/23/2011 Continue with BOP test, , install wear bushing/blow down, PJSM, PU/MU BHA#5(4-3/4"bit-small tools, MU BHA,shallow test, PU/MU 81 joints of 2-7/8"Weatherford dp, run 4"dp f/derrick to 4636',slip and cut drill line, RIH slow,tag drilllable packoff @ 4692'. 00:00 00:15 0.25 INTRM1 WHDBO SFTY T Pre job safety meeting on changing top set of pipe rams, again. 00:15 01:15 1.00 INTRM1 WHDBO NUND T Change out the top pipe rams f/ 2-7/8"x 5"VBR's(CPAI)to another set of 2-7/8"x 5"VBR's(Doyon). 01:15 04:45 3.50 INTRM1 WHDBO BOPE P Fill stack with water. Continue testing.Test top pipe rams to 250 psi low and 3500 psi high. Change out test joint to 2-7/8".Test top pipe rams and annular to 250 psi low and 3500 psi high.Test blind rams. Change test joint to 4".Test top pipe rams and annular to 250 psi low and /�,�P 3500 psi high.All tests were held 5 �`"' minutes each,charted tests.Test accumulator: Full charge 3000 psi, after closing 1900 psi,200 psi build up in 39 seconds,full charge in 175 seconds.Avg 5 bottles of nitrogen 2000 psi. 04:45 05:30 0.75 INTRM1 WHDBO BOPE P Rig down testing equipment. Drain stack. Install 6-3/8"FMC wear bushing. Blow down choke manifold, choke and kill lines. 05:30 05:45 0.25 INTRM1 DRILL SFTY P Pre job safety meeting on picking up and making up slim hole BHA(BHA #5). 05:45 08:00 2.25 INTRM1 DRILL RURD P Rig up double stack casing tongs, change elevators, adjust dog collar clamp. 08:00 08:45 0.75 INTRM1 DRILL OTHR T Wait on Sperry Sun to locate crossover for the BHA.SIM Ops: Install spare air boot on the BOP stack for the riser. 08:45 09:15 0.50 INTRM1 DRILL SFTY P Pre job safety meeting on picking up BHA. Page 19 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:15 11:00 1.75 0 80 INTRMI DRILL PULD P Pick up/Make up small BHA w/ 4-3/4"bit. 11:00 12:30 1.50 80 80 INTRM1 DRILL PULD P Upload Sperry Sun MWD @ 80'. 12:30 14:30 2.00 80 289 INTRM1 DRILL PULD P Continue to pick up BHA#5 f/80'to top of the DC's @ 289'. 14:30 14:45 0.25 289 289 INTRM1 DRILL DHEQ P Shallow pulse test MWD. Pumping 103 gpm w/1300 psi, increased rate to 120 gpm w/1650 psi.Good test. Blow down the top drive. 14:45 20:15 5.50 289 2,850 INTRM1 DRILL PULD P Single in the hole w/Weatherford 2-7/8"HT PAC drill pipe f/289'to 2850'. PU wt 56k, SO wt 60k. 20:15 21:15 1.00 2,850 4,636 INTRM1 DRILL TRIP P Trip in the hole w/4"drill pipe ft 2850' to 4636'. PU wt 78k, SO wt 80k. 21:15 21:30 0.25 4,636 4,636 INTRM1 RIGMNT SFTY P Pre job safety meeting on slip and cut drilling line. 21:30 23:00 1.50 4,636 4,636 INTRM1 RIGMNT SLPC P Slip and cut 78'of 1-1/4"drill line. 23:00 00:00 1.00 4,636 4,692 INTRM1 DRILL TRIP P Make a top drive connection. Break circulation @ 4636', pumping 76 gpm w/1000 psi,81 gpm w/1170 psi, pumping 144 gpm w/2900 psi. Shut down pumps and slack off to tag drillable packoff bushing @ 4692.42'(right on tally depth). PU wt 81k, SO wt 80k. ,� .� 12/24/2011 5 'L Drill drilllable packoff @ 4692', RIH,tag cement @ 6350', POOH to 6329',circ Surf-Surf,Test 3 "liner and 7"casing to 3500 psi f/30 min.-good, charted test, Drill cement @ f/6350'to the wiper rubbers and then landing collar @ 6369',drill cement to FC @ 6412',more cement to FS @ 6458',drill 2'of cement in the rat hole,then 20'of 4-3/4"hole to 4880'.CBU, perform FIT to 16 ppg EMW, Directional drill 4-3/4"production hole f/6480'to 6506'.Observed 2218 units of gas and increase in flow out.CBU, monitor well-static,con't drilling while weighting up f/11.5+to 11.7+,drilled f/6506'to 6521'. 00:00 00:30 0.50 4,692 4,693 INTRMI CEMEN"DRLG P Drill the drillable packoff in the liner top @ 4692'. Pumping 140 gpm w/ 3000 psi. Rotate 40 rpm w/1k ft lbs of torque.WOB 2-3k. Ream through two more times. Blow down top drive. 00:30 01:30 1.00 4,693 6,350 INTRM1 DRILL TRIP P Trip in the hole w/4"drill pipe f/4692' to 6350'.Tagged up on cement. Pull back to 6329'. 01:30 02:45 1.25 6,350 6,350 INTRM1 DRILL CIRC P Rig up to circulate. Circulate surface to surface, pumping 139 gpm w/ 3000 psi. PU wt 105k,SO wt 94k with pumps on. 02:45 03:00 0.25 6,350 6,350 INTRM1 DRILL RURD P Rig up to perform casing test. 03:00 03:45 0.75 6,350 6,350 INTRM1 DRILL PRTS P Test the 7"26 ppf K-55 casing and the 3-1/2"L-80 Hyd 563 liner to 3500 psi f/30 minutes. Chart test. Good test. Page 20 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:45 04:30 0.75 6,350 6,350 INTRM1 DRILL WPRT P Pull out of the hole 3 stands. Make a top drive connection,then pump 126 gpm w/2550 psi, pick up to the crack of the 4th stand.This was to confirm MWD gamma tools were working properly.All good. PU wt 110k, SO wt 90k, Rot wt 95k. RIH to 6329'. 04:30 08:00 3.50 6,350 6,460 INTRM1 CEMEN-DRLG P Make a top drive connection,while pumping 139 gpm w/3000 psi, wash/ream down to the top of cement @ 6350',then drill cement, wiper plugs, landing collar @ 6369', drill cement to FC @ 6412', more cement to FS @ 6458',drill 2'of cement in the rat hole to TD of the 7" hole @ 6460'. 08:00 12:00 4.00 6,460 6,472 INTRM1 DRILL DDRL P Drill 12'of new hole 4-3/4"f/6460'to 6472'. Drilled w/3-5k WOB, Pumping 140 gpm w/3000 psi,rotate 45 rpm w/2k ft lbs of torque on and off bottom.ART= 1.84 hrs,AST=0, ADT 1.84 hrs.Total bit hrs 1.84.Jar hrs 1.84. PU wt 110k,SO wt 95k, Rot wt 100k. 12:00 13:15 1.25 6,472 6,480 INTRM1 DRILL DDRL P Drill 8'more of new hole 4-3/4"f/ 6472'to 6480'.Total of 20'of new 4-3/4"hole. Drilled w/3-5k WOB, Pumping 140 gpm w/3000 psi, rotate 45 rpm w/2k ft lbs of torque on and off bottom.ART=1.25 hrs, AST=0,ADT 1.25 hrs.Total bit hrs 3.09.Jar hrs 3.09. PU wt 110k,SO wt 95k, Rot wt 100k. 13:15 13:45 0.50 6,480 6,480 INTRM1 DRILL CIRC P Circulate bottom's up prior to formation test,pumping 140 gpm w/ 2950 psi. PU wt 98k,SO wt 110k, Rot wt 98k. 13:45 14:00 0.25 6,480 6,325 INTRM1 DRILL RURD P Stand back a stand to 6325'. Blow down the top drive. Rig up to test the formation. 14:00 14:30 0.50 6,325 6,480 INTRM1 DRILL FIT P Perform formation integrity test to 16 ppg.Applied 1400 psi w/11.5 MW in the hole. 5-1/2"shoe @ 6458'MD (6007'TVD). Pumping 5 spm. Charted test, recorded info on pressure inegrity form w/the casing test. 14:30 14:45 0.25 6,325 6,325 PROD1 DRILL RURD P Rig down testing equipment. Blow down the kill line. Page 21 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:45 19:00 4.25 6,480 6,506 PROD1 DRILL DDRL P Make a top drive connection. Continue to drilled 4-3/4"hole f/6480' to 6506'. Drill w/4-5k WOB, Pumping 149 gpm w/3250 psi,39% Totco flow out, rotate 45 rpm w/2k ft lbs of torque on, and 1.5k ft lbs off bottom.ART=4.25 hrs,AST=0, ADT 4.25 hrs.Total bit hrs 7.34.Jar hrs 7.34. PU wt 110k,SO wt 95k, • Rot wt 100k.Observed a flow increase of 8%on Totco. Epoch/Canrig gas increased from background of 13 units to 2218 units. 19:00 19:15 0.25 6,506 6,506 PROD1 DRILL OWFF P Stopped drilling @ 6506'. Picked up off bottom. Shut down pump.Totco flow reading 15%w/no pumps. Observed well to be flowing. 19:15 20:15 1.00 6,506 6,506 PROD1 DRILL CIRC P Turned pump back on, pumping 150 gpm w/3100 psi.Circulate bottom's up. Max gas 392 units. 20:15 20:30 0.25 6,506 6,506 PROD1 DRILL OWFF P Shut down pump,flow check well- static. 20:30 20:45 0.25 6,506 6,506 PROD1 DRILL CIRC P Obtain slow pump rates w/11.5 ppg mud weight @ 6500'(6046'TVD).#1 MP: 10 spm w/660 psi,20 spm w/ 1430 psi.#2 MP: 10 spm w/690 psi,20 spm w/1440 psi. Decision made to increase mud weight f/11.5+to 11.7+while drilling. 20:45 00:00 3.25 6,506 6,521 PROD1 DRILL DDRL P Directional drill 4-3/4"production hole f/6506'to 6521'. Drilled w/4-5k WOB, Pumping 149 gpm w/3250 psi,39%Totco flow out, rotate 45 rpm w/2k ft lbs of torque on, and 1.5k ft lbs off bottom.ART=2.22 hrs, AST=0,ADT 2.22 hrs.Total bit hrs 9.56.Jar hrs 9.56. PU wt 110k,SO wt 95k, Rot wt 100k. 12/25/2011 Directional drill 4-3/4"production hole f/6521'to 6887'(6369'TVD). 00:00 06:00 6.00 6,521 6,649 PROD1 DRILL DDRL P Directional drill 4-3/4"production hole f/6506'to 6649'(6166'TVD). Drilled w/2-5k WOB, Pumping 149 gpm w/ 3350 psi, 39%Totco flow out, rotate 50 rpm w/2k ft lbs of torque on, and ✓ 1.5k ft lbs off bottom.ART=5.08 hrs, AST=0,ADT 5.08 hrs.Total bit hrs 14.64.Jar hrs 14.64. PU wt 110k, SO wt 98k, Rot wt 103k. Page 22 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 6,649 6,745 PROD1 DRILL DDRL P Directional drill 4-3/4"production hole f/6649'to 6745'(6248'TVD). Drilled w/2-5k WOB, Pumping 131 gpm w/ 3000 psi, 39%Totco flow out, rotate 50 rpm w/2k ft lbs of torque on, and 1.5k ft lbs off bottom.ART=4.66 hrs, AST=0,ADT 4.66 hrs.Total bit hrs 19.3.Jar hrs 19.3. PU wt 110k,SO wt 98k, Rot wt 103k. Max gas 133 units. Pumped a hi vis 20 bbl sweep while drilling @ 6718' w/no iincrease in cuttings when reurned to shakers. 12:00 00:00 12.00 6,745 6,887 PROD1 DRILL DDRL P Directional drill 4-3/4"production hole f/6745'to 6887'(6369'TVD). Drilled w/2-5k WOB, Pumping 140 gpm w/ 3300 psi, 39%Totco flow out, rotate 50 rpm w/2k ft lbs of torque on, and 1.5k ft lbs off bottom.ART= 11.65 hrs,AST=0,ADT 11.65 hrs.Total bit hrs 30.95.Jar hrs 30.95. PU wt 111k, SO wt 99k, Rot wt 105k. Max gas 132 units. 12/26/2011 Directional drill 4-3/4"production hole f/6888"to 6940'(6411'TVD), monitor well-static, CBU x3,wiper trip out to 6420',monitor well-static, RIH to 6891', Precautionary reamn to TD @ 6940',while CBU, noticed mud losses.Mixed and pumped 23.6 bbls of a LCM pill around the bit.Tripped to 6940'to 6411'working tight hole until clean. Monitor hole @ 6411',slight losses. Mix another pill to lay in the 5-1/2"csg x 4"dp annulus while tripping. 00:00 06:00 6.00 6,887 6,913 PROD1 DRILL DDRL P Directional drill 4-3/4"production hole f/6887'to 6913'(6388'TVD). Drilled w/2-7k WOB, Pumping 136 gpm w/ 3200 psi,39%Totco flow out, rotate 50 rpm w/2k ft lbs of torque on, and 1.5k ft lbs off bottom.ART=4.68 hrs, AST=0,ADT 4.68 hrs.Total bit hrs 35.63.Jar hrs 35.63. PU wt 115k, SO wt 100k, Rot wt 108k. Max gas 48 units. 06:00 10:15 4.25 6,913 6,940 PROD1 DRILL DDRL P Directional drill 4-3/4"production hole f/6913'to 6940'(66411'TVD). Drilled w/2-5k WOB, Pumping 136 gpm w/ 3200 psi, 39%Totco flow out, rotate 50 rpm w/2k ft lbs of torque on, and 1.5k ft lbs off bottom.ART=4.31 hrs, AST=0,ADT 4.31 hrs.Total bit hrs 39.94.Jar hrs 39.94. PU wt 115k, SO wt 100k, Rot wt 108k. Max gas 27 units. 10:15 10:30 0.25 .6,940 6,940 PROD1 DRILL CIRC P Obtain SPR's.Take final MWD survey. 10:30 10:45 0.25 6,940 6,940 PROD1 DRILL OWFF P Monitor well-static. Page 23 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:45 12:00 1.25 6,940 6,800 PROD1 DRILL CIRC P While circulating 3 BU, rotate 40 rpm w/2k ft lbs of torque,pumping 130 gpm w/3000 psi. Stand back a stand every 30 minutes. Depth @ 1200 hrs 6800'. PU wt 115k, SO wt 100k, Rot wt 108k.Torque on and off=2k ft lbs. 12:00 14:30 2.50 6,800 6,420 PROD1 DRILL WPRT P While circulating 3 BU, rotate 40 rpm w/2k ft lbs of torque, pumping 130 gpm w/3000 psi.Stand back a stand every 30 minutesf/6800'to 6420'. PU wt 115k, SO wt 100k, Rot wt 108k.Torque on and off=2k ft lbs. 14:30 15:00 0.50 6,420 6,420 PROD1 DRILL OWFF P Monitor well-static. 15:00 15:30 0.50 6,420 6,420 PROD1 RIGMNT SVRG P Service top drive while continuing to monitor well. 15:30 16:00 0.50 6,420 6,891 PROD1 DRILL WPRT P Trip in the hole on elevators f/6420' to 6891'. 16:00 16:15 0.25 6,891 6,940 PROD1 DRILL WASH P Precautionary wash and ream f/ 6891'to 6940'. 16:15 17:15 1.00 6,894 6,940 PROD1 DRILL CIRC P Circulate BU x2. Pumping 130 gpm w/3200 psi. Rotate 20 rpm w/2k ft lbs of torque. PU wt 115k,SO wt 97k, Rot wt 108k. Rot torque 2k ft lbs. 17:15 18:00 0.75 6,940 6,940 PROD1 DRILL CIRC P Observed losses of 22 bph while pumping @ 130 gpm, reduced pump rate to 100gpm with same losses, slowed to 86 gpm with losses of 9 bph. Mixed a LCM pill consisting of 31.75 ppb LCM material(20 ppb safe carb 40,5 ppb DynaRed fine, 5 ppb DynaRed med, 1.75 ppb Nut plug fine. Pumped 23.6 bbl pill,spotted in open hole. Shut down. Calculated losses while pumping were 39.25 bbls. 18:00 18:15 0.25 6,940 6,891 PROD1 DRILL TRIP P Pick up stand#44,break and blow down the top drive. 18:15 18:30 0.25 6,891 6,891 PROD1 DRILL OWFF P Blow down the top drive.Monitor well-slight losses. 18:30 22:15 3.75 6,891 6,411 PROD1 DRILL TRIP P Pull out of the hole on elevators f/ 6891'to 6411'. Pulling 10-12k over f/ 6777'to 6540'.Worked and wiped out all tight spots several times. PU wt was 115-110k,SO wt 97k. Overpulled to 125k on weight indicator. Calculated displacement 2.7 bbls,actual 11.5. Lost 8.8 bbls, loss rate approx 3 bph.Approx 4.3 bbls of LCM pill left in the 5-1/2" liner. Page 24 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:15 00:00 1.75 6,411 6,411 PROD1 DRILL OWFF P 'Monitor well f/losses. Lost 2.33 bbls in an hour,but the last 1/2 hr was static(1.6 gallons). Mix another LCM pill(same concentrations as above) to place in the 5-1/2"liner x dp annulus f/precautionary losses while running the 3-1/2"liner.Will pump 13.5 bbls and place outside of the bit. 12/27/2011 Continue circulate at 6420'at 2 BPM. Spot 13.5 BBL LCM pill. Monitor well. POOH on elevators. Lay down 2 7/8" PAC pipe. Breakout&lay down drilling assembly. Rig up running equipment. Make up 3 1/2"liner assembly.TIH picking up singles of 3 1/2"PH-6 pipe from shed. Circulate bottoms up at the 5 1/2"liner top at 4679'.Monitor well. Continue TIH with liner to 5330'MD. 00:00 00:15 0.25 6,411 6,411 PROD1 DRILL SFTY P Pre job safety meeting.Lost 8.85 bbls of mud yesterday pulling f/ 6940'to 6411'. 00:15 00:45 0.50 6,411 6,411 PROD1 DRILL CIRC P Pump 20 spm w/1500 psi, rotate 3=20 rpm w/2k ft lbs of torque. Spot 13.5 bbl LCM pill outside of the bit in the annulus @ 6411'. 00:45 01:00 0.25 6,411 6,411 PROD1 DRILL OWFF P Monitor well-slight losses. Blow down the top drive. 01:00 04:00 3.00 6,411 2,851 PROD1 DRILL TRIP P Pull out of the hole slow f/6411'to top of the 5-1/2"liner @ 4679', pull a little faster after in the 7"f/4679'to 2851'. Lost 6.5 bbls while pulling the 4"drill pipe f/6411'to 2851'. 04:00 04:15 0.25 2,851 2,851 PROD1 DRILL OWFF P Monitor well-slight losses. 04:15 04:45 0.50 2,851 2,851 PROD1 DRILL RURD P Rig up tongs and tools to lay down the 2-7/8"drill pipe and BHA. 04:45 05:00 0.25 2,851 2,851 PROD1 DRILL SFTY P Pre job safety meeting on laying down small drill pipe. 05:00 09:00 4.00 2,851 285 PROD1 DRILL PULD P POOH laying down the 2-7/8"drill pipe f/2851'to 285'. 09:00 10:00 1.00 285 0 PROD1 DRILL PULD P Lay down the BHA f/285'. 10:00 10:45 0.75 0 0 PROD1 DRILL PULD P Plug in,download MWD assembly. 10:45 12:00 1.25 0 0 PROD1 DRILL PULD P Continue breakout&lay down BHA. Inspect&grade bit to 1/2/CT/S/X/I/NO/TD Crew Change 12:00 12:30 0.50 0 0 PROD1 DRILL PULD P Send tools out.Clean&clear rig floor. 12:30 13:15 0.75 0 0 PROD1 CASING RURD P Pull tools to rig floor. Rig up power tongs for liner run. 13:15 13:30 0.25 0 0 COMPZ CASING SFTY P Held PJSM with crew,casing hand, and BOT rep. Discuss safety& hazard recognition issues. Discuss procedure to make up and run 3 1.2" liner assembly. 13:30 14:30 1.00 0 0 COMPZ CASING RNCS P Make up shoe track assembly as per detail. Fill shoe track&check floats. Page 25 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 16:15 1.75 0 682 COMPZ CASING RNCS P Continue RIH with liner. Make up ZXP liner top packer, and flexlock liner hanger. Mix and add PAL mix for liner top.Allow 30 minutes for setting time. Make up running tool assembly. Total liner BHA length= 682.01'. 16:15 17:00 0.75 682 713 COMPZ CASING RNCS P Make up first joint of 3 1/2"PH-6 pipe. Fill liner, and pump 10 BBLS. UP WT=35K, SO WT=39K. 17:00 22:00 5.00 713 4,679 COMPZ CASING RNCS P Continue RIH with 3 1/2"liner to top of 5 1/2"liner at 4679',picking up singles from shed. Observed proper displacement. 22:00 22:30 0.50 4,679 4,679 COMPZ CASING CIRC P Make up XO,and circulate bottoms up at 4 BPM-750 PSI.Work shoe into top of 5 1/2"liner washing top of liner. UP WT=75K,SO WT=75K, ROT WT=75K. 15 RPM's-1K TQ. Blow down Top drive. Monitor well- static. 22:30 00:00 1.50 4,679 5,330 COMPZ CASING RNCS P Conitnue RIH with 3 1/2"liner assembly from 4679'-5330'. Observed no issues with 3 1/2"liner assembly going through the 5 1/2" liner top. Observed proper displacement.Crew change 12/28/2011 Continue RIH with 3-1/2"liner on DP to TD. Cement with 15 BBLs GasBlok cmt. Release from liner and POH. Begin running 3-1/2"completion. 00:00 01:15 1.25 5,330 6,450 COMPZ CASING RNCS P Continue RIH with 3-1/2"liner to 6450'MD. 01:15 02:30 1.25 6,450 6,450 COMPZ CASING CIRC P Circulate BU at the 5-1/2"liner shoe. Pump at 4 BPM @ 1175 PSI. PU= 97K,SO=85K, ROT=97K, ROT @ 10 RPM,TQ=2K ft-lbs. 02:30 03:15 0.75 6,450 6,865 COMPZ CASING RNCS P Continue RIH with 3-1/2"liner to 6865'MD'. Lost 15K down wt. 03:15 05:00 1.75 6,865 6,922 COMPZ CASING WASH P RU and wash down from 6865'to 6922'MD,2.5 BPM @ 850 PSI. 05:00 05:30 0.50 6,922 6,922 COMPZ CEMENT PULD P Blow down top drive and RU cement head. 05:30 08:15 2.75 6,922 6,940 COMPZ CEMENT WASH P Wash down from 6922' to 6940'MD, 2. BPM @ 1000 PSI. 08:15 10:15 2.00 6,940 6,940 COMPZ CEMENT CIRC P Circulate and condition mud, 3 BPM @ 1200 PSI. 10:15 11:00 0.75 6,940 6,940 COMPZCEMEN-CMNT P RU Schlumbergercementers. Pump 5 BBL 12.5 PPG MudPush and PT lines to 4500 PSI. Pump 10.7 BBL ►, MudPush, SD and drop plug. Pump 3 t 15 BBLS of 15.8#GASBLOK1 , Cement,8 BBL H2O,43 BBL mud. Bump plug at calculated volume of 50.1 BBL. Pressured to 4000 PSI. Bled off pressure to test floats. Floats ckd OK. Page 26 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 12:15 1.25 6,940 6,937 COMPZ CEMEN-CMNT P PU 5'on cementing string and pressure up to 1000 PSI. Bleed pressure. Liner tool didn't release. Slack off and line up with cement pumps to pressure up to 4500 PSI. Bled off. Line up with rig pumps and pressure up to 500 PSI. PU 9'and observe pressure drop. Released from hanger. Note liner moved up 3'. 12:15 13:45 1.50 6,937 6,900 COMPZ CEMEN"CIRC P PU to 6900'and circulate 280 GPM @ 2100 PSI. 13:45 14:45 1.00 6,900 6,900 COMPZ CEMEN-PULD P L/D Cement Head. Pump dry job and blowdown top drive. Lay down tools from floor. 14:45 20:00 5.25 6,900 0 COMPZ DRILL PULL P POH with 3-1/2"PH6 cementing string and liner running tool. 20:00 20:30 0.50 0 0 COMPZ WHDBO BOPE P Drain BOP stack and pull wear bushing. Set test plug. 20:30 20:45 0.25 0 0 COMPZ WHDBO BOPE P PJSM proior to C/O and test upper rams 20:45 22:45 2.00 0 0 COMPZ WHDBO BOPE P Change upper pipe rams to 3.5"X 6" VBR's. Test same with 3.5"test joint to 250 PSI low and 3500 PSI _high for 5 min on chart. 22:45 23:00 0.25 0 0 COMPZ RPCOM PULD P RU tubing tongs. 23:00 23:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM for running completion 23:15 00:00 0.75 0 47 COMPZ RPCOM RCST P RIH with stinger and tubing to 47'. 12/29/2011 Continue running 3-1/2"completion. PU SSSV w/control line. Tag up @ 4871'MD. Wk'd free and cont.to 5673'.Tag up again. Circ @ 1 BPM and wk'd free. Cont RIH to liner top @ 6277'. Swap mud to brine. Space out, land tubing hanger and PT. 00:00 07:00 7.00 47 4,871 COMPZ RPCOM RCST P Continue RIH with 3-1/2"completion. PU SSSV, MU control line and test to 5000 PSI. Continue in hole to 4871'MD. 07:00 11:30 4.50 4,871 5,673 COMPZ RPCOM RCST P Tag up at 4871'MD. Worked pipe by turning 1/4 turn and slacking off. Cont RIH but hanging up every 30'. Had to turn pipe 1/4 turn at times and cont in hole. At 5673 would not go. 11:30 15:15 3.75 5,673 6,274 COMPZ RPCOM RCST P Make up x-over to circulate to free tubing. Circ at 1 BPM @ 400 PSI and worked pipe. Put 1/2 wrap into string and after working finallwent down. PU 58k, SO 63K. Continue RIH with completion to NO/GO at 6277'. 15:15 15:45 0.50 6,274 6,274 COMPZ RPCOM RCST P RU to pump. RIH and locate liner top @ 6262'MD pumping at 1 BPM @ 400 PSI. SD pumps, bled off and RIH to tag NO/GO @ 6877'. Pull out of liner top and rig up to displace well to brine. Page 27 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:45 18:00 2.25 6,274 6,274 COMPZ RPCOM CIRC P Displace well to 11.6 ppg brine @ 4 BPM. Pumped 24 BBL brine with SafeSurf, 169 BBLS clean brine, 121 BBLS corrosion inhibited brine followed by 75 BBL clean brine. 18:00 21:15 3.25 6,274 6,274 COMPZ RPCOM HOSO P Space out with one 4.17'pup below the first joint of tubing under the tubing hanger pup. MU SSSV control lines to the hanger and land the hanger. Run in lock down screws. UP WT=80K, SO WT= 74K. Used a total of 59 SS Bands on the control line. 21:15 22:30 1.25 6,274 6,274 COMPZ DRILL PRTS P Test tubing to 3500 PSI for 30 min on chart. 22:30 23:00 0.50 6,274 6,274 COMPZ DRILL PRTS P Bleed off tubing to 2500 PSI and test I(‘'‘'C annulus to 3500 PSI for 30 min_on chart. t tk 23:00 00:00 1.00 6,274 6,274 COMPZ DRILL PRTS P Bleed tubing pressure with 3500 PSI on the annulus. Did not observed the SOV valve shear. Repeat attempts to Xb/ shear SOV,by pressuring up annulus to a max 3800 PSI. No success. Call for Slickline unit to pull valve.Continue attempt to shear valve. 12/30/2011 Continue attempt to shear SOV valve by pressuring the annulus to 3500 PIS. No success. Standby for slickline unit. Rig up slickline unit. Make up tools,WLIH to retrieve SOV valve at 6001'after pressuring tbg, and SSSV to 3500 PSI to verify open. RD Slickline unit. Install BPV. ND BOP's. NU tree.Wait on scaffold crew to RU scaffold in cellar. Make up Lubricator. Pull BPV. Install tree test plug.SIMOPS:Clean pits,prep for move. 00:00 02:15 2.25 6,274 6,274 COMPZ RPCOM PRTS T Continue attempt to shear SOV valve by pressure 3500 PSI on the annulus. No success.Standby for Slickline unit. RD Double stack tongs, prep rig floor for slickline equipment. Held PJSM with HES Slickline crew. 02:15 04:30 2.25 6,274 6,274 COMPZ RPCOM SLKL T Spot Slickline unit. Rig up slickline unit with sheaves.Make up tools. 04:30 05:30 1.00 COMPZ RPCOM SLKL T WLIH with kick over tool.Tagged up on SSSV.Attempt to pass through. No success.WLOH. 05:30 06:30 1.00 COMPZ RPCOM SLKL T Change out tools. Make up 2 1/2" bailer.WLIH to tag SSSV. Pressure tubing to 3500 PSI to aid in opening SSSV. Note,5800 PSI on the control line.Verify free movement through SSSV.WLOH, lay down bailer. 06:30 08:00 1.50 COMPZ RPCOM SLKL T Change of tools again, make up kick over tool.WLIH to SSSV. Pressure to 3500 PSI,verify opening SSSV. WLIH to latch up to DCK SOV. WLOH to SSSV. Pressure to 3500 PSI, observe communication to IA. Continjue WLOH to lay down kick over tool. Page 28 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 08:30 0.50 COMPZ RPCOM SLKL T RD Sheaves,XO's and slickline unit. 08:30 09:30 1.00 COMPZ RPCOM PULD P Pull and lay down landing joint. Install BPV.Test BPV through IA to 2900 PSI. Good test. Drain and flush BOP stack. 09:30 09:45 0.25 COMPZ RPCOM SFTY P Held PJSM with crew&FMC rep. Discuss sasfety&hazard recognition issues. Discuss prteocdeur to ND and NU. 09:45 12:00 2.25 COMPZ RPCOM NUND P ND BOP stack,choke&kill lines. SIMOPS: Cleaning pits.Crew Change 12:00 12:30 0.50 COMPZ RPCOM NUND P Disconnect control line. Blow down kill line. Set back BOP stack in cellar.Call for ASRC scaffold crew. 12:30 14:45 2.25 COMPZ RPCOM NUND P Orient,and NU adapter flange&tree. Attempt to seat the adapter flange. Pull&change seals as per FMC rep. NU Tree. 14:45 15:15 0.50 COMPZ RPCOM PRTS P Test adapter flange seals to 500 PSI -10 minutes. Open SSSV with 5500 PSI&monitor pressure 10 minutes. 15:15 22:15 7.00 COMPZ RPCOM PULD T Wait on ASRC scaffold crew to RU scaffold in cellar. SIMOPS:Clean pits. Rebuild Demco valves. Prepare pipe shed to lay down 4"DP. Pull lubricator to rig floor. 22:15 23:00 0.75 COMPZ RPCOM PULD P Held PJSM. Rig up scaffold in cellar. 23:00 00:00 1.00 COMPZ RPCOM PULD P Make up Lubricator as per FMC rep. Pull BPV. Install tree test plug. SIMOPS: Rig up Litte Red Hot oil service to pump freeze protect _ diesel. Crew Change 12/31/2011 Continue rig up test equipment to test tree.Observed the tree test plug failed. Pull plug. Install new plug.Test tree to 5000 PSI. Pull plug. Pump 80 BBLS of freeze protect diesel down annulus.Allow to U-tube until dead. Install BPV.Test BPV from annulus to 1000 PSI. Secure tree and cellar. RD scaffold. Lay down DP from derrick. Prep rig for move. Rig released at 1400 HRS. 00:00 02:00 2.00 COMPZ RPCOM PRTS P Continue rig up test equipment to pressure test tree.Observed tree test plug failed. RU Lubricator. Pull plug, inspect same. Internal 0 ring failed. 02:00 03:15 1.25 COMPZ RPCOM PRTS T Wait on FMC rep to retrieve secondary tree test plug from valve shop. 03:15 04:00 0.75 COMPZ RPCOM PRTS P RU Lubricator&set Tree test plug. Test tree to 5000 PSI-10 minutes- on chart. 04:00 04:30 0.50 COMPZ RPCOM RURD P Pull tree test plug with lubricator. Rig down test equipment. 04:30 05:00 0.50 COMPZ RPCOM'FRZP P Rig up Litte Red Hot oil Service. Make up lines and test same. Page 29 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 05:15 0.25 COMPZ RPCOM SFTY P Held PJSM with with crew and Little Red reps. Discuss safety&hazard recognition issues. Discuss procedure to pump freeze proetct diesel,and test BPV when set. 05:15 06:00 0.75 COMPZ RPCOM FRZP P Open up well,and pump 75 BBLS freeze protect diesel down annulus at 2.1 BPM-1500 PSI. 06:00 07:00 1.00 COMPZ RPCOM FRZP P Allow diesel to u-tube until well dead. 07:00 08:00 1.00 COMPZ RPCOM PULD P Install BPV.Test BPV from annulus with Little Red to 1000 PSI.Good test. 08:00 09:30 1.50 COMPZ RPCOM RURD P Blow down&rig down all lines. Install blank flanges&gauges. Rig down scaffold. Secure tree&cellar. SITP-60 PSI. 09:30 12:00 2.50 COMPZ RPCOM PULD P Held PJSM. Breakout&lay down 4" DP form derrick. Remove from pipe shed. Crew Change 12:00 13:30 1.50 COMPZ RPCOM PULD P Continue lay down 4"drill pipe from derrick. Remove from pipe shed. 13:30 14:00 0.50 COMPZ RPCOM RURD P Prep rig for rig move. Rig released from 1E-24B at 1400 HRS. Page 30 of 30 WELL LOG TRANSMITTAL To: State of Alaska February 1, 2012 Alaska Oil and Gas Conservation Commission Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501-3539 RE: LWD Formation Evaluation Logs: 1E-24B AK-MW-0008472252 1E-24B 50-029-20857-02 2"x 5" MD GR/RES Logs: 1 Color Log L- 2"x 5"TVD GR/RES Logs: 1 Color Log— Digital Log Images &LWDG-formatted LIS Data w/verification listing; 1 CD Rom ) 9,,c,''-- PLEASE c,�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@halliburton.com i%/ `� c) 0 01 Date:a�,��I l,, ,u1� Signed: `i _ dJ ( — I C-1 ConocoPhillips s TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke,AT01808 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave. Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501-3539 RE: 1E-24B AOGCC permit: 211-151-0 DATE: 01/22/2012 Tr.n itt- I: Kuparuk River Unit, North Slope, Alaska 1E-24B CD and hardcopy report Final Well report, Mud logging report, CANRIG;well 1 E-24B(500292085702); December 26, 2011 Equipment,well data, geological data, pressure/formation strength, drilling data, daily reports,formation logs color prints; Formation log (MD) v Formation log (TVD) Gas ratio (MD) •- Gas ratio (TVD) LWD Combo (MD) LWD Combo (TVD) Drilling dynamics (MD) ;Drilling dynamics (TVD) a CDROM contains; daily reports, DML data, final well report, LAS files, mud log PDF files, remarks and tiff files 4:/__ oso Sign, scan and return electronically to Sandra.D.LemkeaConocophillips com CC: 1 E-24B smittal folder, production well files, eSearch Receipt: v Date: o--C, J,,.,-. A-6 1 INMEMODiiit4, GIS-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 c /( — I ( EITETE ALAsEA SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COM)IISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1E-24B ConocoPhillips Alaska, Inc. Permit No: 211-151 Surface Location: 171' FSL, 226' FEL, SEC. 16, Ti1 N, R 10E, UM Bottomhole Location: 1576' FNL, 451' FWL, SEC. 22, T11N, R10E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. 14 Chair DATED this— day of November, 2011. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) R CEtVj 1 STATE OF ALASKA OV 2Q11 9 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL k‘lak Alaska Gil & Gas Crus. Commission 20 AAC 25.005 ntfiwa 1a.Type of Work: , lb.Proposed Well Class: Development-Oil ❑ •Service-Winj ❑ Single Zone 0 1c.Specify if well is proposeu Tor: Drill ❑ Re-drill❑✓ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket U Single Well 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 ^ 1E-24B • 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD:6966' TVD: 6427' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 171'FSL,226'FEL,Sec. 16,T11N,R10E,UM . ADL 25651 Kuparuk River Oil Pool • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1466'FNL,467'FWL,Sec.22,T11N, R10E,UM 469 12/5/2011 Total Depth: 9.Acres in Property: 14.Distance to 1576'FNL,451'FNL,Sec.22,T11N, R10E,UM 2560 Nearest Property: >1 mile 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 95 feet 15.Distance to Nearest Well Open Surface:x- 550300.6 • y- 5959760.7. Zone- 4 GL Elevation above MSL: • 67 feet to Same Pool: 1 E-24,573'at 6675' 16.Deviated wells: Kickoff depth: 4900 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 35.5° deg Downhole:3500 psig , Surface:2874 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) . 7" 5.5" 15.5# L-80 Hyd 563 1700' 4700' 4356' 6400' 5592' 206 sx Class G 4.75" 3.5" 9.3# L-80 Hyd 511 766' 6200' 5785' 6966' 6427' 60 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) 8167 6443 8070 6399 Casing Length Size Cement Volume MD ND Conductor/Structural 77' 16" 326 sx AS II 112' 112' • Surface 4731' 10.75" 1400 sx ASIII,250 sx AS I 2398' 2398' Intermediate Production 7363' 7" 700 sx Class G,250 sx AS I 7395' 6101' Liner 2807' 3.5" 510 sx Class G 8167' 6443' Perforation Depth MD(ft): 7344-7390,7400-7420,7430-7440, Perforation Depth TVD(ft): 6076-6099,6103-6113,6118-6122, 7442-7452,7460-7470,7520-7550,7818-7840,7880-7900 6123-6128,6132-6136,6159-6173,6291-6301,6319-6327 20.Attachments: Property Plat❑ BOP Sketch❑✓ Drilling Program O Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements E 21.Verbal Approval: Commission Representative: Date: c jr— - 22. I hereby certify that the foregoing is true and correct. Contact David Nugent @ 263-4228 Printed Name G. Alvord Title Alaska Drilling Manager '�' t "/ Signature f : Phon 265-6120 Date 0/6 ice, (A-1y rL-) p 1J t` Commission Use Only Permit to Drill y i API Number: } Permit Approv I See cover letter Number: .2 l 1 l c/ 50- Q aC( 2c7t/- i Date: \�TA \ \ for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed me hane,gas hydrates,or gas contained in shales: 'S rik Clfr^ICE` Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No [" Other: H2S measures: Yes [ No ❑ Directional svy req'd: Yes 2/ No ❑ 'k®'-> c msKA, c vt v r csa.`%r.\\z 'oQ c►-c- co r•—•.> ri / APPROVED BY THE COMMISSION / DATE. �1 COMMISSIONERS Form72._ 01 (Revised 7/2009) This permit is valid for 24 o d t pip 20 AAC 25I1YWq (g)) Submit in Duplicate it 1 /1l.t Con,ocoPhillips Alaska, Inc. Post Office Box 100360 'IV Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 RECEIVED' November 15, 2011 NOV 1 7 2011 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Alaska Oil &Gas Cons. Commission Anchorage,Alaska 99501 Ancnorage Re: Application for Permit to Drill Rotary Sidetrack CTD Setup 1E-24B Producer Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill/Sidetrack an onshore producer well from the lE pad for CTD setup. The expected spud date for this well is December 5,2011 conducting operations with Doyon Rig 141. The 1E-24 wellbore will be temporarily abandoned per separate sundry with 26 bbls of cement squeeze into the perforations from 7,344' to 7,900' MD and well as placed inside the 3-1/2"tubing from 7,344' to 5,390'MD. The proposed plan is to pull the un-cemented tubing and set a 7"retainer at 5,000' MD with a permanent whipstock on top at 4,916 MD/4,632' TVD. Next, a 6-1/8"window will be cut plus 20' of new formation. A formation integrity test will be performed to 16.0 ppg EMW,with a required minimum leak-off of 12.5 ppg EMW. The intermediate section will then be drilled with a 6"by 7"bi-center bit to 6,400' MD/5,952' TVD. The intermediate section will be lined from 6,400' MD to 4,700' MD with 5-1/2" 15.5#L-80 casing. Approximately 20' of new formation will be drilled with a 4-3/4"bit, and a formation integrity test will be performed to 16.0 ppg EMW,with a required minimum leak-off of 13.5 ppg EMW. The production hole section will then be drilled with a 4-3/4"bit to 6,966' MD/ 6,427' TVD. The production hole section will be lined from 6,966' MD to 6,200' MD with 3-1/2"9.3#L-80 casing. A 3-1/2"tubing completion will be landed in a seal bore receptacle at the liner top packer at 6,200' MD. Doyon 141 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 David A. Nugent at 263-4228 or Chip Alvord at 265-6120. Sincerely, ,AC David A.Nugent Drilling Engineer Application for Permit to Drill Document Kuparuk Well 1E-24B Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 1E-24B. Location Summary Requirements of 20 AAC 25.005(c)(2) In 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 ofthe well at the surface, referenced to the state plane coordinate systema for this,state cis 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 171' FSL, 226'FEL, Sec 16, T11N,R10E,UM NGS Coordinates RKB Elevation 95' AMSL • Northings: 5,959,760.7' Eastings: 550,300.6' Pad Elevation 67' AMSL • Location at Top of 1466' FNL,467' FWL, Sec 22,Ti 1N,R10E,UM Productive Interval (Kuparuk A Sand) NGS Coordinates Measured Depth, RKB: 6,762' Northings: 5,958,128.8' Eastings: 551,008.3' Total Vertical Depth, RKB: 6,256' Total Vertical Depth, SS: 6,161' Location at Total Depth 1576' FNL, 451' FWL, Sec 22,T11N,R10E,UM NGS Coordinates Measured Depth, RKB: 6,966' Northings: 5,958,018.9' Eastings: 550,992.6' Total Vertical Depth, RKB: 6,427' Total Vertical Depth, SS: 6,332' and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) 1fa well is to he intentionally deviated,the application for a Permit to Drill(Form 10-401)must (1)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 window and continue to increase with depth. The 1/4" mile pool scan of the top of Kuparuk A4 Sand shows the closest approach to be the original 1E-24 wellbore 573'away at 6,675' MD. And (2)for all wells within 200 feet of the proposed wellbore (=1)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 liwnished 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. ORIGINAL Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill rmrst he accompanied by each of the following items,except for an iters already nn file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(ROPE,)as required by 20 AAC 25.035,20 4 4C 25.036, or 20 A.AC 25.037,as applicable; ' Please reference BOP schematics on file for Doyon 141. 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 fidlowing items,except for an iters already°Ole with the commission and identified in the application: (i)irn(ormation on drilling hacards. including (9)the maximum downhole pressure that may he encountered,criteria used to determine it, and naoLxirnldmpotential surface pressure based on a methane gradient; The maximum potential surface pressure (MPSP) while drilling 1E-24B is calculated using a maximum reservoir pressure of 3,500 psi, a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A sand at 5,995' TVD (WP2): A Sand SIBHP = 3,500 psi A Sand estimated depth(WP02) = 6,260' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 626 psi (6,260' TVD * 0.10 psi/ft) MPSP = SIBHP—gas column =2,874 psi ; (3,500 psi—626 psi) (P)data on potential gas cones: The well bore is not expected to penetrate any gas zones. Ind (t2)data concerning potential causes of hole problems'such as abnormally_;en pressured strata, lost circulation cones.and:ones that have a Propensity far differential sticking, See attached 1E-24 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 as item already on file with the commission and identified in the application: (5)a description Qf the procedure for conductingfnrrnation integrity tests,as required under 20,AAC 25.030("f); A procedure is on file with the commission for performing LOT's. For 1E-24B the formation integrity test for the intermediate hole will occur after milling the window and 20' of new formation. The formation at the window depth will be pressured until leak-off occurs or 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 6,400' MD / 5,952' TVD, 20' of hole will be drilled, and the formation will be pressure tested until leak-off occurs or to 16.0 ppg EMW is reached, which ever comes first. A required minimum leak off of 13.5 ppg EMW must be obtained. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6' An application fin.a Permit to Drill must he accompanied h_r each of the f)llowing,items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20.1.1C'25.030 and a description of any slotted liner,pre perforated liner,or screen to he installed Casing Program Casing Hole weight Top Btm OD Size Grade Grade Connection Length MD/TVD MD/TVD 16" Conductor 62.5 H-40 Weld 80' Surface z 34' 112' I 112- Original 12-Original Wellbore 10-3/4- 13-1r'2" 45.5 K-55 BIC: 2.398' Surtace 33' 2.398' 2.398' 7" 9-718" 26 K-55 BTC 7.395' Surface=32' 7.395' l 6.101' Sidetrack 5-1/2"Liner 7" 15.5 L-80 Hydril 563 1,700' 4,700' /4,356' 6,400'/5,592' Out of 7" Casing 3_./2"Liner 4-3/4" 9.3 L-80 Hydril 511 766' 6,200'/5,785 6,966'/6,427 3-1/2" Tubing 9.3 L-80 IBTM 766' Surface 28' 6,200'/5,785' Single Stage Cement Program—Intermediate Hole Cement will be placed from the intermediate liner TD at 6,400' MD to 100' above the top of liner. The liner shoe will be at 6,400' MD and the top of liner set at 4,700' MD (approximately 200'of overlap inside the existing 7" casing). The slurry consists of 206 sacks of Class G cement plus additives at 15.8 ppg with 35% excess yielding 1.16 ft3/sx. Cement System Preflush: 20 bbls Chemical Wash Spacer: 25 bbls MudPush II Lead Slurry: 206 sacks Class G Cement+ additives Yield= 1.16 ft3/sx Mix Water= 5.1 gal/sx Slurry Volumes Length Capacity Excess Total(ft3) Total(sacks) (ft) (ft3) Liner Lap 200 10 0% 10 8.5 6.276"x 5.50" Open Hole x Liner OD 1500 153 35% 205 177 7"x 5.50" Shoe Track ID 80 11 0% 11 9.5 4.950" Top of liner 100 13 0% 13 11 6.276"" Total 239 206 Single Stage Cement Program—Production Hole Cement will be placed from TD at 6,966' MD to 100' above the top of liner. The liner shoe will be at 6,966' MD and the top of liner set at 6,200' MD (approximately 200'of overlap inside the 5-1/2" liner). ' t..f t,` i t 1 l``C a '1 L The slurry consists of 60 sacks of Class G cement plus additives at 15.8 ppg with 35% excess yielding 1.17 ft3/sx. Cement System Preflush: 10 bbls Chemical Wash Spacer: 12 bbls MudPush II Lead Slurry: 60 sacks Class G Cement+ additives Yield= 1.17 ft3/sx Mix Water= 5.1 gal/sx Length Capacity 3 Slurry Volumes (ft) (ft3) Excess Total(ft ) Total(sacks) Liner Lap 200 13 0% 13 11 4.95"x 3.50" Open Hole x Liner OD 1500 32 35% 43 37 4.75"x 3.50" Shoe Track ID 90 5 0% 5 4 4.950" Top of liner 100 9 0% 9 8 6.276"" Total 70 60 Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application fora Feront to Drill must he accompanied In each of the following items,except for an item already on file with the eornniisiion and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25,035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); This rotary sidetrack will exit pre-existing 7" casing at 4,916' MD. BOPE will be installed prior to exiting the casing, 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 he accompanied by each of the following items,except for an item 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 (ft) (ppg) Vis(cp) PV YP Loss pH Comments (cc/30min) Milling Fluid 9.6 9.8 50-60 15-20 50-60 NC 10.5 11 Milling fluid can be reconditioned 4,915'-4,945' for dilling sidetrack LSND 9.5-11.0 60-80 25-35 7-8 <6 9.5-10 4,945'-6,400' LSND 11.0-12.0 ✓ 60-80 25-40 5-6 <6 9.5-10 6,400'-6,966' Milling Fluid: A 9.8 ppg viscosified water based milling fluid consisting of pH control and weighting agents will be used to cut the 6-1/8" window and 20' of new formation. This fluid will maintain good rheology to remove metal fragments from the wellbore and prevent their recirculation. The milling fluid can be reconditioned for use in the sidetrack. Intermediate and Production Hole Sidetrack Fluid: A 9.8 ppg LSND drilling fluid will be used to drill the intermediate hole to 6,400' MD / 5,925' TVD. An • 11.3 ppg LSND drilling fluid will be used to drill the production hole to 6,966' MD / 6,427' TVD. The drilling mud weight is calculated using an A Sand EMW of 10.8 ppg plus 0.5 ppg trip margin to result in an 11.3 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. Diagram of Doyon 141 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 jor a Permit to Drill must be aeeon:parried by each of the following items,except for an item already on file with the cc=!nmission and identified in the application: 1E-24A P&A Pre Rig Work(previous sundry): a. Replace OV and GLV's with dummy valves. b. RIH on coil tubing and set retainer at 7,000' RKB. c. Pump 26 bbls of 15.8 ppg cement into the perforation from 7,344'—7,900' and fill the tubing above the retainer from 7,000'—5,390'. d. Punch holes in the 3-1/2"tubing at 5,350' RKB. e. Set a retainer at 5,300' RKB. Mix and pump 6 bbls of cement,4 bbls circulated into the IA through the tubing holes and 2 bbls layed on top the cement retainer. f. Tag top of cement with bailer. Test the plug. g. E-line cut tubing at 5,081' MD - Tubing is freeze protected with diesel. ORtGLNAL - BPV and VR plug was set. 1. Move Doyon 141 on 1E-24A 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 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 BOPE to 250 psi low/3,500 psi high as per drilling permit. 4. Pull blanking plug and BPV. Pull tubing hanger and lay down 3-1/2"completion. 5. Run 7"casing scraper to 5,080' MD. • Spot a weighted pill with corrosion inhibitor between tubing stub and cement retainer. 6. Rig up E-line and run gyro/caliper in 7" casing to evaluate for subsidence related issues. 7. Using E-line,perforate 7" casing at 5,010' MD for cement squeeze. 8. Set 7"cement retainer bottom at approximately 5,000' MD. 9. Squeeze approximately 450' into perforations to assist with kickoff and LOT. 10. Nipple down BOP stack and tubing head. Pull 7"packoff and expect casing growth. 11. Run 7"casing spear and engage 7"casing with overpull. Cut excess casing and reset slips with casing. 12. Install 7"packoff,nipple up tubing head and BOP stack. Retest same. 13. Test 7"casing and CIBP to 3,500 psi,chart for 15 minutes. This will be used as a baseline for the FIT/LOT. 3 14. Pick up 7"whipstock/milling assembly. Run in hole and displace casing to milling fluid. Orient whipstock. t� 15. Set whipstock and mill window in 7"plus 20' of new formation for FIT/LOT. Perform FIT with rig pump as per CPAI procedure to 16 ppg EMW. Minimum acceptable leak off is 12.5 ppg EMW. 16. Pull out of hole whipstock/milling assembly and gauge mills. If greater than 1/8"under,make another mill run with new mills. 17. Pick-up and make up 6"X 7"bi-center bit with 4-3/4"L/MWD drilling BHA. 18. Run in hole with drilling BHA to top of window and displace to 9.8 ppg drilling mud. 19. Drill 7"hole from 4,936' MD to 6,400' (above C Sand). 20. At total depth,circulate hole clean and wiper trip to window. Once back on bottom, circulate until hole is clean. Pull out of hole and rack back drill pipe and BHA. Pull wear bushing. 21. Run 5-1/2", 15.5 ppf,L-80 liner to TD. Top of liner will be approximately 200' above window. 22. Cement liner to top with 15.8 ppg Class G slurry and 35%excess. Set liner hanger. Slackoff and set liner top packer. Circulate out excess cement above liner. 23. Drill out shoe track and 20' of new formation. Displace hole to 11.3 ppg MW. Perform open hole leak off to 16.0 ppg EMW. Minimum acceptable leak off is 13.5 ppg EMW. 24. Drill 4-3/4"hole from 6,400' MD to 6,966' (TD). 25. At total depth,circulate hole clean and wiper trip to window. Once back on bottom,circulate until hole is clean. Pull out of hole and rack back drill pipe and BHA. Pull wear bushing. 26. Pick up and run 3-1/2"9.3#L-80 SLHT liner. The top of liner will be placed at approximately 6,200' MD allowing for 200' of overlap. 27. Cement liner to top with 15.8 ppg Class G slurry and 35%excess. Set liner hanger. Slackoff and set liner top packer. Circulate out excess cement above liner. 28. Monitor well then pull out of hole laying down drill pipe. 29. Run upper completion as per procedure with SSSV and 5 GLMs. 30. RD and MO Doyon 141. Coil tubing drilling rig will return at a future date to drill A Sand producers. Discussion of Mud and Cuttings Disposal and Annular Disposal0)11 Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill nnistc he accompanied by each of the following items,except for an item already on jrle with the commission 1")\ and identified in the application: f t tb t (14)a general description()Plow the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intens.to request authorization under 20 AIC 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 Well Schematic I\ ConocoPhillips (Alaska) Inc. -Kup1 IIA Kuparuk River Unit Kuparuk 1E Pad 1E-24 Plan: 1E-24B Plan: 1E-24B (wp02) Standard Proposal Report 04 November, 2011 HALUi3URTON I Sperry Drilling Services OIIG1NAL L, HALL BI V RTON Project: Kuparuk River Unit WELL DETAILS: 1E-24 Site: Kuparuk 1E Pad / Ground Level: Q7.00 Well: 1 E-24 +N/-S +E/-W Northing Fasting Latittude Longitude Slot Sperry Drilling Wellbore: Plan: 1 E-24B 0.00 0.00 5959760.73 550300.55 70°18'2.999 N 149°35'33.373 W Plan: 1E-24B (Wp02) REFERENCE INFORMATION Co-ordinate(N/E)Reference:Well 1E-24,True North 4250 - ---- Vertical(TVD)Reference:PIan:1 E-24B 95.009(D141(28+67)) -- --- -- - -- -- - ---- Measured Depth Reference: Plan:1 E-24B©95.009(D141(28+67)) - . Calculation Methal:Minimum Curvature i 4500— - TOW @ 4900'MD,4619'TVD:631'FNL,451'FWL-Sec 22-T I I N-R I OE_ 7"TOW __��� ----`___.--�-- __- 4 OpJ - 1 4750- s. - - _ CASING DETAILS II _ .; 5000 MD TVD TVDSS Name Size Hole Size 2387.00 2386.94 2291.94 10 3/4" 10-3/4 13-1/2 4900.02 4619.18 4524.18 7"TOW 7 8-3/4 20° 6400.00 5952.29 5857.29 5 1/2" 5-1/2 7 o 6966.02 6426.99 6331.99 3 1/2" 3-1/2 4-3/4 o0 5250 - - - I A \ DDI = 5.645 f 5500- J t CO Ca, - -7op PF, 'h-1 tkrrk,:'ej ~'> 5750-- F-. Casing Pt @ 6400'MD,5952'TVD:1271'FNL,497'FWL-Sec 22-T1IN-RIS _ 5 1/2"_ _ _ -__ s -./bp Kandnk(Nine 1)97) 6000 --K-t Marker- < ,.,ri7 3 - - ---1_ j _- __f-Te C. ,, _ 1E-24B C and l t 1_ 7 --/npBShale- ,`"r, `_- - . BIIL @ 6966'MD,6427'TVD:1576'FNL,451'FWL-Sec 22-TI I N-RI OE li 6250 _ - - _ - -IE-24B A4(wp02- - - - - - I - 1-- - -- -p5 + I - - -+ - -- _ - --__ - . 'Toy:u t� 3 I' _ J 7F Lfturoeach 6500- ___. • ....... ...._..__ ..... ... _ 1E-24B(wp02) I i I I I I i I I l l l l l l l I l l l l I Ill iiI 1 1 1 1 1 1 1 1 1 1 1 1 I I I l ] r I l l 1 , l 500 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 4000 Vertical Section at 144.06°(500 ff/in) -700 �`. - TOW @ 4900'MD,4619'TVD:631'FNL,451'FWL Sec 22 T11N-R10E 4 -1 7"TOW -800 _ "v d - - -900- T >�1t1_ -1000 - s°, -1100 sr 0 on - -!--- -,li o - -1200 -_ -- _ 55 00 T- { -1300 _ .t, - - 5 1/2" 95%conf .-_'L -. _ L-1400 ---- - - x'60 --- ___ -CasingPt 6400 MD,5952'TVDt 1271'FNL,497'FWL-Sec 32-T11 N-Rl t-- - ✓] I @ -1500— , _11E-24B (wP �j� I M1Azimuth C Sand 02 00 T :Magnetic to True North II c North.16 66° -1600— , 1E-24B A4(wp02� � - ,2�., ,/ - - Magnetic Field 1. i - - Strength 57369.8snT -1700- --- - -- 3 1/2 BI4L@ 6966 MD,6427'TVD 1576'FNL,451'FWL Sec 22-TI1N RtOE DipAngle:29.88°_ _ Date 8/3/-2014 VIII y. ,427 [l i-- 1-_ I Model BGG 2(111 -1800 - ._._ j 1R-2413(w02)-- �.__ Ili ! Illi iii i : iijiIiiIiiIijiiIiIiiil IIIIIIiil IIIlllllllllll iii )' liii ilii iiiiiiiiiiii , , 11 0 100 200 300 400 50011 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1911 7000 71 An West(-)/East(+)(300 ft/in) ConocoPhillips Alaska ORIGINAL Halliburton - Sperry I-I A LI B UJ .. TO Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 1E-24 Company: ConocoPhillips(Alaska)Inc.-Kup1 ND Reference: Plan:1 E-24B @ 95.00ft(D141(28+67)) it Project: Kuparuk River Unit MD Reference: Plan:1E-24B @ 95.00ft(D141(28+67)) 1,1 I Site: Kuparuk 1 E Pad North Reference: True 11 Well: 1E-24 Survey Calculation Method: Minimum Curvature Wellbore: Plan:1E-248 Design: 1E-24B(wp02) Project Kuparuk River Unit,North Slope Alaska,United States i.,- ,,,,.--,--,,,,,,,,,,v,, ,m n ,hymn rorrunc,amemrmmmmmummonmsn:- 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 1 E Pad ) mmo Site Position: Northing: 5,959,760.24 ft Latitude: 70°18'3.021 N From: Map Easting: 549,889.51 ft Longitude: 149°35'45.358 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: 0.38° Well 1E-24 Well Position +N/-S 0.00 ft Northing: 5,959,760.73 ft Latitude: 70°18'2.999 N +E/-W 0.00 ft Easting: 550,300.55 ft Longitude: 149°35'33.373 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 67.00ft Wellbore Plan:1E-248 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) 1°) (nT) BGGM2011 8/31/2011 16.66 79.88 57,370 Design 1E-24B(wp02) Audit Notes: Version: Phase: PLAN Tie On Depth: 4,900.00 Vertical Section: Depth From(ND) °I lijiilll II or +N/-S +E/-W Direction (ft) II �ml'i IlhllullljlllliIII IuI 1 11 lilllil!I. (ft) (ft) (1 28.00 0-00 0.00 144.06 L - - Plan Sections Measured Vertical ND Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (°) 1°) (ft) ft (ft) (ft) (°1100ft) (°I100ft) (°I100ft) (°) 4,900.00 34.03 142.02 4,619.17 4,524.17 -802.51 678.73 0.00 0.00 0.00 0.00 4,915.60 35.47 144.45 4,631.99 4,536.99 -809.63 684.05 12.82 9.22 15.62 45.00 4,945.60 35.47 144.45 4,656.42 4,561.42 -823.80 694.17 0.00 0.00 0.00 0.00 5,595.63 18.75 191.31 5,238.93 5,143.93 -1,084.18 784.88 4.00 -2.57 7.21 147.65 5,759.65 18.75 191.31 5,394.24 5,299.24 -1,135.89 774.54 0.00 0.00 0.00 0.00 6,117.06 33.00 188.50 5,715.00 5,620.00 -1,289.28 748.75 4.00 3.99 -0.79 -6.20 6,554.66 33.00 188.50 6,082.00 5,987.00 -1,524.99 713.53 0.00 0.00 0.00 0.00 6,966.03 33.00 188.50 6,427.00 6,332.00 -1,746.58 680.41 0.00 0.00 0.00 0.00 11/4/2011 6:09:40PM Page 2 COMPASS 2003.16 Build 69 - ORIGINAL Halliburton -Sperry LIBUR'`D Standard Proposal Report I.IIRIIIIIIIIIIG,tl MPM IIIIIIMIIIIIIIIIIIIIIIMIIIIIIIIV ,o11111111111111111111111111111111111111111111111111111111VID1111111111111111111111111111111111111111111PIIIIIIIIRMIUMWM1111111111111111111111111111111111111111111111111111111111I Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 1E-24 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Plan:1E-24B @ 95.00ft(D141(28+67)) Project: Kuparuk River Unit MD Reference: Plan:1 E-24B @ 95.00ft(D141(28+67)) Site: Kuparuk 1E Pad North Reference: True Well: 1E-24 Survey Calculation Method: Minimum Curvature Wellbore: Plan:1E-24B Design: 1E-24B(wp02) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) C) (ft) ft (ft) (ft) (ft) (ft) -67.00 28.00 0 00 0.00 28.00 -67.00 0.00 0.00 5,959,760.73 550,300.55 0.00 0.00 71.00 0.35 198.71 71.00 -24.00 -0.12 -0.04 5,959,760.61 550,300.51 0.81 0.08 96.00 0.12 355.24 96.00 1.00 -0.17 -0.07 5,959,760.56 550,300.48 1.85 0.10 121.00 0.15 149.31 121.00 26.00 -0.17 -0.05 5,959,760.56 550,300.50 1.05 0.11 146.00 0.50 111.15 146.00 51.00 -0.24 0.06 5,959,760.49 550,300.62 1.57 0.23 171.00 0.43 103.75 171.00 76.00 -0.30 0.26 5,959,760.43 550,300.81 0.37 0.40 196.00 0.66 97.89 196.00 101.00 -0.34 0.49 5,959,760.39 550,301.04 0.95 0.57 221.00 0.76 83.87 221.00 126.00 -0.35 0.80 5,959,760.39 550,301.35 0.80 0.75 246.00 0.77 94.95 245.99 150.99 -0.34 1.13 5,959,760.39 550,301.68 0.59 0.94 271.00 0.53 119.62 270.99 175.99 -0.41 1.40 5,959,760.33 550,301.95 1.45 1.16 296.00 0.38 102.89 295.99 200.99 -0.49 1.58 5,959,760.25 550,302.13 0.80 1.32 321.00 0.74 85.35 320.99 225.99 -0.50 1.82 5,959,760.25 550,302.37 1.58 1.47 346.00 0.52 102.49 345.99 250.99 -0.51 2.09 5,959,760.24 550,302.65 1.15 1.64 371.00 0.44 58.81 370.99 275.99 -0.48 2.29 5,959,760.26 550,302.84 1.46 1.73 396.00 0.41 61.51 395.99 300.99 -0.39 2.45 5,959,760.36 550,303.00 0.14 1.75 421.00 0.33 71.94 420.99 325.99 -0.32 2.59 5,959,760.42 550,303.15 0.42 1.78 446.00 0.25 39.28 445.99 350.99 -0.26 2.70 5,959,760.49 550,303.25 0.72 1.79 471.00 0.29 102.06 470.99 375.99 -0.23 2.79 5,959,760.52 550,303.34 1.13 1.83 496.00 0.47 62.98 495.99 400.99 -0.20 2.95 5,959,760.55 550,303.50 1.22 1.89 521.00 0.25 12.78 520.98 425.98 -0.10 3.05 5,959,760.65 550,303.60 1.46 1.87 546.00 0.23 94.24 545.98 450.98 -0.05 3.11 5,959,760.70 550,303.66 1.25 1.87 571.00 0.20 123.93 570.98 475.98 -0.08 3.20 5,959,760.68 550,303.75 0.46 1.94 596.00 0.33 119.06 595.98 500.98 -0.14 3.30 5,959,760.62 550,303.85 0.53 2.05 621.00 0.14 50.14 620.98 525.98 -0.15 . 3.38 5,959,760.60 550,303.93 1.23 2.11 646.00 0.15 51.74 645.98 550.98 -0.11 3.43 5,959,760.64 550,303.98 0.04 2.10 671.00 0.23 0.35 670.98 575.98 -0.04 3.46 5,959,760.71 550,304.01 0.72 2.06 696.00 0.22 327.46 695.98 600.98 0.05 3.43 5,959,760.80 550,303.98 0.51 1.97 721.00 0.22 133.38 720.98 625.98 0.06 3.44 5,959,760.81 550,303.99 1.75 1.97 746.00 0.28 174.19 745.98 650.98 -0.04 3.48 5,959,760.72 550,304.03 0.73 2.07 771.00 0.08 246.28 770.98 675.98 -0.10 3.47 5,959,760.65 550,304.02 1.07 2.12 796.00 0.03 192.03 795.98 700.98 -0.12 3.46 5,959,760.64 550,304.01 0.27 2.12 821.00 0.25 11.59 820.98 725.98 -0.07 3.47 5,959,760.68 550,304.02 1.12 2.09 846.00 0.06 207.84 845.98 750.98 -0.03 3.47 5,959,760.72 550,304.02 1.23 2.06 871.00 0.32 67.39 870.98 775.98 -0.01 3.53 5,959,760.74 550,304.08 1.47 2.08 896.00 0.11 150.50 895.98 800.98 -0.01 3.61 5,959,760.75 550,304.15 1.30 2.12 921.00 0.20 93.99 920.98 825.98 -0.03 3.66 5,959,760.72 550,304.21 0.67 2.17 946.00 0.31 66.51 945.98 850.98 -0.01 3.77 5,959,760.75 550,304.32 0.65 2.22 971.00 0.04 308.23 970.98 875.98 0.02 3.82 5,959,760.78 550,304.37 1.32 2.22 996.00 0.36 134.98 995.98 900.98 -0.03 3.87 5,959,760.73 550,304.42 1.60 2.29 1,021.00 0.11 182.27 1,020.98 925.98 -0.10 3.92 5,959,760.65 550,304.47 1.19 2.39 1,046.00 0.21 268.70 1,045.98 950.98 -0.13 3.88 5,959,760.63 550,304.43 0.92 2.38 1,071.00 0.24 215.48 1,070.98 975.98 -0.17 3.80 5,959,760.58 550,304.35 0.81 2.37 1,096.00 0.16 198.84 1,095.98 1,000.98 -0.25 3.76 5,959,760.51 550,304.31 0.39 2.41 1,121.00 0.38 218.18 1,120.98 1,025.98 -0.35 3.70 5,959,760.41 550,304.25 0.94 2.45 1,146.00 0.42 185.93 1,145.98 1,050.98 -0.50 3.64 5,959,760.25 550,304.19 0.90 2.54 11/4/2011 6:09:40PM Page 3 COMPASS 2003.16 Build 69 ORG1NAL Halliburton - Sperry 11AL _T N Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 1E-24 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Plan:1 E-24B©95.00ft(D141(28+67)) Project: Kuparuk River Unit MD Reference: Plan:1 E-24B @ 95.00ft(0141(28+67)) Site: Kuparuk 1E Pad North Reference: True Well: 1 E-24 Survey Calculation Method: Minimum Curvature Wellbore: Plan:1E-24B Design: 1E-248(wp02) ue oxuNouuxouuuouuuu m.. Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (a) (ft) ft (ft) (ft) (ft) (ft) 1,075.98 1,171 00 0.11 153.57 1.170.98 1,075.98 -0.62 3.64 5,959,760.14 550,304 19 1.33 2.63 1,196.00 0.07 217.69 1,195.98 1,100.98 -0.65 3.64 5,959,760.10 550,304.19 0.41 2.66 1,221.00 0.35 174.77 1,220.98 1,125.98 -0.74 3.64 5,959,760.02 550,304.19 1.21 2.73 1,246.00 0.07 199.21 1,245.98 1,150.98 -0.83 3.64 5,959,759.93 550,304.19 1.15 2.81 1,271.00 0.32 189.69 1,270.98 1,175.98 -0.91 3.62 5,959,759.84 550,304.18 1.00 2.86 1,296.00 0.28 185.47 1,295.98 1,200.98 -1.04 3.60 5,959,759.71 550,304.16 0.18 2.96 1,321.00 0.13 231.08 1,320.98 1,225.98 -1.12 3.58 5,959,759.63. 550,304.13 0.84 3.01 1,346.00 0.36 172.93 1,345.98 1,250.98 -1.22 3.56 5,959,759.54 550,304.12 1.25 3.08 1,371.00 0.47 202.26 1,370.98 1,275.98 -1.39 3.54 5,959,759.37 550,304.09 0.94 3.20 1,396.00 0.22 178.74 1,395.98 1,300.98 -1.53 3.50 5,959,759.22 550,304.06 1.13 3.29 1,421.00 0.54 174.14 1,420.98 1,325.98 -1.70 3.51 5,959,759.06 550,304.07 1.28 3.43 1,446.00 0.49 201.41 1,445.98 1,350.98 -1.91 3.48 5,959,758.84 550,304.05 0.99 3.59 1,471.00 0.13 160.32 1,470.98 1,375.98 -2.04 3.45 5,959,758.71 550,304.02 1.60 3.68 1,496.00 0.27 155.49 1,495.98 1,400.98 -2.12 3.49 5,959,758.63 550,304.05 0.56 3.76 1,521.00 0.60 168.48 1,520.98 1,425.98 -2.30 3.54 5,959,758.45 550,304.10 1.37 3.94 1,546.00 0.51 94.61 1,545.97 1,450.97 -2.44 3.68 5,959,758.32 550,304.24 2.68 4.13 1,571.00 0.08 19.45 1,570.97 1,475.97 -2.43 3.79 5,959,758.32 550,304.36 1.98 4.19 1,596.00 0.47 259.54 1,595.97 1,500.97 -2.43 3.70 5,959,758.32 550,304.26 2.06 4.14 1,621.00 0.42 158.74 1,620.97 1,525.97 -2.54 3.63 5,959,758.22 550,304.20 2.75 4.18 1,646.00 0.29 118.56 1,645.97 1,550.97 -2.65 3.72 5,959,758.10 550,304.29 1.09 4.33 1,671.00 0.51 211.39 1,670.97 1,575.97 -2.78 3.72 5,959,757.98 550,304.28 2.40 4.43 1,696.00 0.82 248.68 1,695.97 1,600.97 -2.94 3.49 5,959,757.82 550,304.06 2.07 4.43 1,721.00 0.53 336.99 1,720.97 1,625.97 -2.90 3.28 5,959,757.86 550,303.85 3.85 4.27 1,746.00 0.81 61.04 1,745.97 1,650.97 -2.70 3.39 5,959,758.05 550,303.96 3.68 4.18 1,771.00 0.58 137.34 1,770.97 1,675.97 -2.71 3.63 5,959,758.04 550,304.20 3.51 4.33 1,796.00 0.67 239.65 1,795.97 1,700.97 -2.88 3.59 5,959,757.88 550,304.16 3.90 4.44 1,821.00 0.54 338.95 1,820.97 1,725.97 -2.84 3.42 5,959,757.91 550,303.99 3.70 4.31 1,846.00 0.56 99.30 1,845.96 1,750.96 -2.75 3.50 5,959,758.00 550,304.07 3.82 4.28 1,871.00 0.50 162.62 1,870.96 1,775.96 -2.88 3.65 5,959,757.88 550,304.22 2.23 4.47 1,896.00 0.80 283.93 1,895.96 1,800.96 -2.94 3.52 5,959,757.82 550,304.08 4.57 4.44 1,921.00 0.82 343.35 1,920.96 1,825.96 -2.73 3.29 5,959,758.03 550,303.86 _3.21 4.14 1,946.00 0.54 80.96 1,945.96 1,850.96 -2.54 3.36 5,959,758.22 550,303.93 4.16 4.02 1,971.00 0.37 174.40 1,970.96 1,875.96 -2.60 3.48 5,959,758.16 550,304.05 2.69 4.15 1,996.00 0.31 243.84 1,995.96 1,900.96 -2.71 3.43 5,959,758.05 550,304.00 1.56 4.21 2,021.00 0.53 198.70 2,020.96 1,925.96 -2.85 3.33 5,959,757.91 550,303.90 1.52 4.26 2,046.00 0.50 128.34 2,045.96 1,950.96 -3.02 3.38 5,959,757.73 550,303.95 2.38 4.43 2,071.00 0.09 315.32 2,070.96 1,975.96 -3.08 3.45 5,959,757.68 550,304.02 2.36 4.52 2,096.00 0.49 180.19 2,095.96 2,000.96 -3.17 3.44 5,959,757.58 550,304.01 2.23 4.59 2,121.00 0.54 138.60 2,120.96 2,025.96 -3.37 3.52 5,959,757.39 550,304.09 1.47 4.79 2,146.00 0.22 133.58 2,145.96 2,050.96 -3.49 3.63 5,959,757.27 550,304.20 1.29 4.95 2,171.00 0.57 198.32 2,170.95 2,075.95 -3.64 3.63 5,959,757.12 550,304.20 2.06 5.07 2,196.00 0.45 122.81 2,195.95 2,100.95 -3.81 3.67 5,959,756.95 550,304.24 2.53 5.24 2,221.00 0.86 156.14 2,220.95 2,125.95 -4.03 3.83 5,959,756.72 550,304.40 2.17 5.51 2,246.00 0.34 167.33 2,245.95 2,150.95 -4.28 3.92 5,959,756.48 550,304.50 2.12 5.76 2,271.00 0.40 101.76 2,270.95 2,175.95 -4.37 4.02 5,959,756.39 550,304.60 1.62 5.90 11/4/2011 6:09:40PM Page 4 COMPASS 2003.16 Build 69 ORIGINAL Halliburton -Sperry H/ L__-_ __..... U R' _ _ Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 1E-24 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Plan:1E-24B @ 95.00ft(D141(28+67)) Ill Project: Kuparuk River Unit MD Reference: Plan:1E-24B @ 95.00ft(D141(28+67)) IV Site: Kuparuk 1 E Pad North Reference: True Well: 1E-24 Survey Calculation Method: Minimum Curvature Wellbore: Plan:1E-24B Design: 1E-24B(wp02) Planned Survey 8 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) 2,200.95 2,296.00 0.68 146.22 2,295.95 2,200.95 -4.51 4.19 5,959,756.25 550,304.77 1.94 6.11 1� 2,321.00 0.11 191.31 2,320.95 2,225.95 -4.66 4.27 5,959,756.10 550,304.85 2.43 6.27 2,346.00 0.65 81.42 2,345.95 2,250.95 -4.66 4.40 5,959,756.10 550,304.98 2.78 6.36 2,371.00 0.66 103.15 2,370.95 2,275.95 -4.67 4.68 5,959,756.09 550,305.26 0.99 6.53 2,387.00 0.83 118.06 2,386.94 2,291.94 -4.75 4.88 5,959,756.02 550,305.46 1.62 6.70 10 314" 2,396.00 0.95 123.83 2,395.94 2,300.94 -4.82 4.99 5,959,755.95 550,305.58 1.62 6.83 2,421.00 1.49 86.44 2,420.94 2,325.94 -4.91 5.49 5,959,755.85 550,306.07 3.74 7.20 2,446.00 0.83 108.16 2,445.93 2,350.93 -4.95 5.99 5,959,755.82 550,306.57 3.13 7.52 2,471.00 1.33 107.55 2,470.93 2,375.93 -5.09 6.44 5,959,755.68 550,307.02 2.00 7.90 2,496.00 1.04 88.88 2,495.92 2,400.92 -5.18 6.94 5,959,755.60 550,307.52 1.92 8.27 2,521.00 0.91 118.78 2,520.92 2,425.92 -5.27 7.34 5,959,755.51 550,307.93 2.07 . 8.57 2,546.00 1.84 94.45 2,545.91 2,450.91 -5.40 7.92 5,959,755.39 550,308.50 4.31 9.01 2,571.00 1.24 111.68 2,570.90 2,475.90 -5.53 8.57 5,959,755.26 550,309.15 3.01 9.50 2,596.00 2.52 114.43 2,595.89 2,500.89 -5.85 9.32 5,959,754.94 550,309.91 5.13 10.21 2,621.00 4.12 113.92 2,620.85 2,525.85 -6.44 10.64 5,959,754.36 550,311.23 6.40 11.46 2,646.00 5.96 118.44 2,645.75 2,550.75 -7.43 12.60 5,959,753.39 550,313.20 7.52 13.41 2,671.00 6.92 123.97 2,670.59 2,575.59 -8.89 14.99 5,959,751.94 550,315.60 4.57 15.99 2,696.00 8.20 126.64 2,695.37 2,600.37 -10.79 17.67 5,959,750.06 550,318.29 5.31 19.11 2,721.00 9.36 129.27 2,720.08 2,625.08 -13.14 20.68 5,959,747.73 550,321.31 4.91 22.78 2,746.00 10.66 126.90 2,744.70 2,649.70 -15.82 24.10 5,959,745.07 550,324.75 5.45 26.95 2,771.00 12.12 128.92 2,769.21 2,674.21 -18.86 27.99 5,959,742.06 550,328.66 6.05 31.70 2,796.00 13.57 129.48 2,793.58 2,698.58 -22.37 32.30 5,959,738.58 550,332.99 5.82 37.07 2,821.00 14.17 130.13 2,817.85 2,722.85 -26.21 36.90 5,959,734.77 550,337.62 2.48 42.88 2,846.00 14.95 132.46 2,842.05 2,747.05 -30.36 41.62 5,959,730.66 550,342.37 3.90 49.01 2,871.00 15.81 133.63 2,866.15 2,771.15 -34.88 46.46 5,959,726.16 550,347.24 3.66 55.51 2,896.00 17.13 138.02 2,890.13 2,795.13 -39.97 51.39 5,959,721.11 550,352.20 7.25 62.52 2,921.00 17.65 135.59 2,913.99 2,818.99 -45.41 56.51 5,959,715.70 550,357.35 3.57 69.93 2,946.00 17.86 136.99 2,937.79 2,842.79 -50.93 61.77 5,959,710.22 550,362.66 1.90 77.49 2,971.00 18.24 137.95 2,961.56 2,866.56 -56.63 67.01 5,959,704.55 550,367.93 1.93 85.18 2,996.00 18.96 136.10 2,985.26 2,890.26 -62.47 72.45 5,959,698.76 550,373.41 3.72 93.10 3,021.00 18.84 139.33 3,008.91 2,913.91 -68.45 77.89 5,959,692.81 550,378.89 4.21 101.14 3,046.00 19.53 136.83 3,032.52 2,937.52 -74.56 83.38 5,959,686.73 550,384.42 4.29 109.31 3,071.00 19.63 139.34 3,056.08 2,961.08 -80.80 88.98 5,959,680.54 550,390.06 3.39 117.64 3,096.00 20.38 138.35 3,079.57 2,984.57 -87.24 94.61 5,959,674.14 550,395.73 3.29 126.16 3,121.00 19.99 139.84 3,103.03 3,008.03 -93.75 100.26 5,959,667.66 550,401.42 2.58 134.75 3,146.00 21.26 140.15 3,126.43 3,031.43 -100.50 105.92 5,959,660.95 550,407.13 5.10 143.53 Ili 3,171.00 19.86 139.91 3,149.84 3,054.84 -107.23 111.56 5,959,654.26 550,412.81 5.61 152.29 3,196.00 20.55 140.86 3,173.30 3,078.30 -113.88 117.06 5,959,647.65 550,418.36 3.06 160.91 3,221.00 20.18 141.41 3,196.74 3,101.74 -120.65 122.52 5,959,640.91 550,423.86 1.67 169.60 3,246.00 20.78 143.89 3,220.16 3,125.16 -127.61 127.82 5,959,633.99 550,429.21 4.22 178.34 3,271.00 20.51 140.41 3,243.55 3,148.55 -134.57 133.23 5,959,627.07 550,434.66 : 5.02 187.15 3,296.00 21.46 144.20 3,266.90 3,171.90 -141.65 138.69 5,959,620.03 550,440.18 6.63 196.09 3,321.00 21.31 143.33 3,290.17 3,195.17 -149.00 144.08 5,959,612.71 550,445.61 1.40 205.21 3,346.00 21.73 144.94 3,313.43 3,218.43 -156.44 149.45 5,959,605.31 550,451.03 2.90 214.37 11/4/2011 6:09:40PM Page 5 COMPASS 2003.16 Build 69 1 0 RI ORIGINAL AL Halliburton - Sperry Hlq •R LLI L ' - _- Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 1E-24 Company: ConocoPhillips(Alaska)Inc.-Kup1 ND Reference: ')'"`j Plan:1 E-24B @ 95.00ft(D141(28+67)) Project: Kuparuk River Unit MD Reference: Plan:1E-24B @ 95.00ft(D141(28+67)) Site: Kuparuk 1 E Pad North Reference: True Well: 1E-24 Survey Calculation Method: Minimum Curvature Wellbore: Plan:1E-246 Design: 1E-248(wp02) Armra Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N1-S +EJ-W Northing Easting DLS Vert Section (ft) (1 (*) (ft) ft (ft) (ft) (ft) (ft) 3,241.62 3,371.00 22.17 142.95 3,336.62 3,241.62 -163.99 154.95 5,959,597.80 550,456.58 3.46 223.72 3,396.00 22.10 146.06 3,359.78 3,264.78 -171.65 160.42 5,959,590.17 550,462.10 4.70 233.13 3,421.00 22.98 144.72 3,382.87 3,287.87 -179.54 165.87 5,959,582.32 550,467.60 4.08 242.71 3,446.00 23.78 144.26 3,405.82 3,310.82 -187.62 171.63 5,959,574.29 550,473.41 3.28 252.64 3,471.00 24.39 143.38 3,428.64 3,333.64 -195.85 177.65 5,959,566.09 550,479.49 2.83. 262.84 3,496.00 24.93 144.73 3,451.36 3,356.36 -204.29 183.77 5,959,557.69 550,485.67 3.12 273.27 3,521.00 25.35 141.25 3,473.99 3,378.99 -212.77 190.17 5,959,549.26 550,492.12 6.15 283.88 3,546.00 26.46 143.11 3,496.48 3,401.48 -221.40 196.86 5,959,540.68 550,498.87 5.50 294.80 3,571.00 27.67 143.49 3,518.74 3,423.74 -230.52 203.66 5,959,531.60 550,505.73 4.89 306.17 3,596.00 28.08 142.74 3,540.84 3,445.84 -239.87 210.67 5,959,522.30 550,512.80 2.16 317.86 3,621.00 29.08 142.67 3,562.79 3,467.79 -249.38 217.92 5,959,512.84 550,520.11 4.00 329.81 3,646.00 29.98 141.26 3,584.55 3,489.55 -259.09 225.51 5,959,503.19 550,527.77 4.55 342.13 3,671.00 30.85 140.29 3,606.11 3,511.11 -268.89 233.52 5,959,493.44 550,535.84 4.00 354.76 3,696.00 31.57 140.21 3,627.49 3,532.49 -278.85 241.80 5,959,483.53 550,544.19 2.88 367.69 3,721.00 32.13 138.94 3,648.72 3,553.72 -288.89 250.36 5,959,473.55 550,552.81 3.49 380.84 3,746.00 33.08 138.02 3,669.78 3,574.78 -298.97 259.29 5,959,463.53 550,561.81 4.29 394.24 3,771.00 34.43 136.59 3,690.57 3,595.57 -309.18 268.71 5,959,453.38 550,571.29 6.27 408.04 3,796.00 34.88 138.73 3,711.14 3,616.14 -319.69 278.28 5,959,442.94 550,580.94 5.19 422.16 3,821.00 36.12 138.08 3,731.49 3,636.49 -330.54 287.92 5,959,432.15 550,590.65 5.18 436.61 3,846.00 36.08 140.42 3,751.69 3,656.69 -341.70 297.53 5,959,421.06 550,600.33 5.52 451.29 3,871.00 36.12 138.36 3,771.89 3,676.89 -352.88 307.12 5,959,409.95 550,609.99 4.86 465.96 3,896.00 37.04 140.27 3,791.97 3,696.97 -364.18 316.83 5,959,398.71 550,619.78 5.85 480.81 3,921.00 35.54 138.94 3,812.12 3,717.12 -375.45 326.41 5,959,387.51 550,629.44 6.78 495.56 3,946.00 36.62 140.19 3,832.32 3,737.32 -386.66 335.96 5,959,376.37 550,639.06 5.23 510.24 3,971.00 36.01 138.52 3,852.47 3,757.47 -397.89 345.60 5,959,365.20 550,648.77 4.65 524.99 3,996.00 36.12 140.69 3,872.67 3,777.67 -409.10 355.14 5,959,354.06 550,658.38 5.13 539.66 4,021.00 36.39 138.78 3,892.84 3,797.84 -420.38 364.69 5,959,342.84 550,668.01 4.65 554.40 4,046.00 35.84 140.16 3,913.03 3,818.03 -431.58 374.27 5,959,331.71 550,677.66 3.93 569.09 4,071.00 36.36 139.85 3,933.23 3,838.23 -442.86 383.74 5,959,320.49 550,687.21 2.20 583.78 4,096.00 35.19 139.64 3,953.51 3,858.51 -454.02 393.18 5,959,309.40 550,696.72 4.71 598.36 4,121.00 36.11 140.18 3,973.83 3,878.83 -465.16 402.56 5,959,298.32 550,706.18 3.89 612.89 4,146.00 35.76 138.46 3,994.07 3,899.07 -476.29 412.13 5,959,287.26 550,715.81 4.27 627.51 4,171.00 35.20 140.85 4,014.43 3,919.43 -487.34 421.52 5,959,276.27 550,725.28 5.98 641.98 4,196.00 35.38 138.90 4,034.84 3,939.84 -498.39 430.83 5,959,265.29 550,734.66 4.56 656.38 4,221.00 35.60 140.71 4,055.19 3,960.19 -509.47 440.19 5,959,254.26 550,744.10 4.29 670.85 4,246.00 34.93 139.25 4,075.61 3,980.61 -520.53 449.47 5,959,243.27 550,753.45 4.31 685.25 4,271.00 35.56 141.07. 4,096.02 4,001.02 -531.60 458.71 5,959,232.26 550,762.77 4.90 699.64 4,296.00 34.97 139.46 4,116.44 4,021.44 -542.70 467.94 5,959,221.22 550,772.06 4.40 714.04 4,321.00 35.08 140.39 4,136.91 4,041.91 -553.68 477.17 5,959,210.31 550,781.37 2.18 728.35 4,346.00 36.16 140.13 4,157.23 4,062.23 -564.88 486.48 5,959,199.18 550,790.76 4.36 742.88 4,371.00 33.58 140.28 4,177.74 4,082.74 -575.86 495.63 5,959,188.26 550,799.98 10.33 757.14 4,396.00 35.63 139.75 4,198.32 4,103.32 -586.74 504.76 5,959,177.44 550,809.17 8.29 771.30 4,421.00 34.26 141.09 4,218.81 4,123.81 -597.77 513.88 5,959,166.47 550,818.37 6.28 785.59 4,446.00 35.26 140.22 4,239.35 4,144.35 -608.79 522.92 5,959,155.51 550,827.48 4.46 799.82 4,471.00 33.80 140.86 4,259.94 4,164.94 -619.73 531.92 5,959,144.63 550,836.56 6.02 813.96 11/4/2011 6:09:40PM Page 6 COMPASS 2003.16 Build 69 ORIGINAL Halliburton - Sperry <,,a - '1 _ 2 Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 1E-24 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Plan:1E-24B©95.00ft(D141(28+67)) Project: Kuparuk River Unit MD Reference: hIIVIN�IIIIIIIIIIIINIIIIIIHIIIIII& ;N'O IIIIIIIIIIIJ Plan:1E-24B @ 95.00ft(D141(28+67)) Site: Kuparuk 1E Pad North Reference: 'i True Well: 1E-24 Survey Calculation Method: Minimum Curvature Wellbore: Plan:1E-24B 11 Design: 1E-24B(wp02) ieitarmimr- __ Planned Survey iirKs5 iellIIIVI5llllllliln(ilin=FIIIIIIhIIIVIIIIW141 3"N @ice Y uworoIma lopiiiiIVINII@IIiINIIIIHIIIIIIIIm.(ir "IuIINIRIIIIIIIIIIIII'IIIIIIIIIIIIIng?A„V1hiVllllllllllIIllIIIIllI Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (1 (°) (ft) ft (ft) (ft) (ft) (ft) 4,185.59 4,496.00 34.84 139.96 4,280.59 4,185.59 -630.59 540.91 5,959,133 83 550,845.61 4.63 828.03 4,521.00 33.52 142.42 4,301.27 4,206.27 -641.53 549.71 5,959,122.96 550,854.49 7.64 842.05 4,546.00 33.55 139.70 4,322.11 4,227.11 -652.27 558.39 5,959,112.27 550,863.24 6.01 855.84 4,571.00 33.46 142.06 4,342.96 4,247.96 -662.98 567.10 5,959,101.63 550,872.02 5.22 869.62 4,596.00 33.27 140.06 4,363.84 4,268.84 -673.67 575.74 5,959,091.00 550,880.73 4.46 883.35 4,621.00 32.96 142.42 4,384.78 4,289.78 -684.32 584.29 5,959,080.41 550,889.35 5.30 896.99 4,646.00 32.95 139.77 4,405.76 4,310.76 -694.90 592.83 5,959,069.88 550,897.96 5.77 910.56 4,671.00 32.43 142.98 4,426.80 4,331.80 -705.44 601.25 5,959,059.40 550,906.45 7.24 924.05 4,696.00 32.06 140.16 4,447.94 4,352.94 -715.89 609.54 5,959,049.01 550,914.81 6.20 937.37 4,721.00 32.18 141.20 4,469.12 4,374.12 -726.17 617.96 5,959,038.78 550,923.30 2.26 950.64 4,746.00 32.06 143.25 4,490.29 4,395.29 -736.68 626.11 5,959,028.33 550,931.51 4.39 963.92 1 4,771.00 32.81 140.27 4,511.39 4,416.39 -747.20 634.41 5,959,017.86 550,939.88 7.06 977.32 1 4,796.00 32.81 142.25 4,532.41 4,437.41 -757.77 642.88 5,959,007.36 550,948.43 4.29 990.84 4,821.00 32.92 140.42 4,553.41 4,458.41 -768.36 651.36 5,958,996.82 550,956.97 4.00 1,004.39 4,846.00 33.69 142.63 4,574.30 4,479.30 -779.11 659.89 5,958,986.13 550,965.58 5.75 1,018.11 4,871.00 33.78 139.76 4,595.09 4,500.09 -789.92 668.59 5,958,975.38 550,974.35 6.39 1,031.97 4,896.00 33.95 142.23 4,615.85 4,520.85 -800.75 677.36 5,958,964.61 550,983.19 5.55 1,045.88 ' 4,900.00 34.03 142.02 4,619.17 4,524.17 -802.51 678.73 5,958,962.86 550,984.57 3.56 1,048.11 KOP(Colville,TOW wp02) 4,900.02 34.03 142.02 4,619.18 4,524.18 -802.52 678.74 5,958,962.85 550,984.58 0.00 1,048.12 TOW @ 4900'MD,4619'TVD:631'FNL,451'FWL Sec 22-T11 N-R1OE-7"TOW 4,915.60 35.47 144.45 4,631.99 4,536.99 -809.63 684.05 5,958,955.77 550,989.94 12.84 1,057.00 4,945.60 35.47 144.45 4,656.42 4,561.42 -823.80 694.17 5,958,941.68 551,000.15 0.00 1,074.41 5,000.00 33.65 146.56 4,701.22 4,606.22 -849.22 711.65 5,958,916.38 551,017.80 4.00 1,105.25 5,100.00 30.41 150.98 4,786.00 4,691.00 -894.48 739.21 5,958,871.30 551,045.65 4.00 1,158.07 5,200.00 27.35 156.33 4,873.58 4,778.58 -937.66 760.71 5,958,828.27 551,067.45 4.00 1,205.65 5,300.00 24.54 162.85 4,963.51 4,868.51 -978.56 776.06 5,958,787.49 551,083.07 4.00 1,247.77 5,400.00 22.07 170.83 5,055.37 4,960.37 -1,016.96 785.18 5,958,749.15 551,092.45 4.00 1,284.21 5,500.00 20.08 180.49 5,148.70 5,053.70 -1,052.68 788.03 5,958,713.45 551,095.54 4.00 1,314.81 5,595.63 18.75 191.31 5,238.93 5,143.93 -1,084.18 784.88 5,958,681.93 551,092.59 4.00 1,338.46 5,600.00 18.75 191.31 5,243.06 5,148.06 -1,085.56 784.60 5,958,680.56 551,092.32 0.00 1,339.41 5,700.00 18.75 191.31 5,337.75 5,242.75 -1,117.08 778.30 5,958,648.99 551,086.23 0.00 1,361.24 5,759.65 18.75 191.31 5,394.24 5,299.24 -1,135.89 774.54 5,958,630.17 551,082.60 0.00 1,374.26 5,800.00 20.36 190.81 5,432.26 5,337.26 -1,149.14 771.95 5,958,616.90 551,080.10 4.00 1,383.47 5,900.00 24.34. 189.84 5,524.73 5,429.73 -1,186.54 765.17 5,958,579.45 551,073.57 4.00 1,409.77 6,000.00 28.33 189.13 5,614.33 5,519.33 -1,230.29 757.88 5,958,535.66 551,066.57 4.00 1,440.91 6,100.00 32.32 188.58 5,700.63 5,605.63 -1,280.17 750.12 5,958,485.73 551,059.15 4.00 1,476.74 6,117.06 33.00 188.50 5,715.00 5,620.00 -1,289.28 748.75 5,958,476.62 551,057.84 4.00 1,483.31 6,132.56 33.00 188.50 5,728.00 5,633.00 -1,297.63 747.51 5,958,468.26 551,056.65 0.00 1,489.34 Top HRZ(K-2 Marker) 6,200.00 33.00 188.50 5,784.56 5,689.56 -1,333.95 742.08 5,958,431.90 551,051.47 0.00 1,515.56 6,300.00 33.00 188.50 5,868.42 5,773.42 -1,387.82 734.03 5,958,377.99 551,043.78 0.00 1,554.45 6,387.73 33.00 188.50 5,942.00 5,847.00 -1,435.07 726.97 5,958,330.69 551,037.03 0.00 1,588.57 Top Kalubik(Base HRZ) 11/4/2011 6:09:40PM Page 7 COMPASS 2003.16 Build 69 ORIGINAL Halliburton -Sperry FILLI_-.-.. TIT _ Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 1E-24 Company: ConocoPhillips(Alaska)Inc.-Kup1 ND Reference: Plan:1 E-24B @ 95.00ft(D141(28+67)) Project Kuparuk River Unit MD Reference: Plan:1 E-24B @ 95.00ft(D141(28+67)) • Site: Kuparuk 1 E Pad North Reference: True Well: 1E-24 Survey Calculation Method: Minimum Curvature Wellbore: Plan:1E-24B Design: 1E-24B(wp02) Planned Survey I 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) 5,857.29 6,400.00 33.00 188.50 5,952.29 5,857.29 -1,441.68 725.98 5,958,324.08 551,036.09 0.00 1,593.34 Casing Pt @ 6400'MD,5952'TVD:1271'FNL,497'FWL-Sec 22-T11 N-R10E-5 1/2" 6,471.20 33.00 188.50 6,012.00 5,917.00 -1,480.03 720.25 5,958,285.69 551,030.62 0.00 1,621.02 K-1 Marker 6,500.00 33.00 188.50 6,036.16 5,941.16 -1,495.55 717.93 5,958,270.17 551,028.40 0.00 1,632.22 6,554.66 33.00 188.50 6,082.00 5,987.00 -1,524.99 713.53 5,958,240.70 551,024.20 0.00 1,653.48 Top C Sand-1E-24B C-Sand(wp02) 6,600.00 33.00 188.50 6,120.02 6,025.02 -1,549.41 709.88 5,958,216.25 551,020.71 0.00 1,671.11 6,633.36 33.00 188.50 6,148.00 6,053.00 -1,567.38 707.19 5,958,198.27 551,018.15 0.00 1,684.08 Top B Shale 6,700.00 33.00 188.50 6,203.89 6,108.89 -1,603.28 701.83 5,958,162.34 551,013.02 0.00 1,710.00 6,762.13 33.00 188.50 6,256.00 6,161.00 -1,636.75 696.82 5,958,128.84 551,008.25 0.00 1,734.16 Top A6.. 6,774.06 33.00 188.50 6,266.00 6,171.00 -1,643.17 695.86 5,958,122.41 551,007.33 0.00 1,738.79 Top A5 6,800.00 33.00 188.50 6,287.76 6,192.76 -1,657.15 693.78 5,958,108.43 551,005.34 0.00 1,748.88 6,803.87 33.00 188.50 6,291.00 6,196.00 -1,659.23 693.47 5,958,106.34 551,005.04 0.00 1,750.39 Top A4 6,881.37 33.00 188.50 6,356.00 6,261.00 -1,700.98 687.23 5,958,064.56 550,999.08 0.00 1,780.52 Top Miluveach 6,900.00 33.00 188.50 6,371.63 6,276.63 -1,711.01 685.73 5,958,054.51 550,997.65 0.00 1,787.77 6,966.02 33.00 188.50 6,426.99 6,331.99 -1,746.57 680.41 5,958,018.92 550,992.57 0.00 1,813.44 BHL @6966'MD,6427'ND:1576'FNL,451'FWL Sec 22.711N-R10E-3 1/2 6,966.03 33.00 188.50 6,427.00 .6,332.00 -1,746.58 680.41 5,958,018.92 550,992.57 0.00 1,813.44 Targets Target Name -hit/miss target Dip Angle Dip Dir. ND +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) 1E-24B C-Sand(wp02) 0.00 0.00 6,082.00 -1,524.99 713.53 5,958,240.70 551,024.20 -plan hits target center -Circle(radius 150.00) 1E-24B A4(wp02) 0.00 0.00 6,259.00 -1,638.89 696.76 5,958,126.70 551,008.20 -plan hits target center -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter IIII otlIIIINIHIuIIIIIVu1MIIIIltllIIIIulVdunlumu (ft) (ft) Name (") (") 4,900.02 4,619.18 7"TOW 7 8-3/4 6,400.00 5,952.29 5 1/2" 5-1/2 7 6,966.02 6,426.99 3 1/2" 3-1/2 4-3/4 2,387.00 2,386.94 10 3/4" 10-3/4 13-1/2 11/4/2011 6:09:40PM Page 8 COMPASS 2003.16 Build 69 ORIGiNAL Halliburton -Sperry HEAL I B U RTD- - Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 1E-24 Company: ConocoPhillips(Alaska)Inc.-Kup1 ND Reference: PIan:1 E-24B @ 95.00ft(D141(28+67)) 11 Project: Kuparuk River Unit MD Reference: PIan:1E-24B @ 95.00ft(D141(28+67)) Site: Kuparuk 1E Pad North Reference: True 10 Well: 1E-24 Survey Calculation Method: Minimum Curvature Wellbore: Plan:1E-24B Design: 1E-24B(wp02) Formations Measured Vertical Vertical ' Dip Depth Depth Depth SS - Dip Direction (ft)) (ft ) ft. Name ?v Lithology iu ; r) (1 6,762.13 6,256.00 Top A6 0.00 6,471.20 6,012.00 K-1 Marker 0.00 6,633.36 6,148.00 Top B Shale 0.00 6,387.73 5,942.00 Top Kalubik(Base HRZ) 0.00 6,774.06 6,266.00 Top A5 0.00 6,803.87 6,291.00 Top A4 0.00 4,900.00 4,619:17 KOP(Colville,TOW wp02) 0.00 6,132.56 5,728.00 Top HRZ(K-2 Marker) 0.00 6,881.37 6,356.00 Top Miluveach 0.00 6,554.66 6,082.00 Top C Sand 0.00 Plan Annotations 1 'II Measured Vertical Local Coordinates Depth Depth +N/-S +EJ-W (ft) (ft) (ft) (ft) Comment 4,900.02 4,619.18 -802.52 678.74 TOW @ 4900'MD,4619'ND:631'FNL,451'FWL-Sec 22-T11 N-R10E 6,400.00 5,952.29 -1,441.68 725.98 Casing Pt @ 6400'MD,5952'TVD:1271'FNL,497'FWL-Sec 22-T11N-R10E 6,966.02 6,426.99 -1,746.57 680.41 BHL @ 6966'MD,6427'TVD:1576'FNL,451'FWL-Sec 22-T11 N-R10E 11/4/2011 6:09:40PM Page 9 COMPASS 2003.16 Build 69 � � rn n • m al 3 c 0 —1 a z L a� ▪ a N r In CL C 0 in co 1Hr N O3 VIN Z o 0 Z w m m c CZ Lin Z , o t p ro m E - ICC a tau (13 0 mem • W O L = m N - to i W m O 0 d V+a. 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V N N N M M V _ V O O a rn a o co+ ¢+ IT . w to p N 'p N O O N On NO u) U 0, U+ CD= Z r Crn Z r CO a3 m a a N N N N O m O m r a� 3 a� u)1-CO u)r- o 03 N Lc, etTi m N Q M N ¢ 6 w ° w m W W o — o o N o 3 Q m3 a N ti d U CI Ti U C U x 0 O C O C d O QI O N V Lci L 6 N d r a r m L CD co to d N n co N CC 0 el E z x co N 6 J O L 0 0 a t O V N O O O` N 3 C Q :.i G = Q m Q Q =c: N Qu▪ 9 p N 0 . 0 O cn t. c Q O U N N - O N . 1E-24B SIDETRAC =_ 3 'h" TRMAXX-CMT safety valve 2.813"ID at 1,895'MD/1,800'TVD Topset 5-1/2" Liner ■ 10-3/4"45.5#K-55 @ 2,398'MD/2,398'TVD Sidetrack KOP GLM# Type MD TVD Valve Type out window 1 KBG2-9 2,500' 2,500' Dummy @ 4,915'MD 2 KBG2-9 3,721' 3,650' Dummy 3 KBG2-9 4,754' 4,500' Dummy 4 KBG2-9 5,515' 5,111' Dummy 5 SOV 6,123' 5,611' Annulus to tubing shear e.< • 3-'z"9.3#,L-80,IBTM w/ - ' 3.865"O.D.Special Clearance :• m.. couplings Casing cmt retainer :::'- '^ " TOC on5-'A" @ 5,000'MD @+/-4,900'MD (above liner top) Squeeze perfs ............... ... below retainer sl//ii, I //I, , 3 'h" CMU Sliding Sleeve w/2.813" 4141 DS Profile(closed position) @ 6,100'MD/5,700'TVD 3 'h" HES"X"selective 3 'h"liner Seal "` "" nipple w/2.813"@ 6,123' Assembly MD/5,720'TVD @ 5371 MD 3-'/2"TOL @ 5,360'MD ....,..Tii....... -.......::::;:::::::.::::::::::::::::. `: 3-1/2"x 5-1/2" v.% 44,.``:: Liner Hanger&Packer @ 6,200'MD/5,785'TVD _ - Perls @ 7,344'-7,900' 5-1/2"Hydri1563, 15.5# set @ 6,400'MD/5,952'TVD 3-1/2"9.3#L-80 3-1/2"Hydril 511,9.3#liner 8,167'MD/6,443'TVD set @6,966'MD/6,427'TVD 0 R4iNAL 1E-24B Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) 7" Hole with 5-1/2" Liner Interval* Ri Event Vel Mitigation Strategy LeWindow/ Open Hole leak Moderate Squeeze 7" casing at window off less than required Hole instability while Moderate Utilize a mud weight to stabilize formations without drilling shale section sustaining losses Placement of KOP and bottom hole location to allow for 4° Directional control Moderate DLS. Use a bi-center bit or underreamer with successful past performance. Drill 6"X 7"hole with proper mud weight for hole Run liner to bottom Moderate stability, directional plan with 4° DLS and a tangent from HRZ to TD, and run 5-1/2" 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. Abnormal Reservoir BOPE drills, keep mud weight above 9.5 ppg, 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. Tracking along 7" casing Moderate Perforate 7" casing and squeeze cement in 7"X 8-1/2" during window milling annulus. Cement Bonding Moderate Run liner with centralization for standoff Reciprocate during circulation and pump 35% excess cement. Hydrogen Sulfide Gas Low H2S drills, detection systems, alarms, and standard well control practices. *See Well Plan for more detailed risk information and offset data. 4-3/4" Hole with 3-1/2" Liner Interval* Event RiskeMitigation Strategy LeLeak off test less than Low Squeeze 5-1/2" liner casing shoe. required Hole instability while Moderate Utilize a mud weight to stabilize formatioins without drilling shale section sustaining losses Directional control Low Tangent part of well. Run liner to bottom Moderate Drill 4-3/4"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 11.0 ppg, check for Abnormal Reservoir Moderate flow during connections and if needed increase mud Pressure weight. Area injectors have been shut in to reduce reservoir pressure. Reduced pump rates, real time equivalent circulating Lost Circulation Low density (ECD) monitoring, mud rheology, and LCM. Use GKA LC decision tree as needed. Run liner with centralization for standoff. Reciprocate Cement Bonding Moderate during circulation and pump 35% excess cement. Hydrogen Sulfide Gas Low H2S drills, detection systems, alarms, and standard well control practices. *See Well Plan for more detailed risk information and offset data. Txaa' E V rx_x OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL/ - /6- � LETTER CHECKLIST WELL NAME - /L, � -Z PTD# 7—/ I ( S i Development Service Exploratory Stratigraphic Test Non -CConventional Well ) • FIELD: /�-� �i POOL: /6r-7-Liz -�'�'`C� ! I Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 m m m T o a o n 0 ° a 0 'o 0 r I— o 3CD � S 3.o . -, m N.� � v jv `� - v o j XI p CO v v (b 0 3 O 7 n N m N a N (D CD o c) o CO CO w CO CO w CO w CO CO N N N N N N N N) N N _, (O co V O) 01 A w N o n CO CO V CO Cn A CO N — 0 CO ()D V CO CO A CO N — 0 (0 CO Cr) 01 A W N) — 0 V a m ,nnwom K E g n W co o � D Dnnnnwn -oDn -o -000 �, ngg * c (n vz 0 o O CD (D CCD a. oSOOa n n 0 n U CO . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Weil History file and to simpirfy finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Jan 31 15:48:10 2012 Reel Header Service name LISTPE Date 12/01/31 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 12/01/31 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: 1E-24B API NUMBER: 500292085702 OPERATOR: ConocoPhillips Alaska, Inc LOGGING COMPANY: Sperry Drilling TAPE CREATION DATE: 31-JAN-12 JOB DATA MWD RUN 1 MWD RUN 3 MWD RUN 4 JOB NUMBER: -XX-0008472252 -XX-0008472252 -XX-0008472252 LOGGING ENGINEER: BLAKE DELANE BLAKE DELANE BRETT HARVEY OPERATOR WITNESS: LARRY HILL LARRY HILL LARRY HILL MWD RUN 5 JOB NUMBER: -XX-0008472252 LOGGING ENGINEER: BRETT HARVEY OPERATOR WITNESS: GUY WHITLOCK # r� SURFACE LOCATION SECTION: 16 n TOWNSHIP: 11N RANGE: 10E c FNL: FSL: 171 FEL: 226 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 93.80 GROUND LEVEL: 67.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS I — IS { BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 7.000 7.625 4913.0 2ND STRING 4 .750 5.500 6458.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) . 3. THIS SIDETRACK EXITED 1E-24A BY MEANS OF A WHIPSTOCK, THE TOP OF WHICH WAS AT 4913'MD/4629'TVD. THE WINDOW WAS MILLED AND ABOUT 20' OF RAT HOLE WERE DRILLED DURING MWD RUN 1. ONLY ROP DATA ARE PRESENTED FOR THIS RUN. MWD RUN 2 WAS A CLEAN-OUT RUN - NO DATA ARE PRESENTED. 4. MWD RUNS 3, 4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTIL- IZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY-PHASE 4 (EWR-P4) , DRILLSTRING DYNAMICS SENSOR (DDSr) , AND PRESSURE WHILE DRILLING (PWD) . 5. MWD RUN 5 COMPRISED DIRECTIONAL, DGR, AND SUPER-SLIM EWR-P4 (WITH DIFFERENT SENSOR SPACINGS THAN THE EWR-P4 TOOL IN RUNS 3 & 4) . 6. LWD DATA ARE CONSIDERED PRIMARY DEPTH CONTROL PER PHONE CONVERSATION BETWEEN LAIRD LITTLE (CPAI) AND BUSTER BRYANT (SD) ON 18 JUNE 2012. 7. MWD RUNS 1-5 REPRESENT WELL 1E-24B WITH API# 50-029-20857-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6940'MD/6411'TVD. MNEMONICS CURVE DESCRIPTION ROPA AVERAGE RATE OF PENETRATION DGRC DGR COMBINED GAMMA RAY R09P 9 INCH PHASE RESISTIVITY R12P 12 INCH PHASE RESISTIVITY R15P 15 INCH PHASE RESISTIVITY R2OP 20 INCH PHASE RESISTIVITY R27P 27 INCH PHASE RESISTIVITY R28P 28 INCH PHASE RESISTIVITY R39P 39 INCH PHASE RESISTIVITY R44P 44 INCH PHASE RESISTIVITY EWXT EWR FORMATION EXPOSURE TIME ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/01/31 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 4892.0 6883.5 RPM 4905.0 6895.0 RPX 4905.0 6895.0 FET 4905.0 6895.0 RPS 4905.0 6895.0 RPD 4905.0 6895.0 ROP 4922.0 6940.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 4922.0 4945.5 MWD 3 4945.5 5896.0 MWD 4 5896.0 6460.0 MWD 5 6460.0 6940.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 FET MWD HR 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4892 6940 5916 4097 4892 6940 GR MWD API 27.79 514.32 130.966 3984 4892 6883.5 FET MWD HR 0.53 114.46 5.71945 3916 4905 6895 RPX MWD OHMM 0.73 1731.22 5.1067 3916 4905 6895 RPS MWD OHMM 0.71 1957.32 12.6877 3916 4905 6895 RPM MWD OHMM 0.14 2000 10.8916 3916 4905 6895 RPD MWD OHMM 0.2 2000 12.6476 3916 4905 6895 ROP MWD FPH 0.03 154.08 45.5022 4037 4922 6940 First Reading For Entire File 4892 Last Reading For Entire File 6940 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/01/31 Maximum Physical Record65535 File Type LO Next File Name STSLIB.002 Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/01/31 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROPA 4922.0 4945.5 LOG HEADER DATA DATE LOGGED: 16-DEC-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 4946.0 TOP LOG INTERVAL (FT) : 4922.0 BOTTOM LOG INTERVAL (FT) : 4946.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 34.0 MAXIMUM ANGLE: 34.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER # $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 7.000 DRILLER'S CASING DEPTH (FT) : 4913.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9.20 MUD VISCOSITY (S) : 46.0 MUD PH: 9.4 MUD CHLORIDES (PPM) : 550 FLUID LOSS (C3) : 6.1 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : MUD AT MAX CIRCULATING TERMPERATURE: 111.2 MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FPH 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4922 4945.5 4933.75 48 4922 4945.5 ROP MWD010 FPH 9.51 46.55 21.9583 48 4922 4945.5 First Reading For Entire File 4922 Last Reading For Entire File 4945.5 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/01/31 Maximum Physical Record65535 File Type LO Next File Name STSLIB.003 Physical EOF File Header Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/01/31 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 4892.0 5842.5 R39P 4905.0 5849.5 R15P 4905.0 5849.5 EWXT 4905.0 5849.5 R27P 4905.0 5849.5 R09P 4905.0 5849.5 ROPA 4946.0 5896.0 LOG HEADER DATA DATE LOGGED: 18-DEC-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.47 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 5896.0 TOP LOG INTERVAL (FT) : 4946.0 BOTTOM LOG INTERVAL (FT) : 5896.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 15.9 MAXIMUM ANGLE: 36.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10436096 EWR4 Electromag Resis. 4 167219 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 7.000 DRILLER'S CASING DEPTH (FT) : 4913.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9.90 MUD VISCOSITY (S) : 46.5 MUD PH: 9.4 MUD CHLORIDES (PPM) : 700 FLUID LOSS (C3) : 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 2.400 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.360 120.0 MUD FILTRATE AT MT: 2.000 65.0 MUD CAKE AT MT: 2.500 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD030 API 4 1 68 4 2 FET MWD030 HR 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 ROP MWD030 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4892 5896 5394 2009 4892 5896 GR MWD030 API 52.07 238.67 136.866 1902 4892 5842.5 FET MWD030 HR 0.53 112.33 6.42993 1890 4905 5849.5 RPX MWD030 OHMM 0.75 1731.22 5.35112 1890 4905 5849.5 RPS MWD030 OHMM 0.76 1957.32 5.41942 1890 4905 5849.5 RPM MWD030 OHMM 0.14 2000 9. 91351 1890 4905 5849.5 RPD MWD030 OHMM 0.2 1317.12 3.56122 1890 4905 5849.5 ROP MWD030 FPH 0.03 145.64 56.4674 1901 4946 5896 First Reading For Entire File 4892 Last Reading For Entire File 5896 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/01/31 Maximum Physical Record65535 File Type LO Next File Name STSLIB.004 Physical EOF File Header Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/01/31 Maximum Physical Record65535 File Type LO • Previous File Name STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 5843.0 6406.0 R39P 5850.0 6413.0 R27P 5850.0 6413.0 R15P 5850.0 6413.0 EWXT 5850.0 6413.0 R09P 5850.0 6413.0 ROPA 5896.5 6460.0 LOG HEADER DATA DATE LOGGED: 20-DEC-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.47 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 6460.0 TOP LOG INTERVAL (FT) : 5896.0 BOTTOM LOG INTERVAL (FT) : 6460.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 24 .3 MAXIMUM ANGLE: 34 .1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10907643 EWR4 Electromag Resis. 4 10959183 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 7.000 DRILLER'S CASING DEPTH (FT) : 4913.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 10.00 MUD VISCOSITY (S) : 44.0 MUD PH: 9.7 MUD CHLORIDES (PPM) : 400 FLUID LOSS (C3) : 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 2.400 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 3.310 122.7 MUD FILTRATE AT MT: 2.300 72.0 MUD CAKE AT MT: 2.500 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: • Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD040 API 4 1 68 4 2 FET MWD040 HR 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 ROP MWD040 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5843 6460 6151.5 1235 5843 6460 GR MWD040 API 70.16 514.32 170.278 1127 5843 6406 FET MWD040 HR 0.71 18. 68 2.76367 1127 5850 6413 RPX MWD040 OHMM 0.73 6.57 2.28947 1127 5850 6413 RPS MWD040 OHMM 0.71 5.58 2.22012 1127 5850 6413 RPM MWD040 OHMM 0.65 5.19 2.17788 1127 5850 6413 RPD MWD040 OHMM 0. 68 4.56 2.19994 1127 5850 6413 ROP MWD040 FPH 1.2 154.08 50.886 1128 5896.5 6460 First Reading For Entire File 5843 Last Reading For Entire File 6460 File Trailer Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/01/31 Maximum Physical Record65535 File Type LO Next File Name STSLIB.005 Physical EOF File Header Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/01/31 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GMGR 6406.5 6883.5 R20P 6446.0 6895.0 R44P 6446.0 6895.0 R28P 6446.0 6895.0 EWXT 6446.0 6895.0 R12P 6446.0 6895.0 ROPA 6460.5 6940.0 LOG HEADER DATA DATE LOGGED: 26-DEC-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 6940.0 TOP LOG INTERVAL (FT) : 6460.0 BOTTOM LOG INTERVAL (FT) : 6940.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 32.5 MAXIMUM ANGLE: 33.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 93091 EWR4 ELECTROMAG. RESIS. 4 10178424 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 4.750 DRILLER'S CASING DEPTH (FT) : 6458.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 11. 60 MUD VISCOSITY (S) : 48.0 MUD PH: 9.4 MUD CHLORIDES (PPM) : 450 FLUID LOSS (C3) : 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 2.200 66.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.080 141.8 MUD FILTRATE AT MT: 3.950 66.0 MUD CAKE AT MT: 1.850 66.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FET MWD050 HR 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 ROP MWD050 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6406.5 6940 6673.25 1068 6406.5 6940 FET MWD050 HR 1.43 114.46 7.93119 899 6446 6895 GR MWD050 API 27.79 137.76 72.8222 955 6406.5 6883.5 RPX MWD050 OHMM 1.27 694.24 8.12459 899 6446 6895 RPS MWD050 OHMM 1.29 1925.22 41.0906 899 6446 6895 RPM MWD050 OHMM 1.35 1659.33 23.8715 899 6446 6895 RPD MWD050 OHMM 1.41 2000 44.8477 899 6446 6895 ROP MWD050 FPH 0.09 52.19 18. 6402 960 6460.5 6940 First Reading For Entire File 6406.5 Last Reading For Entire File 6940 File Trailer Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/01/31 Maximum Physical Record65535 File Type LO Next File Name STSLIB.006 Physical EOF Tape Trailer Service name LISTPE Date 12/01/31 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 12/01/31 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File FINAL WELL REPORT MUDLOGGING DATA 1E-24B Approved by: Laird Little Compiled by: James Foradas Joshua Dubowski Distribution: January 9, 2012 Date: December 26, 2011 1E-24B 2 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ................................................................................................ 3 1.1 Equipment Summary ...................................................................................................................... 3 1.2 Crew................................................................................................................................................ 4 2 WELL DATA ........................................................................................................................................... 5 2.1 Well Summary................................................................................................................................. 5 2.2 Hole Data ........................................................................................................................................ 5 2.3 Well Synopsis ................................................................................................................................. 5 3 GEOLOGICAL DATA ............................................................................................................................. 6 3.1 Formation Tops: .............................................................................................................................. 6 3.2 Lithologic Descriptions/Stratigraphy ............................................................................................... 7 3.3 Connection Gas Summary: ........................................................................................................... 11 3.4 Trip/Wiper Gas Summary ............................................................................................................. 12 3.5 Sampling Program / Sample Dispatch .......................................................................................... 13 4 PRESSURE / FORMATION STRENGTH DATA ................................................................................. 14 4.1 Pore Pressure Gradient Evaluation .............................................................................................. 14 4.2 Quantitative Methods .................................................................................................................... 15 5 DRILLING DATA .................................................................................................................................. 16 5.1 Daily Activity.................................................................................................................................. 16 5.2 Survey Data .................................................................................................................................. 18 5.3 Bit Record ..................................................................................................................................... 19 5.4 Mud Record: ................................................................................................................................. 20 5.4.1 Mud Record for 7” Hole ......................................................................................................... 20 5.4.2 Mud Record for 4 3/4” hole .................................................................................................... 20 6 DAILY REPORTS ................................................................................................................................ 21 Enclosures: 2”/100’ Formation Log (MD and TVD) 2”/100’ LWD Combo Log (MD and TVD) 2”/100’ Drilling Dynamics Log (MD and TVD) 2”/100’ Gas Ratio Log (MD and TVD) Final Well Data on CD ROM 1E-24B 3 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Downtime Comments Ditch gas QGM agitator and gas trap Flame ionization total gas and chromatography. 0 Hook Load, Weight on bit TOTCO WITS Feed 0 Mud Flow In Derived from Pump Stroke Rates* and Pump Output 0 Mud Flow Out TOTCO WITS Feed* 0 Mudlogging Unit computer systems HP Compaq Pentium 4 (x2: DML & RigWatch) 0 Mudlogging Unit Acromeg box In-unit data collection/distribution center 0 Pit Volumes, Pit Gain/Loss TOTCO WITS Feed* 0 Pump Pressure TOTCO WITS Feed* 0 Pump Strokes TOTCO WITS Feed* 0 TOTCO Well Monitoring Components TOTCO computer networked in mud logging unit* 0 Rate of Penetration Derived from TOTCO depth tracking components (block height*) 0 RPM TOTCO WITS Feed* 0 Torque TOTCO WITS Feed* 0 1E-24B 4 1.2 Crew Unit Number: ML056 Unit Type: Custom/Arctic/Steel Logging Geologist Years of Experience Days at 1E-24B Sample Catchers Years of Experience Days at 3H-34 Technician Days at 1E-24B Joshua Dubowski 4 12/13 Dickie Hudgins 3 12 Allen Williams 5 James Foradas 5 12/13 Steve Franzen 4 12 Steve Forrest 1 1E-24B 5 2 WELL DATA 2.1 Well Summary Well: 1E-24B API Index #: 50-103-20857-02-00 Field: Kuparuk River Unit Surface Co-Ordinates: 5959760.73N 550300.55E Borough: North Slope Primary Targets: Top of A4 sand State: Alaska Primary Target Depth: 6804’MD/6196’SSTVD Rig Name / Type: Doyon 141/Arctic Triple Primary Actual Depth 6779’MD/6181’SSTVD Spud Date: December 15, 2011 TD Depth: 6940’MD/6316’SSTVD TD Date: December 26, 2011 Ground Elevation: 67.0’ Days Drilling: 11 KB Elevation: 93.8’ Completion Status: TD Formation: Miluveach Classification: Sidetrack for CTD Laterals Days Evaluating: None 2.2 Hole Data Hole Section Maximum Depth TD Formation Mud Weight (ppg) Dev. (oinc) Casing/ Liner Shoe Depth LOT (ppg) MD (ft) TVD (ft) MD (ft) TVD (ft) 1E-24A* 6.276” 4913 Cased Hole. 9.7 10-3/4” 4900’ 4524’ 1E-24B 6.276” 4926 4641’ Milling Window 9.7 34.91 6.276” 4926’ 4641 6.15” 4946 4657’ Initial Kickoff 9.7 34.91 6.276” 4946 4657’ 7.0” 6460 6007’ Colville fmn 60’ TVD above the C sand 10.0 33.64 5.5” 6460 6007’ 4-3/4” 6940 6411’ Miluveach 11.8 31.95 3.5” 6937 6409’ 16 * Previously drilled and cased well bore. 2.3 Well Synopsis KRU 1E-24B is a sidetrack off an existing well (1E-24A targeting the top of the Kuparuk A4 sand. The sidetrack will serve as a Kick-off-point for two production (CTD) laterals to be drilled with coiled-tubing. The horizontal laterals will extend east (lower window ~ 6743’ MD) and west (upper window ~ 6722’ MD) and will be logged as a separate project. A mill bit was used to kick off 1E-24B at a measured depth of 4913’ MD (--- ‘TVD) to a window depth of 4926 (4641‘TVD). Directional Drilled to a total depth of 6940’ MD (6411’ TVD). 3.5” Liner was cemented in place to prepare the well for coiled tubing drilling in the A Sands. 1E-24B 6 3 GEOLOGICAL DATA 3.1 Formation Tops: Zone or Horizon Prognosed Depth (ft) Actual Depth (ft) MD TVD SS MD TVD SS KOP (Colville) 4900 4524 Top of HRZ 6133 5633 6117 5720 5625 Top Kalubik (base HRZ) 6388 5847 6365 5930 5835 K-1 Marker 6471 5917 Top of C sand 6555 5987 6526 6064 5969 Top of B shale 6633 6053 6606 6131 6036 Top A6 6762 6161 6739 6242 6147 Top A5 6774 6171 6752 6253 6158 Top A4 6804 6196 6779 6276 6181 Top of Miluveach 6881 6261 6865 6349 6254 TD 6966 6332 6940 6411 6316 Note: Horizons and Depths provided by the Wellsite Geologist. Only data provided are listed. 1E-24B 7 3.2 Lithologic Descriptions/Stratigraphy COLLVILLE TO TOP OF HRZ: (4900' MD /-4524’ TVDSS to 6133’ MD /-5625’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 266 4.5 59 461 10 74 Gas Peaks Depth(MD) TG C1 C2 C3 iC4 nC4 iC5 nC5 5377 74 12611 684 142 16 40.147 5872’ 461 77901 7054 2645 297 538 45 0 Gas is generally low in this formation section with one notable drilled gas peak. The gas peak appears to originate immediately below the "shale wall" shown in well 1E-24A at 5850' MD and may represent injection gas. The Colville formation is composed of claystone, siltstone and a small amount of sandstone. Claystones in this section appear medium gray to light or dark medium gray with occasional brown or blackish hues. soft; non to poorly indurated; cohesive and adhesive; pulverized claystone clumped in mushy cohesive lumps; tacky to somewhat pasty; irregular fracture; massive cuttings habit; waxy to earthy luster; clayey to silty texture; massive bedding structure; silt; very fine to lower fine quartz sand imbedded within claystone matrix; no petroleum indicators. Siltstones are light medium gray to medium gray with occasional olive gray hues; friable to easily friable; moderately to poorly indurated; tabular to nodular cuttings; silty to abrasive texture; tough to crunchy and fairly dense occasionally brittle and crumbly; occasional thin black and brown laminations in fragments under higher magnification; sample does not appear to be fissile along laminations. Sandstones are commonly white to light gray with bluish, greenish and darker gray hues; very fine grained quartz framework with some coarser grains. Well sorted; sub angular to rounded angularity; moderate to high sphericity; some frosting and polish; friable to moderately hard; cement is calcareous in part; grain supported; thinly bedded and interbedded with thin beds of shale and veins of dolomite and quartz; shale is dark gray and similar in character to claystone described immediately above; no visible hydrocarbon indicators; fine cuttings dominate giving salt and pepper appearance to sample. HRZ TO TOP OF KALUBIK: (6117’ MD / -5625 TVDSS to 6365’ MD / -5835’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 131 14 50 314 42 119 Gas Peaks Depth(MD) TG C1 C2 C3 iC4 nC4 iC5 nC5 6228’ 110 55740 5041 1772 172 381 14 Gas is low to moderate in this formation section with one notable peak. This interval consists of shale. 1E-24B 8 The shales in this section are typically medium to dark gray to greenish gray with brownish and black hues; dense to brittle tenacity; irregular blocky to planar fracture; very fine to fine platy to flaky cutting habit; dull to resinous luster becoming sparkling at higher magnification and illumination; laminar structure with alternating light and dark bands on some specimens. Rare weak yellowish fluorescence with a milky white cut. TOP OF KALUBIK TO TOP OF C SAND: (6365’ MD / -5835’ TVDSS’ TO 6526’ MD / -5969’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 64.5 3.6 28.2 1447 5 146 Gas Peaks Depth(MD) TG C1 C2 C3 iC4 nC4 iC5 nC5 6365’ 77 13095 981 407 28 120 0 0 6482’ 191 40781 4067 1884 244 490 50 53 6502 1447 866304 62236 27280 3247 6130 Total gas was generally moderate in this section of the formation with a few spikes associated with sandstone and possibly injection gas trapped below the “shale wall” and other traps. Pump pressure spikes also appear to correlate with the thin, hard sandstone beds This interval generally consists of siltstone, with minor thin resistant sandstone beds and moderate amounts of light brown to tan claystone. The siltstone is medium brownish gray to dark gray with blackish hues; moderate induration; tough to dense to occasionally crumbly; has planar fracture and elongated to wedgelike cuttings habit. It exhibits resinous to earthy luster; and has silty to gritty texture. Small amounts of what appears to be free standing oil; but no fluorescence or cut were observed in samples. TOP OF C SAND TO TOP OF B SHALE: (6526’ MD / -5969’ TVDSS’ TO 6606’ MD / -6036’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 38.3 9.9 29.6 114 35 82.4 Gas Peaks Depth(MD) TG C1 C2 C3 iC4 nC4 iC5 nC5 6581’ 114 17075 1610 763 82 287 22 27 Total gas was generally low in this section of the formation. This interval generally consists of primarily unconsolidated sandstone logged as sand. The sand is light medium gray to light gray to occasionally dark yellowish orange; is upper to lower fine grained; has moderate to good sphericity; sub rounded to rounded to occasionally subangular angularity; is well sorted; unconsolidated; with clay infill. It is grain supported; with composition dominated by clear to translucent to milky white quartz. Small amounts of clay and siltstone and trace amounts of pyrite and carbonaceous shale are also present in samples. Hydrocarbon indicators include: mild hydrocarbon odor; no fluorescence; slow bright bluish white cut; and yellowish white residual cut. 1E-24B 9 TOP OF B SHALE TO TOP OF RESERVOIR (A6): (6606’ MD / -6036’ TVDSS TO 6739’ MD / -6147’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 37 5.8 26.3 131 26 75.7 Gas Peaks Depth(MD) TG C1 C2 C3 iC4 nC4 iC5 nC5 6647 131 21898 1835 860 109 296 32 19 Total gas was generally low in this section of the formation. Gas correlates with drill rate and rock type with sandstones being slightly gassier. This interval is comprised of sandstone, sand, and claystone. Sample quality was moderate from abundant nutplug and dark mud additives. The sandstone is light gray with white and yellowish hues. It has a quartz framework; is upper fine to lower coarse grained; poor to well sorted; has subangular to subrounded angularity; and moderate sphericity. Some abrasion is evident on grain surfaces. Much of it is represented by unconsolidated sand. Firmer specimens are better sorted. The sandstones are generally grain supported and dominated by translucent and clear quartz with a trace of glauconite. Hydrocarbon indicators do not include odor or fluorescence, but a residual milky white cut was observed. These rocks are calcareous in part; and interbedded with thin beds of shale, carbonaceous shale, and siltstone that is also calcareous in part. Claystone is partly carbonaceous and black to dark gray with medium gray hues and pyrite colored speckles. The rock is tough to crumbly; has irregular blocky fracture; fine cuttings habit with some coarser planar cuttings. Dull to sparkling luster and smooth to gritty textures exhibited. Pyrite lamina and speckles are common. The rocks are also slightly calcareous and interbedded with lighter gray thinly bedded siltstone and sandstone as described above. TOP TO BASE OF RESERVOIR (A6, A5, A4): (6739’ MD / -6147’ TVDSS - 6865’MD / -6254’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 51.8 5.2 19.6 118 26 73.9 Gas Peaks Depth(MD) TG C1 C2 C3 iC4 nC4 iC5 nC5 6768 118 193474 1715 779 35 211 0 0 6799 110 18652 1639 706 9 200 17 0 6836 109 17471 1536 738 92 186 14 0 Total gas was generally low in this section of the formation due in part to increased mud weight. The reservoir zone is predominantly composed of sandstone underlain by sandy siltstone. The sandstone is light gray to light brownish gray with olive hues; has a quartz framework; and is lower very fine to lower coarse grained. It is moderate to poorly sorted; with subrounded to rounded grains of moderate sphericity. There are some signs of abrasion. It is unconsolidated to easily friable; grain supported with some calcareous cement. Along with abundant quartz there are also trace amounts of 1E-24B 10 glauconite, pyrite, and dark lithics. Laminae are visible on some cuttings. Hydrocarbon indicators include dull yellow brown sample fluorescence; mild odor; instantaneous milk white cut with some grains exhibiting a yellow-white streaming delayed cut. There is common oil staining, and some free oil was seen when sandstone cuttings were treated with HCl. The sandstone occurs with thinly bedded siltstone and claystone in a sequence that generally fines downward and becomes siltier in the bottom of the section. Siltstone in this interval is medium gray to dark medium gray; moderate to well indurated; pulverulent to dense with blocky to occasionally planar fracture; resinous to earthy luster; and silty to clayey texture. Claystone, sandstone and black carbonaceous material are present in thin beds with the siltstone, but not abundant. Trace amounts of pyrite and glauconite are present. No hydrocarbon indicators were observed. BASE OF RESERVOIR TO TD: (6865’ MD / -6254’ TVDSS – 6940’ MD / -6316’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 18.3 2.4 6.5 33 22 25.7 Gas Peaks Depth(MD) TG C1 C2 C3 iC4 nC4 iC5 nC5 6936’ 27 2402 142 52 0 0 0 0 Total gas was very low in this section. At the base of the reservoir, shale and carbonaceous shale, with claystone, siltstone and stringers of sandstone is encountered. Shale (6880-6950) = medium to dark gray with brownish hues; dense to crumbly; blocky to planar fracture; fine flaky to tabular wedgelike cuttings habit; dull earthy to sparkling luster; smooth to silty texture; thin laminae; some shale carbonaceous, black with pyrite laminae; interbedded with siltstone and claystone and decreasing amounts of sandstone. . 1E-24B 11 3.3 Connection Gas Summary: 1 Unit = 200 ppm =0.05% Methane Equivalent Depth (ft) MD/TVD Units Above Background 4958’/4667’ 19 5054’/4745’ 48 5145’/4821’ 43 5239’/4901’ 29 5336’/4989’ 29 5431’/5076’ 58 5518’/5158’ 18 5614’/5251’ 26 5712’/5345’ 51 5805’/5434’ 80 5900’/5523’ 206 5993’/5609’ 31 6088’/5694’ 76 6182’/5776’ 157 6276’/5855’ 115 6370’/5934’ 823 6891/6369’ 22 1E-24B 12 3.4 Trip/Wiper Gas Summary 1 Unit = 200 ppm = 0.05% Methane Equivalent Depth (ft) MD/TVD Trip to (ft) MD/TVD Max. Gas (Units) Comments 7” Hole Section 4926’ SURFACE 11 Tripping out of milling window (4913 to 4926’ MD) with milling BHA. Background gas was <1u. SURFACE 4926’ MD 10 Tripping into milling window with Magnetic Cleaning BHA. Background gas was generally <1u above 2800’ MD and 10u below this depth 4926’ SURFACE Tripping out of milling window with Magnetic Cleaning BHA. Background gas was generally <1u After TD of the intermediate section before POOH 6460’ 1st BU 1847 11 ppg MW 6320’ 2nd BU 1612 11 ppg MW 6320’ 3rd BU 1631 11.15 ppg MW 6320’ 4th BU 1411 11.1 ppg MW 6360’ 5th BU 1083 11.15/11.1 ppg MW 6360’ 6th BU 963 11.15/11.1 ppg MW 6440’ 7th BU 1539 11.1/11.15 ppg MW 6460’ 8th BU 324 11.35 ppg MW 6460’ SURFACE 1976 Trip out of hole to R/U Liner SURFACE 6458’ 35 Trip into hole with 5 ½” Liner After Running 5 ½ Liner 6458’ 1st BU 1975 11.4/11.4 ppg MW 6458’ 2nd BU 125 11.4/11.45 ppg MW 6458’ SURFACE Trip out of hole after 5 ½” Liner run SURFACE 6460’ 0 Cementing SURFACE 6369’ MD 0 Trip into hole to tag cement 4 ¾” Hole Section 6940’ 6880 31 R/B 5 stands, pulling out wet to monitor hole 6880 6940’ 0 Trip back in 5 stands, pumps off 6940’ BU 67 Prior to Trip out; 11.75/11.75 ppg MW 6940’ 6458’ 21 BU at Casing shoe 6458’ SURFACE 4 Trip out of hole after drilling 4 ¾” hole 3 ¾” Completion Liner Run SURFACE 4650’ 22 Trip into hole with 3 ½” Liner 4650’ 6440’ 54 Trip into hole with 3 ½” Liner 1E-24B 13 3.5 Sampling Program / Sample Dispatch Set Type/Purpose Frequency Interval Dispatched To (A) Washed, screened and dried for geologic analysis. 30 ft 10 ft 4926’ to 6460’ MD 6460’ to 6940’ MD N/A (Samples analyzed on site and discarded. No samples curated) 1E - 2 4 B 14 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 G r a d i e n t 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 ( E M W ) Trend Indicators MD (f t ) TV D (f t ) TV D S S (f t ) Mi n (p p g ) Ma x (p p g ) Tr e n d To p C s a n d S D 7 0 % CL S T 2 0 % , SL T S T 1 0 % 65 2 6 ’ 6 0 6 4 ’ 5 9 6 9 ’ 1 1 . 7 1 1 . 7 + E V E N B G , M W , C G To p B s h a l e C L S T 4 0 % SL T S T 3 0 % , SD 3 0 % 66 0 6 ' 6 1 3 1 ’ 6 0 3 6 ’ 1 1 . 7 1 1 . 7 + E V E N B G , M W , C G A- 6 S D 4 0 % SL T S T 4 0 % , CL S T 2 0 % 67 3 9 ’ 6 2 4 2 ’ 6 1 4 7 ’ 1 1 . 7 1 1 . 7 + E V E N B G , M W , C G A- 5 S D 7 0 % SL T S T 2 0 % , CL S T 1 0 % 67 5 2 ’ 6 2 5 3 ’ 6 1 5 8 ’ 1 1 . 7 1 1 . 7 + E V E N B G , M W , C G A- 4 S D 7 0 % SL T S T 2 0 % , CL S T 1 0 % 67 7 9 6 2 7 6 ’ 6 1 8 1 ’ 1 1 . 7 1 1 . 7 + E V E N B G , M W , C G TD 6 9 4 0 6 4 1 1 ’ Ab b r e v i a t i o n s CL 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 SH = S h a l e S S = S a n d s t o n e n / a = n o t a d d r e s s e d / a v a i l a b l e BG = B a c k g r o u n d G a s C G = C o n n e c t i o n G a s D T G = D o w n T i m e G a s MW = M u d W e i g h t T G = T r i p G a s W T G = W i p e r T r i p G a s E M W = E q u i v a l e n t M u d W e i g h t 1E-24B 15 4.2 Quantitative Methods The primary indicators used for PPG evaluation were gas trends relative to mud weight (MW) and effective circulating density (ECD), including increases in background gas (BG), appearance and trends of connection gas (CG), and magnitudes of trip gas (TG) and wiper gas (WG). Regional pore pressure trends from sonic data, provided by ConocoPhillips, and surface manifestations of hole conditions were also considered. As a reference, PPG is calculated initially with a formula provided by Canrig Drilling Technology LTD, and then modified using the indicators described above, DXC and resistivity (RES) data. The formula uses DX, ECD, and BG as measured by total ditch gas: PPG = ECD – (0.6-((.001*TLGSU) + (0.05*DX))) The formula has certain limitations, such that it does not allow for a PPG more than 1 ppg less than the ECD, and TLGSU must be differentiated from show gas and gas carried from over pressure zones, and is dependent on reliable DX data. However, the formula proved useful in helping formulate a PPG range, when estimating trends, as with DXC data, with data points in shale intervals. 1E-24B 16 5 DRILLING DATA 5.1 Daily Activity December 14, 2011 Pump 20 bbls of 15.8 ppg cement and chased with 6 bbls of fresh water and 16 bbls seawater. Stung into cement retainer and displaced with 40 bbls of seawater with choke at 7/8 closed position. Unstung and CBU 2X. tested casing to 3500 PSI. POOH, N/D and change pack off. December 15, 2011 RIH with whip stock and milling assembly to 4888’. circulate and condition mud to 9.8 drill plex mud. Mill window from 4913’ to 4922’. Hole taking fluid due to high YP 200+ and a visc of 1000+. Evaluating solution to mud problem and building more volume. December 16, 2011 Circulate and condition mud. Mill from 4922’ to 4946’. Perform FIT test, MWE 12.5 PPG. POOH with milling assembly. 2 bbl gain, RIH to 4854’, monitor well (static). Continue POOH. L/D Milling BHA. P/U magnet BHA. RIH to 4913’. Slowly reamed to 4946’. Pulled up to 4913’ and CBU then monitor well (static). POOH stopping to monitor well at 412’ (static). L/D Magnet BHA at report time. December 17, 2011 P/U BHA, RIH, Pulse test MWD. RIH to 4946’ and drill ahead. December 18, 2011 Drill from 5430’ to 5900’. POOH to change bend in mud motor. L/D BHA at report time.. December 19, 2011 P/U 1.76 degree motor and changed bit due to wear. TIH and slid through window. Ran to 5804 and washed down to bottom. Drilled from 5900’ to 6434’. December 20, 2011 Drilled from 6434’ to TD at 6460’/6007’ TVD. CBU recorded 1500+ units of BU gas. Weight up mud to 11.3+ ppg mud and POOH. December 21, 2011 Pumped out of the window, then POOH. L/D BHA and tested upper 3.5” x 6” rams. Rigged up and ran 1781 of 5.5” liner. CBU 1976u of trip gas. Circulate gas out of hole. December 22, 2011 Cemented, set packer, unstung and CBU with rig pump. Test BOP’s. December 23, 2011 Finished BOP testing, P/U BHA and 2560’ of 2 7/8” pipe. RIH and cut and slip drill line. December 24, 2011 TIH to 6350’ and weighted up mud to 11.5. tested casing to 3500 psi. Good. Drilled out cement and 20’ of new hole. FIT to 16.00 ppg. Drilling at report time. December 25, 2011 Drilled from 6521’ to 6889’. 1E-24B 17 December 26, 2011 Drilled from 6889’ to TD at 6940. CBU 3x. Ream out of hole to 6420’. RIH to bottom. Saw losses while pumping on bottom, pumped LCM pill. Lost 40 bbls total. Wiped hole clean through tight spots until clean. POOH to shoe monitor well. December 27, 2011 POOH and L/D 2 7/8” pipe and BHA. P/U BHA and single in with liner to 5330’. December 28, 2011 Single in with liner from 5330’ to 6940; 2xCBU (max gas 54u); C&C mud; pump cement and wait on cement. POOH and lay down BHA; Rigdown mudlogging unit. 1E-24B 18 5.2 Survey Data Measured Depth (feet) Inclination (degrees)) Azimuth (degrees) Verticle Section (feet) True Vertical Depth (feet) Latitude N(+)/S(-) (feet) Departure E(+)/W(-) (feet) Dogleg Rate (o/100ft) 4927.59 34.91 142.02 1064.36 4641.73 -815.26 688.82 5.04 5018.91 36.41 148.43 1117.52 4715.95 -858.97 719.10 4.41 5113.70 33.62 150.00 1171.68 4793.57 -905.67 746.96 3.09 5208.53 29.15 154.29 1220.55 4874.52 -949.25 770.12 5.27 5255.40 27.93 154.86 1242.57 4915.69 -969.47 779.74 2.67 5303.24 25.44 160.02 1263.46 4958.44 -989.27 788.01 7.11 5353.98 23.72 163.34 1283.57 5004.58 -1009.30 794.66 4.35 5397.26 21.53 170.42 1298.91 5044.54 -1025.47 798.48 8.07 5444.54 19.67 175.79 1313.46 5088.79 -1041.96 800.51 5.60 5490.54 17.84 182.24 1325.58 5132.36 -1056.73 800.80 6.01 5539.97 16.52 185.04 1336.84 5179.58 -1071.30 799.89 3.15 5584.45 15.97 189.71 1345.89 5222.28 -1083.63 798.30 3.19 5674.64 15.87 192.03 1362.82 5309.02 -1107.92 793.64 0.71 5771.72 17.26 189.60 1381.80 5402.07 -1135.10 788.47 1.60 5864.75 20.11 188.71 1402.85 5490.18 -1164.53 783.74 3.08 5960.94 24.32 189.69 1428.47 5579.21 -1200.41 777.90 4.39 6053.71 26.86 190.34 1456.32 5662.88 -1239.87 770.92 2.75 6148.95 29.50 190.55 1487.34 5746.82 -1284.09 762.77 2.77 6242.45 32.33 190.24 1520.51 5827.03 -1331.34 754.11 3.03 6335.15 34.12 189.51 1555.91 5904.57 -1381.38 745.40 1.98 6429.99 33.88 189.34 1593.17 5983.20 -1433.69 736.72 0.27 6480.45 33.52 189.02 1612.93 6025.18 -1461.33 732.25 0.80 6574.95 33.66 190.15 1649.55 6103.90 -1512.88 723.55 0.68 6670.05 33.30 191.22 1685.58 6183.22 -1564.43 713.82 0.73 6763.52 32.45 190.11 1720.43 6261.72 -1614.29 704.43 1.11 6855.88 32.04 189.18 1754.92 6339.84 -1662.87 696.17 0.70 6907.84 31.75 190.96 1773.99 6383.96 -1689.90 691.37 1.89 6940.00 31.75 190.96 1785.55 6411.30 -1706.51 688.15 0.00 1E - 2 4 B 19 5. 3 B i t R e c o r d NB = N e w B i t BN = B i t N u m b e r RB = R e - B u i l t RR = R e - R u n Si z e (i n ) Ma k e r / Ty p e Se r i a l Nu m b e r Je t s / T F A (3 2 ’ s / s q . in ) De p t h In ( f t ) De p t h Ou t ( f t ) Fe e t Dr i l l e d Dr i l l i ng Hr s . Wear MI L L I N G B I T 1 3 - 1 / 2 Hu g h e s / MX L - 1 X 51 7 9 9 2 2 1 x 1 2 , 3 x 1 6 / 4 9 1 3 4 9 4 6 3 6 3 . 7 5 N o t g r a d e d RB B N # 1 (R U N 3 0 0 ) 7. 0 Hy c a l o g CS D R 4 2 1 3 S 12 8 7 6 9 RB 1x 1 3 , 1 x 1 2 , 1x 1 1 , 2 x 1 0 / 0. 4 8 6 3 49 4 6 5 9 0 0 9 0 4 1 1 . 9 3-4-BT-S-X-I-ER-BHA RR B N # 2 (R U N 4 0 0 ) 7. 0 Hy c a l o g CS D R 4 2 1 3 S 12 8 7 7 0 1x 1 3 , 1 x 1 2 , 1x 1 1 , 2 x 1 0 / 0. 4 8 6 3 59 0 0 6 4 6 0 5 6 0 1 1 . 9 1-1-CT-A-X-I-NO-TD NB B N # 3 (R U N 5 0 0 ) 4. 7 5 Ba k e r QD 4 0 5 H X 70 2 3 4 7 2 2 x 9 , 3 x 1 2 6 4 6 0 6 9 4 0 4 8 0 4 0 1-2-CT-A-X-I-NO-TD 1E - 2 4 B 20 5. 4 M u d R e c o r d : 5. 4 . 1 M u d R e c o r d f o r 7 ” H o l e DA T E DE P T H MW pp g VI S (s / q t ) PV (c P ) YP (# / 1 0 0 f t ² ) GE L S (1 0 s / 1 0 m / 3 0 m ) FL (c c / 3 0 m i n ) SO L S (% ) SD (% ) MB T (3 / b b l ) pH Cl- (ml/l)Ca+ (ml/l) MD (f t ) TV D (f t ) 12 / 1 5 / 2 0 1 1 4 9 2 2 - 9 . 7 N / A 3 4 1 5 9 8 7 / 9 5 / 1 0 1 N C 2 - 1 2 1 1 . 3 1 1 0 0 3 2 0 12 / 1 6 / 2 0 1 1 3 9 9 0 3 5 2 8 9 . 6 7 5 1 0 1 9 8 / 9 / 9 9 4 - 0 1 0 . 2 3 0 0 4 0 12 / 1 7 / 2 0 1 1 5 3 0 0 4 9 8 2 9 . 6 4 3 9 2 1 7 / 9 / 1 1 5 . 4 5 . 5 T r 5 9 . 3 9 0 0 1 2 0 12 / 1 8 / 2 0 1 1 5 9 0 0 5 5 1 9 1 0 . 0 4 6 1 2 2 4 8 / 1 2 / 1 4 5 . 6 9 T r 1 2 9 . 5 4 5 0 4 0 12 / 1 9 / 2 0 1 1 6 3 4 5 5 8 1 2 1 0 . 4 4 7 1 0 3 0 8 / 1 1 / 1 2 4 1 1 T r 1 2 . 5 9 . 5 5 4 0 1 2 0 12 / 2 0 / 2 0 1 1 6 4 6 0 6 0 0 7 1 1 . 4 4 7 1 6 2 7 9 / 1 2 / 1 5 3 . 9 1 3 . 7 5 T R 1 2 . 5 9 . 8 4 0 0 4 0 Ab 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 M B T = M e th y l e n e B l u e T e s 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 VI S = F u n n e l V i s c o s i t y F L = F l u i d L o s s p H = P e r c e n t H y d r o g e n I o n N A F = N o n - A q u e o u s F l u i d PV = 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 C l - = C h l o r i d e 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 S a n d = S a n d c o n t e n t C a + = H a r d n e s s C a l c i u m F L T = F l o w L i n e T e m p 5. 4 . 2 M u d R e c o r d f o r 4 3 / 4 ” h o l e DA T E DE P T H MW pp g VI S (s / q t ) PV (c P ) YP (# / 1 0 0 f t ² ) GE L S (1 0 s / 1 0 m / 3 0 m ) FL (c c / 3 0 m i n ) SO L S (% ) SD (% ) MB T (3 / b b l ) pH Cl- (ml/l)Ca+ (ml/l) MD (f t ) TV D (f t ) 12 / 2 3 / 2 0 1 1 6 4 6 0 6 0 0 7 1 1 . 4 4 2 1 9 2 8 9 / 1 1 / 1 4 4 . 4 1 4 T R 1 2 . 5 9 . 2 4 5 0 4 0 12 / 2 4 / 2 0 1 1 6 5 1 5 6 0 5 7 1 1 . 5 4 8 1 9 2 9 9 / 1 1 / 1 3 4 . 2 1 4 T R 1 0 9 . 3 6 0 0 6 0 12 / 2 5 / 2 0 1 1 6 8 8 5 6 0 5 7 1 1 . 7 5 2 1 9 3 1 1 2 / 1 4 / 1 5 4 . 2 1 6 0 . 6 9 . 4 9 . 0 6 0 0 8 0 12 / 2 6 / 2 0 1 1 6 9 4 0 6 4 1 1 1 1 . 8 5 2 2 0 2 8 9 / 1 1 / 1 3 3 . 8 1 6 0 . 5 1 0 8 . 9 6 0 0 8 0 12 / 2 7 / 2 0 1 1 6 9 4 0 6 4 1 1 1 1 . 7 5 2 1 8 3 0 8 / 1 0 / 1 2 3 . 9 1 6 0 . 5 1 0 8 . 9 6 0 0 8 0 Ab 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 M B T = M e th y l e n e B l u e T e s 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 VI S = F u n n e l V i s c o s i t y F L = F l u i d L o s s p H = P e r c e n t H y d r o g e n I o n N A F = N o n - A q u e o u s F l u i d PV = 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 C l - = C h l o r i d e 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 S a n d = S a n d c o n t e n t C a + = H a r d n e s s C a l c i u m F L T = F l o w L i n e T e m p 1E-24B 21 6 DAILY REPORTS ConocoPhillips Alaska Inc. KRU 1E-24B Daily Report Report for: Larry Hill Robert Wall Date: 12/14/11 Time: 00:01 Current Depth (MD): 5081’ Current Depth (TVD): - Current Operations: Cutting Casing 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: 8.5 FV: 27 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 - - - - - - - - Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N - - - - - - - - - - Lithologies: Current: No New footage Drilled Last 24 hrs: Operational Summary: Pump 20 bbls of 15.8 ppg cement and chased with 6 bbls of fresh water and 16 bbls seawater. Stung into cement retainer and displaced with 40 bbls of seawater with choke at 7/8 closed position. Unstung and CBU 2X. tested casing to 3500 PSI. POOH, N/D and change pack off. Calibrations: Calibrate Peak Simple. Failures: - Daily Cost: $2,010.00 ConocoPhillips Alaska Inc. KRU 1E-24B Daily Report Report for: Larry Hill Robert Wall Date: 12/15/11 Time: 00:01 Current Depth (MD): 4922’ Current Depth (TVD): - Current Operations: 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 @ 21:00 MW: 9.7 FV: n/a PV: 34 YP: 159 FL: nc Gels: 87/95/101 Sol: 2 pH: 11.3 Cl -: 1100 Ca ++: 320 MW Change: Depth: - From: - To: - Reason: - Mud Loss event: Depth: - Volume: - Gas Data Ditch Gas: Current: 0 Max: 13 Depth (MD/TVD): - Avg BG : 0 Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas - - - - - - - - Connection Gases - - - - - - - - Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N - - - - - - - - - - Lithologies: Current: No New footage Drilled Last 24 hrs: Operational Summary: RIH with whip stock and milling assembly to 4888’. circulate and condition mud to 9.8 drill plex mud. Mill window from 4913’ to 4922’. Hole taking fluid due to high YP 200+ and a visc of 1000+. Evaluating solution to mud problem and building more volume. Calibrations: Failures: Daily Cost: $2,110.00 ConocoPhillips Alaska Inc. KRU 1E-24B Daily Report Report for: Larry Hill Robert Wall Date: 12/16/11 Time: 00:01 Current Depth (MD): 4946’ Current Depth (TVD): Current Operations: L/D magnet BHA 24 hr Footage (MD): 24’ Drilling Parameters ROP: Current: 0 Max: 21 Torque: Current: 0 Max: 4612 WOB: Current 0 Max: 7 RPM: Current: 0 Max: 102 PP: Current: 0 Max: 1597 Lag: Strokes: 1113 Time: 18.6 Surf-Surf: Strokes 2127 Time: 35.4 ECD: Current: Max: Mud Properties: Mud report unavailable 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: 0 Max: 123 Depth (MD/TVD): 4946’ Avg BG : 60 Gas Events Depth (MD/TVD) Total Gas (units) C1 C2 C3 C4I C4N C5I C5N Trip Gas 4946’ 595 103128 3948 876 132 0 7 0 Connection Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Circulate and condition mud. Mill from 4922’ to 4946’. Perform FIT test, MWE 12.5 PPG. POOH with milling assembly. 2 bbl gain, RIH to 4854’, monitor well (static). Continue POOH. L/D Milling BHA. P/U magnet BHA. RIH to 4913’. Slowly reamed to 4946’. Pulled up to 4913’ and CBU then monitor well (static). POOH stopping to monitor well at 412’ (static). L/D Magnet BHA at report time. Calibrations: Failures: Daily Cost: $2,970.00 ConocoPhillips Alaska Inc. KRU 1E-24B Daily Report Report for: Larry Hill Robert Wall Date: 12/17/11 Time: 00:01 Current Depth (MD): 5430’ Current Depth (TVD): Current Operations: Drilling 24 hr Footage (MD): 484’ Drilling Parameters ROP: Current: 65 Max: 21 Torque: Current: 0 Max: 3061 WOB: Current 6.6 Max: 7 RPM: Current: 0 Max: 64 PP: Current: 2101 Max: 1597 Lag: Strokes: 1207 Time: 14.7 Surf-Surf: Strokes 8140 Time: 99.3 ECD: Current: Max: Mud Properties: @ 21:00 MW: 9.6 FV: 43 PV: 9 YP: 21 FL: 5.4 Gels: 7/9/11 Sol: 5.5 pH: 9.3 Cl -: 900 Ca ++: 120 MW Change: Depth: From: To: Reason: - Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 65 Max: 108 Depth (MD/TVD): 5402’ Avg BG : 48 Gas Events Depth (MD/TVD) Total Gas (units) C1 C2 C3 C4I C4N C5I C5N Trip Gas 4958 43 7503 395 117 15 2 5054 95 18536 982 150 42 22 Connection Gases 5145 87 14825 797 148 24 35 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: 60% Siltstone, 20% Claystone, 20% Sand Last 24 hrs: 50% Claystone, 30% Siltstone, 20% Sand Operational Summary: P/U BHA, RIH, Pulse test MWD. RIH to 4946’ and drill ahead. Calibrations: Failures: Daily Cost: $2,970.00 ConocoPhillips Alaska Inc. KRU 1E-24B Daily Report Report for: Larry Hill Robert Wall Date: 12/18/11 Time: 00:01 Current Depth (MD): 5900’ Current Depth (TVD): 4657’ Current Operations: L/D BHA 24 hr Footage (MD): 470’ Drilling Parameters ROP: Current: 0 Max: 141 Torque: Current: 0 Max: 4552 WOB: Current 0 Max: 18 RPM: Current: 0 Max: 64 PP: Current: 0 Max: 5671 Lag: Strokes: 1296 Time: 16 Surf-Surf: Strokes 5429 Time: 66.2 ECD: Current: Max: Mud Properties: @ 21:00 MW: 10.0 FV: 46 PV: 12 YP: 24 FL: 5.6 Gels: 8/12/14 Sol: 9 pH: 9.5 Cl -: 450 Ca ++: 40 MW Change: Depth: 5896 From: 9.6 To: 10.0 Reason: Connection gas Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: 461 Depth (MD/TVD): 5872’/5497’ Avg BG : 81.7 Gas Events Depth (MD/TVD) Total Gas (units) C1 C2 C3 C4I C4N C5I C5N Trip Gas 5431/5075 110 20866 1118 171 47 25 5518/5158 46 7599 436 57 15 8 5614/5251 63 9602 648 119 23 12 5712/5345 96 17415 1227 299 22 30 Connection Gases 5805/5434 166 27451 1883 651 72 147 4 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: 70% Shale, 20% Siltstone, 10% Sandstone Last 24 hrs: 60% Shale 20% Sandstone, 20% Siltstone Operational Summary: Drill from 5430’ to 5900’. POOH to change bend in mud motor. L/D BHA at report time.. Calibrations: Failures: Daily Cost: $2,970.00 ConocoPhillips Alaska Inc. KRU 1E-24B Daily Report Report for: Larry Hill Robert Wall Date: 12/19/11 Time: 00:01 Current Depth (MD): 6434’ Current Depth (TVD): 5987’ Current Operations: Drilling 24 hr Footage (MD): 534’ Drilling Parameters ROP: Current: 53 Max: 159 Torque: Current: 3261 Max: 3397 WOB: Current 9 Max: 20 RPM: Current: 53 Max: 55 PP: Current: 2240 Max: 2643 Lag: Strokes: 1581 Time: 20 Surf-Surf: Strokes 1967 Time: 24 ECD: Current: Max: Mud Properties: @ 21:00 MW: 10.4 FV: 47 PV: 10 YP: 30 FL: 4 Gels: 8/11/12 Sol: 11 pH: 9.5 Cl -: 540 Ca ++: 120 6240’ 10.0 10.4 Conn gas MW Change: Depth: 6390’ From: 10.4 To: 10.6 Reason: Conn gas Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 125 Max: 1405 Depth (MD/TVD): 6433’/5986’ Avg BG : 124 Gas Events Depth (MD/TVD) Total Gas (units) Total gas above background (units) Trip Gas 5900’/5523’ 344 211 5993’/5608’ 147 31 6088’/5693’ 216 76 6182’/5775’ 235 157 6276’/5855’ 215 115 Connection Gas 6370’/5933’ 911 823 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: 30% Siltstone, 30% Claystone 20% Sandstone, 20% Shale Last 24 hrs: 70% Shale 20% Sandstone, 10% Siltstone Operational Summary: P/U 1.76 degree motor and changed bit due to wear. TIH and slid through window. Ran to 5804 and washed down to bottom. Drilled from 5900’ to 6434’ Calibrations: Failures: Daily Cost: $2,970.00 ConocoPhillips Alaska Inc. KRU 1E-24B Daily Report Report for: Guy Whitlock Granville Rizek Date: 12/20/11 Time: 00:01 Current Depth (MD): 6460’ Current Depth (TVD): 6007’ Current Operations: POOH 24 hr Footage (MD): 26’ Drilling Parameters ROP: Current: 0 Max: 59 Torque: Current: 0 Max: 3261 WOB: Current 0 Max: 8 RPM: Current: 0 Max: 53 PP: Current: 0 Max: 2628 Lag: Strokes: 1581 Time: 20 Surf-Surf: Strokes 1967 Time: 24 ECD: Current: Max: Mud Properties: @ 21:00 MW: 11.4 FV: 47 PV: 16 YP: 27 FL: 3.9 Gels: 9/12/15 Sol: 13.75 pH: 9.8 Cl -: 400 Ca ++: 40 MW Change: Depth: 6460’ From: 10.6 To: 11.3+ Reason: Downtime gas Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: 225 Depth (MD/TVD): 6446’/5996’ Avg BG : 117 Gas Events Depth (MD) Total Gas (units) Mud Weight Comments 6460 1847 11 1st BU 6320 1612 11 2nd BU 6320 1631 11.15 3rd BU 6320 1411 11.1 4th BU 6360 1083 11.15/11.1 5th BU 6360 963 11.15/11.1 6th BU 6440 1539 11.1/11.15 7th BU Trip/Downtime Gas 6440 324 11.35 8th BU Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: 30% Siltstone, 30% Claystone 20% Sandstone, 20% Shale Last 24 hrs: 70% Shale 20% Sandstone, 10% Siltstone Operational Summary: Drilled from 6434’ to TD at 6460’/6007’ TVD. CBU recorded 1500+ units of BU gas. Weight up mud to 11.3+ ppg mud and POOH. Calibrations: Failures: Daily Cost: $2,970.00 ConocoPhillips Alaska Inc. KRU 1E-24B Daily Report Report for: Guy Whitlock Granville Rizek Date: 12/21/11 Time: 00:01 Current Depth (MD): 6460’ Current Depth (TVD): 6007’ Current Operations: Circulating 24 hr Footage (MD): Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 1351 Time: 45 Surf-Surf: Strokes 2263 Time: 75 ECD: Current: Max: Mud Properties: @ 18:00 MW: 11.4 FV: 57 PV: 18 YP: 32 FL: 4 Gels: 8/11/13 Sol: 14 pH: 9.5 Cl -: 450 Ca ++: 40 MW Change: Depth: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: 0 Depth (MD/TVD): Avg BG : 0 Gas Events Depth (MD) Total Gas (units) Mud Weight Comments Trip/Downtime Gas 6460 1976 11.4 1st BU, after roughly 24 hours downtime Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: No new footage drilled Last 24 hrs: Operational Summary: Pumped out of the window, then POOH. L/D BHA and tested upper 3.5” x 6” rams. Rigged up and ran 1781 of 5.5” liner. CBU 1976u of trip gas. Circulate gas out of hole. Calibrations: Failures: Daily Cost: $2,970.00 ConocoPhillips Alaska Inc. KRU 1E-24B Daily Report Report for: Guy Whitlock Granville Rizek Date: 12/22/11 Time: 00:01 Current Depth (MD): 6460’ Current Depth (TVD): 6007’ Current Operations: Testing BOP’s 24 hr Footage (MD): Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: Time: Surf-Surf: Strokes Time: ECD: Current: Max: Mud Properties: @ 18:00 MW: 11.4 FV: 59 PV: 18 YP: 28 FL: 4.3 Gels: 8/11/13 Sol: 14 pH: 9.3 Cl -: 450 Ca ++: 40 MW Change: Depth: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: 0 Depth (MD/TVD): Avg BG : 0 Gas Events Depth (MD) Total Gas (units) Mud Weight Comments Trip/Downtime Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: No new footage drilled Last 24 hrs: Operational Summary: Cemented, set packer, unstung and CBU with rig pump. Test BOP’s. Calibrations: Failures: Daily Cost: $2,970.00 ConocoPhillips Alaska Inc. KRU 1E-24B Daily Report Report for: Guy Whitlock Granville Rizek Date: 12/23/11 Time: 00:01 Current Depth (MD): 6460’ Current Depth (TVD): 6007’ Current Operations: Cut and slip 24 hr Footage (MD): Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 1428 Time: Surf-Surf: Strokes 1770 Time: ECD: Current: Max: Mud Properties: @ 18:00 MW: 11.4 FV: 52 PV: 19 YP: 28 FL: 4.4 Gels: 9/11/14 Sol: 14 pH: 9.2 Cl -: 450 Ca ++: 40 MW Change: Depth: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: 0 Depth (MD/TVD): Avg BG : 4 Gas Events Depth (MD) Total Gas (units) Mud Weight Comments Trip/Downtime Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: No new footage drilled Last 24 hrs: Operational Summary: Finished BOP testing, P/U BHA and 2560’ of 2 7/8” pipe. RIH and cut and slip drill line. Calibrations: Failures: Daily Cost: $2,970.00 ConocoPhillips Alaska Inc. KRU 1E-24B Daily Report Report for: Guy Whitlock Granville Rizek Date: 12/24/11 Time: 00:01 Current Depth (MD): 6521’ Current Depth (TVD): 6060’ Current Operations: Drilling 24 hr Footage (MD): 61’ Drilling Parameters ROP: Current: 8 Max: 21 Torque: Current: 2191 Max: 2578 WOB: Current 4 Max: 11 RPM: Current: 48 Max: 51 PP: Current: 3037 Max: 3354 Lag: Strokes: 1440 Time: 41 Surf-Surf: Strokes 1786 Time: 50 ECD: Current: Max: Mud Properties: @ 21:00 MW: 11.5 FV: 48 PV: 19 YP: 29 FL: 4.2 Gels: 9/11/13 Sol: 14 pH: 9.3 Cl -: 600 Ca ++: 60 MW Change: Depth: 6500’ From: 11.5 To: 11.7 Reason: High gas Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 31 Max: 2218 Depth (MD/TVD): 6502’/xxxx’ Avg BG : 143 Gas Events Depth (MD) Total Gas (units) Mud Weight Comments Trip Gas Connection Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: 40% Siltstone 30% Shale 20% Claystone 10% Sandstone Last 24 hrs: 40% Siltstone 30% Shale 20% Claystone 10% Sandstone Operational Summary: TIH to 6350’ and weighted up mud to 11.5. tested casing to 3500 psi. Good. Drilled out cement and 20’ of new hole. FIT to 16.00 ppg. Drilling at report time. Calibrations: Failures: Daily Cost: $2,970.00 ConocoPhillips Alaska Inc. KRU 1E-24B Daily Report Report for: Guy Whitlock Granville Rizek Date: 12/25/11 Time: 00:01 Current Depth (MD): 6889’ Current Depth (TVD): 6368’ Current Operations: Drilling 24 hr Footage (MD): 368’ Drilling Parameters ROP: Current: 4 Max: 51 Torque: Current: 2191 Max: 2707 WOB: Current 2 Max: 6 RPM: Current: 52 Max: 55 PP: Current: 3147 Max: 3398 Lag: Strokes: 1520 Time: 48 Surf-Surf: Strokes 2063 Time: 65 ECD: Current: Max: Mud Properties: @ 21:00 MW: 11.7 FV: 52 PV: 19 YP: 31 FL: 4.2 Gels: 12/14/15 Sol: 16 pH: 9.0 Cl -: 600 Ca ++: 80 MW Change: Depth : From: To: Reason: Mud Loss event: Depth : Volume: Gas Data Ditch Gas: Current: 26 Max: 131 Depth (MD/TVD): 6647’/6163’ Avg BG : 73 Gas Events Depth (MD) Total Gas (units) Mud Weight Comments Trip Gas Connection Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: 40% Siltstone 30% Shale 20% Sand 10% Claystone Last 24 hrs: 60% Sand, 20% Siltstone, 20% Claystone Operational Summary: Drilled from 6521’ to 6889’. Calibrations: Failures: Daily Cost: $2,970.00 ConocoPhillips Alaska Inc. KRU 1E-24B Daily Report Report for: Guy Whitlock Granville Rizek Date: 12/26/11 Time: 00:01 Current Depth (MD): 6940’ Current Depth (TVD): 6411’ Current Operations: Monitoring well 24 hr Footage (MD): 51’ Drilling Parameters ROP: Current: 0 Max: 9 Torque: Current: 0 Max: 2576 WOB: Current 0 Max: 4 RPM: Current: 0 Max: 53 PP: Current: 0 Max: 3276 Lag: Strokes: 1530 Time: 48 Surf-Surf: Strokes 2078 Time: 65 ECD: Current: Max: Mud Properties: @ 21:00 MW: 11.8 FV: 52 PV: 20 YP: 28 FL: 3.8 Gels: 9/11/13 Sol: 16 pH: 8.9 Cl -: 600 Ca ++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: 6940’ Volume: 40 bbls Gas Data Ditch Gas: Current: 13 Max: 27 Depth (MD/TVD): 6936’/6407’ Avg BG : 26 Gas Events Depth (MD) Total Gas (units) Mud Weight Comments Trip Gas 6940 67 11.8 CBU Connection Gas 6891 48 11.7 22u conn. gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: 50% shale, 20% Claystone; 20% siltstone, 10% sand Operational Summary: Drilled from 6889’ to TD at 6940. CBU 3x. Ream out of hole to 6420’. RIH to bottom. Saw losses while pumping on bottom, pumped LCM pill. Lost 40 bbls total. Wiped hole clean through tight spots until clean. POOH to shoe monitor well. Calibrations: Failures: Daily Cost: $2,970.00 ConocoPhillips Alaska Inc. KRU 1E-24B Daily Report Report for: Guy Whitlock Granville Rizek Date: 12/27/11 Time: 00:01 Current Depth (MD): 6940’ Current Depth (TVD): 6411’ Current Operations: Running 3.5” Liner 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: 1370 Time: 62 Surf-Surf: Strokes Time: ECD: Current: Max: Mud Properties: 21:00 MW: 11.7 FV: 52 PV: 18 YP: 30 FL: 3.9 Gels: 8/10/12 Sol: 16 pH: 10.4 Cl -: 600 Ca ++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 12 Gas Events Depth (MD) Total Gas (units) Mud Weight Comments Trip Gas 4650’ 22 11.8 Trip w/ liner Connection Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: POOH and L/D 2 7/8” pipe and BHA. P/U BHA and single in with liner to 5330’. Calibrations: Failures: Daily Cost: $2,970.00 ConocoPhillips Alaska Inc. KRU 1E-24B Daily Report Report for: Guy Whitlock Granville Rizek Date: 12/28/11 Time: 14:27 Current Depth (MD): 6940’ Current Depth (TVD): 6940’ Current Operations: POOH/DML Rigdown 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: 1370 Time: 62 Surf-Surf: Strokes Time: ECD: Current: Max: Mud Properties: Not available at rigdown 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) Total Gas (units) Mud Weight Comments Trip Gas 6440’ 59 11.8 Trip w/ liner Connection Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Single in with liner from 5330’ to 6940; 2xCBU (max gas 54u); C&C mud; pump cement and wait on cement. POOH and lay down BHA; Rigdown mudlogging unit. Calibrations: Failures: Daily Cost: $4,460.00
