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210-075
• Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q 1 Q - 0 7,..s Well History File Identifier Organizing (done) ❑ nizin Two -sided III I111111 III ❑ Rescan Needed 11111111 III I R AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: Greyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner PAr oor Quality Originals: I OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: 1{ -- Date: 02 a , I /s/ f, Project Proofing I 1111 g BY: AIM Date: a A / /s/ Scanning Preparation 1 x 30 = + a = TOTAL PAGES 3 a_ cz: '' LL I (Count does not include cover sheet) 11(1 BY: Date: ap T 1 /s/ Production Scanning II 1E11 MI Prod g Stage 1 Page Count from Scanned File: . S 3 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES NO BY: Maria Date: / /cL_ I I /s/ j l/' F Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II 111111111111 ReScanned II 111111 111111 BY: Maria Date: /s/ Comments about this file: Quality Checked 13111111i 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 2/16/2011 Permit to Drill 2100750 Well Name /No. KUPARUK RIV UNIT 31 -11AL1 Operator CONOCOPHILLIPS ALASKA INC API No. 50 -029- 21932 -63 -00 MD 8071 TVD 6253 Completion Date 8/5/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Surveyr Yes "- DATA INFORMATION Types Electric or Other Logs Run: GR / RES (data taken from Logs Portion of Master Well Data Maint III Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments r C Asc Directional Survey 7585 8071 Open Directional Survey 7585 8071 Open Lis 20245 ' Induction /Resistivity 6220 8071 Open 11/1/2010 MPR logs in PDF and tiff og Induction /Resistivity 2 Col 6394 8071 Open 11/1/2010 MD MPR,. GR Log Induction /Resistivity 5 Col 6394 8071 Open 11/1/2010 MD MPR,. GR Log Induction /Resistivity 5 Col 6394 8071 Open 11/1/2010 TVD MPR,. GR Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments • ADDITIONAL INFORMATION Well Cored? Y I& Daily History Received? '"G-21 N Chips Received? Y-#4.1..... Formation Tops V / N Analysis YY Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 2/16/2011 Permit to Drill 2100750 Well Name /No. KUPARUK RIV UNIT 31 -11AL1 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 029 - 21932 -63 -00 MD 8071 TVD 6253 Completion Date 8/5/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N Compliance Reviewed By: Date: _I L 1 t "l, ! t • Company ConocoPhillips, Alaska, Inc. �� BAK lirilitill ER Well Name 31 -11AL1 r (� 5 HUGHES 447 10/12/2010 Date t � 0 IlN TE Q ConocoPhillips Alaska Greater Kuparuk Area * ** Data Distribution RECIPIENTS ll No other distribution is allowed without OH FINAL OH FINAL ' i � written approval from ConocoPhillips Image files and /or Digital Data a C_ ° � _ � f ,. l. contact: Lisa Wright, 907 263 4823 hardco � prints . , _ `.1 ' '"'" ConocoPhillips Alaska, Inc. Sharon Allsup -Drake Drilling Tech, ATO -1530 LL:A y j ib gip ConocoPhillips Alaska, Inc. 1 Hardcopy Print `'`rd NSK Wells Aide, NSK 69 t ? ATTN: MAIL ROOM a/ r�,1 700 G Street, '' . I Anchorage, AK 99501 _ � G ConocoPhillips Alaska, Inc. W Ricky Elgarico 1 Graphic Image 1 Disk * / ���_�' - - _. , ■ e :! File * * / * ** Electronic d t 700 G Street, CGM / TIFF LIS ftp: / /b2bftp.conocophillips.com * * ** AOGCC 1 Hardcopy Print, ' 40014., '114' cop r Pri t Christine Mahnken 1 Graphic image file 1 Disk/ fi c ., 333 West 7th Ave, Suite 100 in lieu of ia ** Electronic Anchorage, Alaska 99501 CGM /TIFF sep LIS ,. 5 . BP 1 , �;d 5p "r , `t Petrotechnical Data Center, MB33 1 Gr Hardcopy aphic image Print file 1 Disk * / ` ` David Douglas in lieu of sepia ** Electronic = 1� . f f e it, P.O. Box 196612 CGM /TIFF LIS a ¢ Anchorage, Alaska 99519 -6612 CHEVRON /KRU REP 1 i 4ardcopy Print, g el i @ ® Pr n Glenn Fredrick 1 Graphic image file I Disl`! � ® P.O.Box 196247 in lieu of sepia ** Electronic ; :4, ', Ctr® Anchorage, Alaska 99519 CGM /TIFF LIS` °" ': Brandon Tucker, PERT , �� m ,..,:,1,17,,!,77.1 State of Alaska; DNR, Div. of Oil and Gas 1 Dish " /�1 550 W. 7th Ave, Suite 800 Electronics Anchorage, Alaska 99501 -3510 _ LIS DS Engineer / Rig Foreman '' TOTAL - ,, _ d ux . x . .:L_ Hardcopy Prints 4�_;:��¢ Page 1 of 4 • • RErF-iVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SEP d 3 2011 WELL COMPLETION OR RECOMPLETION REPORLAMPLeaCnitliSSi011 la. Well Status: Oil IN Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ lb. Well Class: " � £ ;t1ctt 20AAC 25.105 20AAC 25.110 Development 0 tzploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test El 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: August 5, 2010 210 - 0750 / 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 July 22, 2010 50 029 - 21932 - 63 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 147' FSL, 48' FEL, Sec. 36, T13N, R8E, UM July 30, 2010 3I - 11AL1 Top of Productive Horizon: 8. KB (ft above MSL): 76' RKB 15. Field /Pool(s): 1216' FNL, 2111' FEL, Sec. 6, T12N, R9E, UM GL (ft above MSL): 40' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1511' FNL, 2215' FEL, Sec. 6, T12N, R9E, UM 8071' MD / 6253' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 507830 y 6007088 Zone 4 8071' MD / 6253' TVD ADL 25523, 25631 TPI: x - 506296 y - 6005723 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 506194 y 6005428 Zone 4 2212' MD / 2212' TVD 2559, 2564 18. Directional Survey: Yes is No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1650' MD / 1650' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD GR/Res 7610' MD / 6229' TVD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 Surf. 116' Surf. 116' 24" 250 sx CS II 9.625" 36# J -55 Surf. 3383' Surf. 3383' 12.25" 330 sx Class G, 544 sx AS III, 175 sx AS L I 7" 26# J -55 Surf. 6408' / Surf. 6141' 8.5" 250 sx Class G, 175 sx AS I 2.375" 4.7# L -80 7422' 8071' J 6231' 6253' 3" slotted liner 24. Open to production or injection? Yes 0 No ❑ If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET ( MD/TVD) 3.5" 6143' 6146' MD / 5977' TVD slotted liner: 6422' MD / 6230' TVD 7431' - 8069' MD 6231' - 6253' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. COMPLETIONS DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED none ,iI4, 1PIT., 1 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) August 11, 2010 gas lift oil Date of Test Hours Tested Production for OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE GAS - OIL RATIO 8/28/2010 17.5 hours Test Period - -> 256 899 1123 104 Bean 3922 Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. 168 psi 1303 24 -Hour Rate -> 315 1234 1481 24 deg. 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE RBDMS SEP 0 7101 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original 2. rl. /O , •i� /io C, • 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes El 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 1650' 1650' needed, and submit detailed test information per 20 AAC 25.071. Kuparuk Al 7757' 6249' Kuparuk A2 7591' 6229' N/A Formation at total depth: Kuparuk Al 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic, directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: JiJyLong •■ 263 - 4093 Printed -me V.awve Title: Alaska Wells Manager Signature _ �i _ • _AL... Phone 265 - 6306 Date Sharon Allsup -Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: 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 3I -11A, AL1, & AL2 CTD Sidetrack Schematic Camco TRMAXX -5E SSSV @ 2212 MD (2.813" min ID, X- profile) Updat 9 - Aug - 10 3 -1/2 ", 9.3# L -80 EUE 8rd -Mod Tubing to surface K EY Equipment and perforations set in 3 -1/2" Camco MMG gas lift mandrels (5) @ pa wellbore 2512', 3702', 4760', 5668', & 6074' Equipment set and lateral drilled 16" 62# H -40 shoe @ 116' MD X' landing nipple @ 6123' MD (2.813" min ID) during first CTD project Baker 3 -1/2" seal assembly 6131' - 6143' MD Equipment set and laterals drilled 11110..._ 80 -40 PBR at 6132' - 6145' during second CTD project 9 -5/8" 36# J -55 Baker KBH Anchor Seal Assy at 6145' MD shoe @ 3383' MD Baker SAB 40 -32 packer © 6146' MD 'X' landing nipple @ 6156' MD (2.813" min ID) Liner top @ 6180' MD Holes shot in 3 straddle at - 6408' - 6413'S, 6213' MD 31 - 11A L2PB1 Whipstock @ 6396' Kickoff from 31 - 11 sand) 31 - 11A L2 MD Baker F1 permanent packer @ 6422' MD (e - line set ° G 7423' (A3 sand) TD @ 8500' Kickoff from 31 -11 AL2 PB1 7930' (Baker monobore z 7930 - 80 - 40 Sealbore extension (6425' 6430') Anchored billet ' @ whlnctnrkt °e Sho Sol d liner deployment rom 6181 62243' 3 - 1/2" straddle ' 'D' landing nipple @ 6433' MD (2.750" min ID) ' Slotted liner from to 43' cemented in place l;},.w WLEG @ 6438' MD TD @ 9279' 279' Cast Iron Bridge Plug 1 N' ro: to @ -6406' ' ----- - l ' � , Mill , FISH: 3- 1 /2 "x;w, monobore ;4, 31-11 A whipstock at 6422' fir?" `.a -,- _ - - ._ (A2 sand) (TOWS) a '• '.. ` t�---`::----. .................. ... :- :.........,... : -: Kickoff from 31 - 11 @ 6394.2' TD 94 -. - :- . ', , '•- - - Anchored billet @ 7600' FISH: 3 - 1/2° �,� ' .. > Slotted liner from 7600' to 9490' monobore whipstock @ �■ I ---..- unknown depth _ A sand perfs 31 - A3: 6437' - 6454' __----._ 31 -11 L1 (Al sand) A2: 6457' - 6486' —�� (A2 sand) Kickoff from 31 -11A @ 7597' --�-- Kickoff from 31 -11 @ 6409' Liner top billet @ 7423' Al: 6494' - 6503' \ Openhole from 6409' -7590' Slotted liner from 7423' to TD \ Shorty deployment sleeve @ 7590' TD @ 8071' Slotted liner from 7590' to TD TD © 9437' • 7" 26# J -55 shoe @ 6761' MD . . 111 411 KUP 31-11AL1 ..,_ .... ___ _ .... _ int ,,Ir" 4 ft Lonougurrumps r - \ _Well Attributes Max Angle & MD TD Af I Wellbore APUUWI 1Fie Id Name Well Status Inc! (') i MD (ftKB) 6,49 806, (ftKB) 500292193263 KUPARUK RIVER UNIT PROD 8,080.0 Comment H2S (ppm) IDate Annotation End Date 1(8-6idot) - --- riii ReleaseDtde ... SSSV: TRDP 150 6/22/2009 Last WO: 35.91 4/4/1989 SOmplp_rf_MktaL____. Annotation Depth(ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: SIDETRACKS _ Imosbor 8/7/2010 HANGER, 31 .. Casing Strings 7. Casing Description String 0... String ID ... Top (ftKB) [Set Depth (f... Set Depth (TVD) .. String Wt... String ...iString Top Thrd I ;i l AL1 LINER 1 2318 1.995 7,422.9 8,071.0 1 4.43 L-80 STL ' ', Liner Details I IR , ' Top Depth Top Inc! r i Top (ftKB) ( 0 7 K D B ) ) (1 Bern Description ID (in) fig . 7,4229 Perforations & Slots CONDUCTOR, Shot BILLET LINER TOP BILLET Comment Nomi... 1 000 36-116 Top (TVD) Bt.. (TVD) Dens Top (ftKB) Btm (IfIKB) (668) (ftKB) Zone p (sh... Typo Comment 1111 7,432 8,070 A-2, 3I-11AL1 7/31/2010 32.0 SLOTS SLOTTED LINER - 0.125"x2.5" @ 4 SAFETY VLV, illik circumferential adjacent rows, 3" 2,212 centers staggered 18 deg, 3' non-slotted ends It Notes: General & Safety_ W End Date Annotetion GAS gl Ti 8/6/2010 NOTE: VIEW MULTI-LATERAL SCHEMATIC w/Alaska Schematic9.0 lit i -I ti SURFACE, 'r 35-3,383 GAS LIFT, 3,702 1 1111 it IF GAS 1 At:: it „,..; GAS LIFT. lir_ 1 lir g GAS LIFT, 6,074 ..iir it NIPPLE, 6,123 1-1 SEAL ASSY, 6,131 — i s, 666, 6,132 :', - 1 S E A L A PACKER, 6,146 - NIPPLE, 6,156 . 4 . WHIPSTOCK, 6,396 t` . WINDOW A, 6,396-6,406 PLUG, 6,406 CEMENT SOZ, 6,213 ,. .1, • Pk SEAL ASSY, PACKER, 6,422 SBE, 6,425 NIPPLE. 6,433 1 I Mandrel Details Top Depth Top 1 Port 1 30,3 6 437 (TVD) Ind OD Valve Latch Sire TRO Run SP. Top (ftKB) M18) (1 Make Model (in) Sent TYPs Tyr. (n) (psi) Run Date Com... 1 2,511.6 Camco MMG 1 1/2 GAS LIFT DMY R-20 0.000 0.0 6/1812010 , , 1 2 3,702.1 Camco MMG 11/2 GAS LIFT DMY R-20 0.000 0.0 2/19/2010 3 4,760.5 Camco MMG 1 1/2 GAS LIFT DMY R-20 0.000 0.0 6/19/2010 PRODUCTION, 4 5,667.8 Camco MMG 11/2 GAS LIFT DMY R-20 0.000 0.0 6/21/2010 33 5 6,074.0 Camco MMG 11/2 GAS LIFT DMY RDO... 0.000 0.0 6/20/2010 7,43tTITA AL1 LINER, Tcr,r,sin, - \ _ 8,060 CcnooPhs Iip Alaska ConocoPhillips(Alaska) Inc. • Kuparuk River Unit Kuparuk 31 Pad 31 -11AL1 50- 029 - 21932 -63 Baker Hughes INTEQ • BAKER Definitive Survey Report HUGHES 11 August, 2010 ConocoPhillips VARI Conoco Definitive Survey Report HUGHES Alaska • Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 31 -11 Project: Kuparuk River Unit TVD Reference: 31 -11 © 76.00ft (31 -11) Site: Kuparuk 31 Pad MD Reference: 31 -11 © 76.00ft (31 -11) F Well: '' : 31 - 11 North Reference: ! TRUE Wellbore: 31 -11 Survey Calculation Method: Minimum Curvature D esign: 31 -11 Database: EDM Alaska Prod v16 a. 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 31 -11 • Well Position +N/-S 0.00 ft Northing: 6,007,088.16ft Latitude: 70 25 50.121 N +El - 0.00 ft Easting: 507,830.23ft Longitude: 149° 56' 10.241 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore_ ; 31 -11AL1 .., Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2009 7/15/2010 17.05 79.85 57,388 Design ,c,; 31 -11AL1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,585.68 Vertical Section: Depth From (TVD) +N /S +E/-W Direc a "' (ft) (ft) (ft) ( 0 ) 0 76.00 0.00 0.00 224.65 Survey Pogram Date From - To. Survey Survey (ft) (ft) Survey (Wellborn) ` Tool Name Description Start Date End Date 100.00 6,300.00 31 -11 (31 -11) BOSS -GYRO Sperry-Sun BOSS gyro multishot 1/12/2001 6,394.00 7,585.68 3I -11A (3I -11A) MWD MWD - Standard 7/25/2010 7/28/2010 7,597.10 8,030.61 31 -11AL1 (3I- 11AL1) MWD MWD - Standard 7/30/2010 7/30/2010 L I 8/11/2010 8:54:21AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips fei ConocoPhillips Definitive Survey Report BAKER Alaska HUGHES Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 31 -11 Project: :;' Kuparuk River Unit TVD Reference: 31 -11 © 76.00ft (31 -11) Site Kuparuk 31 Pad MD Reference: 31 -11 © 76.00ft (31 -11) Well: 31 -11 North Reference: TRUE Wellbore;! 31 -11 Survey Calculation Method: M Curvature Design-, ; 31 -11 Database: EDM Alaska Prod v16 Survey Map Map; VerticaI MD' "Azl ° TVDS +NI-S Northing Ea sting ( B I7oa LS ) O Section , Survey Tool Name Annotation 7,585.68 90.95 2 t tftj (n► (M) Ifs) (ft) s • 1 5.18 6,229.01 6,153.01 - 1,211.62 - 1,461.17 6,005,875.13 506,370.47 24.41 1,888. MWD (2) TIP 7,597.10 91.31 212.99 6,228.78 6,152.78 - 1,221.07 - 1,467.57 6,005,865.67 506,364.09 19.43 1,900.07 MWD (3) KOP; Top of Billet 7,630.87 85.75 210.21 6,229.65 6,153.65 - 1,249.81 - 1,485.25 6,005,836.91 506,346.44 18.41 1,932.94 MWD (3) Interpolated AZI 7,660.45 82.76 207.75 6,232.61 6,156.61 - 1,275.55 - 1,499.51 6,005,811.16 506,332.21 13.06 1,961.27 MWD (3) 7,690.30 79.15 205.53 6,237.30 6,161.30 - 1,301.90 - 1,512.73 6,005,784.81 506,319.02 14.15 1,989.30 MWD (3) MWD 79.35 201.51 6,242.85 6,166.85 - 1,328.67 - 1,52 W 4.38 6,005,758.02 506,307.39 13.30 2,016.54 MD (3) 7,750.37 82.12 195.55 6,247.74 6,171.74 - 1,357.05 - 1,533.89 6,005,729.64 506,297.92 21.43 2,043.41 MWD (3) 7,780.29 85.33 192.02 6,251.01 6,175.01 - 1,385.93 - 1,540.97 6,005,700.76 506,290.87 15.89 2,068.93 MWD (3) 7,810.62 87.14 192.01 6,253.00 6,177.00 - 1,415.53 - 1,547.27 6,005,671.15 506,284.60 5.97 2,094.41 MWD (3) 7,840.61 88.22 196.86 6,254.21 6,178.21 - 1,444.54 - 1,554.74 6,005,642.14 506,277.16 16.55 2,120.30 MWD (3) 7,870.61 87.54 200.60 6,255.32 6,179.32 - 1,472.92 - 1,564.36 6,005,613.74 506,267.57 12.66 2,147.25 MWD (3) 7,900.79 88.77 205.77 6,256.30 6,180.30 - 1,500.64 - 1,576.23 6,005,586.02 506,255.73 17.60 2,175.32 MWD (3) 7,930.43 88.93 208.92 6,256.89 6,180.89 - 1,526.96 - 1,589.85 6,005,559.68 506,242.15 10.64 2,203.60 MWD (3) 7,960.63 89.20 204.77 6,257.39 6,181.39 - 1,553.90 - 1,603.48 6,005,532.74 506,228.54 13.77 2,232.35 MWD (3) 7,990.54 90.80 200.71 6,257.39 6,181.39 - 1,581.47 - 1,615.04 6,005,505.15 506,217.01 14.59 2,260.09 MWD (3) 8,020.56 93.07 196.91 6,256.37 6,180.37 - 1,609.87 - 1,624.71 6,005,476.75 506,207.37 14.74 2,287.09 MWD (3) 8,030.61 93.81 195.58 6,255.77 6,179.77 - 1,619.50 - 1,627.52 6,005,467.12 506,204.58 15.12 2,295.91 MWD (3) 8,071.00 93.81 195.58 6,253.08 6,177.08 - 1,658.32 - 1,638.34 6,005,428.29 506,193.80 0.00 2,331.13 PROJECTED to TD • 8/11/2010 8:54:21AM Page 3 COMPASS 2003.16 Build 69 • 31 -11 Well Events Summary DATE SUMMARY 6/11/10 LOG GR /CCL /PRESS/TEMP FOR PRE SIDETRACK REFERENCE LOG. LOGGED BHPS: 6400'= 3962 PSI, 156 DEGF & 6300'= 3927 PSI, 152 DEGF. 6/14/10 DRIFT TBG W/ 2.78" DMY PLUG (OAL = 46 ") TO 6170' RKB. PULLED GLV @ 5668' RKB, LOST TOOL STRING @ —5200' SLM. TAG FISH W/ 2.74" LIB @ 5607' SLM (CLEAN ROPE SOCKET W/ WIRE PRESENT) FISH IN GLM @ 5668' RKB. FISH IN HOLE= 37.5' OAL & -30' OF .108 WIRE. IN PROGRESS. 6/15/10 ATTEMPTED PULL 37.5' TOOLSTRING FROM 5607' SLM. PUMPED 11 BBL DSL, T & IA TRACKED TO 2500 PSI; APPARENT SAND BRIDGE IN TBG. MOVED FISH UPHOLE 28' TO 5579' SLM. IN PROGRESS. 6/16/10 RECOVERED —30' WIRE & TOOLSTRING LOST 6/14/2010. 1.5" GLV PULLED 6/14/2010 MISSING IN WELL. IN PROGRESS. 6/17/10 RECOVERED GLV LOST 6/14/10. BAILED THROUGH SAND BRIDGES @ 6095' & 6122' SLM. TAGGED WITH 2.79" GAUGE @ 6391' SLM. BRUSHED X NIPPLE @ 6123' RKB & SET 2.813" XX PLUG @ SAME. IN PROGRESS. 6/18/10 SET CATCHER ON XX PLUG @ 6123' RKB. PULLED GLVs @ 4760', 3702' & 2511' RKB. SET DVs @ 5667', 4760', 3702' & 2511' RKB. BLED IA TO VERIFY VALVES ARE SET; TBG TRACKING IA. PULLED OV @ 6074' RKB, CHECK OK. IN PROGRESS. 6/19/10 VERIFIED DVs SET WITH HOLEFINDER. CIRCULATED 50 BBL DSL TO LOAD WELL. SET DV @ 6074' RKB. TESTED TBG 2000 PSI, PASSED. DRAW DOWN TEST ON IA, PASSED. MITIA 2500 PSI, PASSED. PULLED CATCHER SUB. IN PROGRESS. 6/20/10 PULLED 2.81" XX PLUG @ 6123' RKB. DRIFTED & TAGGED @ 6395' SLM, EST. 6418' RKB, WITH 2.63" CENT, BLB & 2.77" LIB (OAL =55 "). LIB INDICATES FILL. CLOSURE TESTED TRMAXX -5E SSSV, GOOD. READY FOR E /L. 6/22/10 SET BAKER 3.5" CIBP. TOP OF CIBP SET AT A DEPTH OF 6405.85'. BOTTOM OF CIBP SET AT A DEPTH OF 6407'. CCL TO BOTTOM OF CIBP MEASURED 14.96'. CCL STOP DEPTH RECORDED AT 6392'. 6/28/10 PERFORM POS/ NEG TESTS ON CIBP. DRIFTED TBG WITH DUMMY WHIPSTOCK (2.65" x 18.3') TO TOP OF CIBP @ 6406' RKB. COMPLETE. 7/7/10 T -POT (PASSED), T -PPPOT (PASSED), IC -POT (PASSED), IC -PPPOT (PASSED), MITOA (PASSED), PT & DD TEST ON SV (PASSED), MV (PASSED), SSV (PASSED) 8/9/10 GAUGED TBG WITH 2.80" GAUGERING TO 6180' RKB. PERFORMED 30 MIN SBHPS @ 6180' RKB 3861 PSI, 143 DEG F. 20 MIN GRADIENT STOP @ 6060' = 3798 PSI.SET CATCHER SUB ON LINER TOP @ 6180' RKB.REPLACED 1.5" DV WITH 1/4" ORFICE @ 6074' RKB.PULLED 1.5" DV © 5667' RKB.IN PROGRESS 8/10/10 SET GLV @ 5667' RKB. REPLACED DVs WITH GLVs @ 4760', 3702', AND 2511' RKB. DRAWDOWN IA, GOOD. PULLED CATCHER FROM LINER TOP. READY FOR FLOWBACK OPERATIONS. • .Time. Logs Date - From, To Dur S. Depth E. Depth Phase aide Subcode . T Comment 19:00 21:30 2.50 8,096 45 COMPZ CASING TRIP T Stop -reset counter, set & pump across the top while POOH to window. Flag pipe for second run. Continue POOH to surface pumping KWF down CT. Clean KWF over shakers. 21:30 22:00 0.50 45 0 COMPZ CASING PULD T Flow -check then Lay down BHA. 22:00 22:30 0.50 0 0 COMPZ CASING SFTY T Set up rig floor & pre -job safety meeting for Liner run. 22:30 00:00 1.50 0 550 COMPZ CASING PUTB T P/U 15 jnts of liner with anchored billet. 07/29/2010 RIH with OH Liner & Billet. Set TOB @ 7598'. POOH - 6395' Stuck in window. Worked free with 12K on DH weight. POOH. P/U Crayola Mill - Circ out KWF - back reaming was clean other than 45 degree LOHS. 6394 - Stuck BHA - worked free & dressed window to 30 degree LOHS. POOH - No marks on mill 2.80" No -go. 00:00 00:30 0.50 550 559 COMPZ CASING PULD T P/U Coil trac BHA. & make up injector. 00:30 02:30 2.00 559 8,093 COMPZ CASING RUNL T Open EDC RIH pumping .3bpm. Flag correction +2.2 , Stop pumping, close EDC. P/U weight 17.5K. RIH. 02:30 03:00 0.50 8,093 7,597 COMPZ CASING CIRC P Orientate TF to 160 ROHS - tagged low liner. P/U weight 21K, sit down 1K. P/U neutral weight. Start pumping - tool set @ 3200 psi, P/U weight 18K. Continue POOH. 03:00 04:00 1.00 7,597 6,396 COMPZ CASING TRIP P TOB - 7597' - Pump across the top, POOH to window. Tie into PIP tag +3 ft correction. Overpull @ window from 19K to 24K. Try to orientate - torque up on HOT 04:00 04:30 0.50 6,396 6,396 COMPZ CASING TRIP T Set up to pump down CT - try move CT slowly up & down. No movement on BHA. -5K to +5K within 3ft. Pump .5 bpm, 1300 psi. no movement +5 to -7K quickly - stop pumping. Call town to discuss. 04:30 04:45 0.25 6,396 6,393 COMPZ CASING TRIP T Try pumping 1 bpm, 3100 psi, working CT stirng, returns @ surface. Work it up /down 5 times. Stop and sit. Stop pumping. 04:45 07:15 2.50 6,393 6,393 COMPZ CASING CIRC T Pump minimum rate, Wait on discussion from town 07:15 07:15 0.00 6,393 6,393 COMPZ CASING TRIP T Try push more wieght down, -5K WOB increasing to -10K WOB, slowly. No luck 07:15 07:45 0.50 6,393 6,393 CO MPZ CASING TRIP T PU to 5K over, Stuck, RIH 10 15, 20, 25, 30 FPM to -10K WOB, No luck. 07:45 08:15 0.50 6,393 6,393 COMPZ CASING TRIP T PUH, 30K surface weight 10K over. Stuck RIH 35 FPM -12K WOB, Hold down weight. 08:15 08:45 0.50 6,393 6,393 COMPZ CASING TRIP T Get free, orient keyway on setting tool HS PUH 10 -15 FPM, PUH through window clean 08:45 10:30 1.75 6,393 0 COMPZ CASING TRIP P POOH 10:30 10:45 0.25 0 0 COMPZ CASING OWFF P At surface PJSM, flow check good Page 8 of 15 • I Time.Logs. Date r =. _ From . To Dur . S. Depth . E. Depth Phase Code Subcode T Comment. • 10:45 12:00 1.25 0 0 COMPZ CASING PULD T LD BHA, All components of BHA are in good shape with normal wear. 12:00 14:15 2.25 0 0 PROD2 WHPST PULD T PU/MU BHA #11. 14:15 15:15 1.00 0 6,250 PROD2 WHPST TRIP T RIH 15:15 15:30 0.25 6,250 6,250 PROD2 WHPST DLOG T Tie in depth + 4' correction, RIH 15:30 15:45 0.25 6,250 6,600 PROD2 WHPST TRIP T Slide through window no problem. RIH to 6600' performing weight checks every 50'. 15:45 18:45 3.00 6,600 6,600 PROD2 WHPST CIRC T PUH above window pumping 9.8ppg flo -pro to bit. RIH Displace well back to flo -pro from 6600'. 18:45 20:00 1.25 6,600 6,394 PROD2 WHPST REAM T Begin Milling passes up /down at milled TF. Two clean passes no motor work. 1 pass 45 ROHS - light motor work. 1st pass 45 LOHS - torqued up @ 6394' - stop pumping, _ RIH instant WOB, Orient HS. Hung up- P/U Orient 45 ROHS - sit down 5K and popped free 20:00 20:30 0.50 6,400 6,400 PROD2 WHPST REAM T HS - Make pass up /down -1/2 fpm - start 15 LOHS - clean, 30 LOHS - clean, 30 ROHS - slight work. Discuss with town - Make 2 HS dry passes. - clean. 20:30 23:00. 2.50 6,400 71 PROD2 WHPST TRIP T Open EDC - POOH. 23:00 00:00 1.00 71 0 PROD2 WHPST PULD T Undeploy BHA with crayola mill. Crayola came out 2.80" No -go, _clean. 07/30/2010 Milled off anchored billet at 7600' and drillled to 8071'. TD well due to poor quality Al sands in this area. Lay in liner running pill and KWF. 00:00 01:00 1.00 0 0 PROD2 STK SVRG P Service injector & Inspect CT connector. 01:00 02:30 1.50 0 72 PROD2 STK PULD P Deploy BHA # 12 02:30 05:00 2.50 72 7,597 PROD2 STK TRIP P RIH with EDC open, tie in+ Oft correction. Smooth through window _ HS. Dry tag TOB @ 7597.1' 05:00 07:30 2.50 7,597 7,610 PROD2 STK MILL P Bring pumps on -line 1.40 bpm, 3500psi, BHP 4200, ECD 13.2, VIA WOB .7K, CT weight 7K. n 1 FPH for 1' 31 1 - 1 - 2 FPH for 1' 3 FPH for 1' 15 FPH for 5' 07:30 07:42 0.20 7,610 7,610 PROD2 STK MILL P Peform dry drift through ST, Looks good 07:42 08:42 1.00 7,610 7,760 PROD2 DRILL DRLG P Drill Ahead 1.4 BPM, 3600 CTP, 1 -2K WOB, 4 -5K CTW, 300 WHP, 4220 BHP, 150 FPH 08:42 10:27 1.75 7,760 7,760 PROD2 DRILL WPRT P Wiper trip back to window 16K PUW 10:27 11:57 1.50 7,760 7,910 PROD2 DRILL DRLG P Drill Ahead 1.4 BPM, 3600 CTP, 1 -2K WOB, 4 -5K CTW, 300 WHP, 4288 BHP, 100 -150 FPH 11:57 13:42 1.75 7,910 7,910 PROD2 DRILL WPRT P Wiper trip to window 17K PUW Page 9 of 15 • • • Time Logs" Date From .. To Dur . S. Depth :.E. Depth. Phase Code Subcode T Comment 13:42 15:42 2.00 7,910 8,060 PROD2 DRILL DRLG P Drill Ahead 1.4 BPM, 3600 CTP, 1 -2K WOB, 4 -5K CTW, 300 WHP, 4288 BHP, 100 FPH 15:42 17:18 1.60 8,060 6,440 PROD2 DRILL WPRT P TD lateral perform wiper trip chasing low /high sweep to window, 20K 17:18 17:30 0.20 6,440 6,440 PROD2 DRILL DLOG P Tie in depth to RA marker, +2' 17:30 18:42 1.20 6,440 8,071 PROD2 DRILL WPRT P RIH 18:42 19:42 1.00 8,071 6,600 PROD2 DRILL DISP P Lay in liner running pill 19:42 21:00 1.30 6,600 0 PROD2 DRILL TRIP P POOH laying in KWF. Paint flag at 5600 EOP 21:00 21:12 0.20 0 0 PROD2 DRILL SFTY P PJSM for laying down drilling BHA 21:12 21:48 0.60 0 0 PROD2 DRILL PULD P Lay down drilling BHA 21:48 22:48 1.00 0 0 COMPZ CASING PUTB P Rig up floor for liner running 22:48 00:00 1.20 0 0 COMPZ CASING PUTB P Run 20 joints slotted liner 07/31/2010 Ran liner to td at 8071' and left liner top billet at 7423'. Milled off billet and drilled AL2 lateral to 7775'. Mud swap after milling off billet 00:00 01:12 1.20 0 693 COMPZ CASING PUTB P Continue PU liner and make up Inteq tools. 01:12 02:36 1.40 693 6,292 COMPZ CASING RUNL P RIH 02:36 03:18 0.70 6,292 8,071 COMPZ CASING RUNL P Correct at flag, +2.5'. Weight check 18K PUW, 13K RIW. Continue RIH 03:18 05:33 2.25 8,071 0 COMPZ CASING RUNL P Tag at 8071', pump 1.2 BPM and release liner. POOH pumping down backside. At window line up pump down CT and continue POOH 05:33 06:30 0.95 0 0 COMPZ CASING PULD P At surface, PJSM. LD BHA 13, PU BHA 14 06:30 07:33 1.05 0 0 PROD3 STK PULD P PU BHA # 14 07:33 08:48 1.25 0 6,250 PROD3 STK TRIP P RIH 08:48 09:03 0.25 6,250 6,250 PROD3 STK DLOG P Tie in depth, +3'. Closed EDC, 09:03 11:33 2.50 6,250 6,600 PROD3 STK DISP P RIH to 6600' displacing KWF out of well 11:33 14:03 2.50 7,423 7,436 PROD3 STK MILL P Start ST Bring pumps on -line 1.30 bpm, 3546psi, BHP 4266, ECD 13.2, WOB .7K, CT weight 7K. 1 FPH for 1 ' 2 FPH for 1' 3 FPH for 1' 10 FPH for 5' 14:03 14:18 0.25 7,436 7,436 PROD3 STK MILL P Perform dry drift through ST, Good. 14:18 15:48 1.50 7,436 7,580 PROD3 DRILL DRLG P Drill Ahead 1.3BPM, 3600 CTP, 4285 BHP, 1.5 -2K WOB, 300 WHP, 4 -5K CTW Start mud swap 15:48 17:30 1.70 7,580 7,580 PROD3 DRILL WPRT P Wiper trip to window 16K PUW 17:30 21:12 3.70 7,580 7,730 PROD3 DRILL DRLG P Drilling ahead, 3300 CTP, 420 WHP, 4270 BHP 21:12 22:00 0.80 7,730 6,670 PROD3 DRILL WPRT P Wiper to window, 18K PUW Page 10 of 15 • • Sifalfl (IF nELPIIII(Kn SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 V. Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3I -11AL1 ConocoPhillips Alaska, Inc. Permit No: 210 -075 Surface Location: 147' FSL, 48' FEL, Sec. 36, T13N, R8E, UM Bottomhole Location: 2619' FSL, 2406' FEL, Sec. 6, T12N, R9E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to drill the above referenced development wellbore. The permit is for a new wellbore segment of existing well KRU 3I -11A, Permit No 210- 074, API 50- 029 - 21932 -01. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. 4 cerel , Daniel T. Seamount, Jr. Chair DATED thi day of June, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/ o encl. (via e-mail) RECEIVED STATE OF ALASKA JUN 1 1 2 010 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Alaska Oil e Gas Cons. Commission 20 AAC 25.005 Anchorage 1 a. Type of ork: , 1 b. Proposed Well Class: Development - Oil Q • Service - Winj ❑ Single Zone • • lc. Specify if well is proposed for. Drill r . w i i Stratigraphic Test ❑ Development - Gas El Service - Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re -entry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: IA Blanket ❑ Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59 - 52 - 180 • 3I - 11AL1 - 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 9165 • TVD: 6193' • Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 147' FSL, 48' FEL, Sec. 36, T13N, R8E, UM . ADL 25523, 25631 ° Kuparuk River Oil Pool - Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1111' FNL, 1860' FEL, Sec. 6, T12N, R9E, UM 2559, 2564 7/1/2010'` ' Total Depth: 9. Acres in Property: 14. Distance to 2619' FSL, 2406' FEL, Sec. 6, T12N, R9E, UM 2560 Nearest Property: 18560 • 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: • 76 feet 15. Distance to Nearest Well Open Surface: x - 507830 y - 6007088 Zone 4 GL Elevation above MSL: 16.5 feet to Same Pool: 31 -13 , 1342 16. Deviated wells: Kickoff depth: 7400 • ft. 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Maximum Hole Angle: 96.9° deg Downhole: 4452 psig Surface: 3800 psig • 18. Casing Prod ram: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L - 80 ST - L 1805' 7360' 6152' 9165' 6193' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) 6772' 6560' 6680' 6473' 6422' Casing Length Size Cement Volume MD TVD Conductor /Structural 116' 16" 250 sx CS II 116' 116' Surface 3348' 9.625" 330 sx Class G, 3383' 3383' Intermediate 544 sx AS III, 175 sx AS I Production 6728' 7" 250 sx Class G, 175 sx AS I 6761' 6550' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 6437'- 6454', 6457'- 6486', 6494' -6503' 6245- 6261', 6264'- 6291', 6298' -6306' 20. Attachments: Property Plat ❑ BOP Sketch 0 Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Jill Long @ 263 - 4093 9.111 Printed Name V. Cawvey Title Alaska Wells Manager Signature rket/PAAA $ r j(70/1 le '11- tectOULY Phon -6306 Date C/////6 Co mission Use Only Permit to Drill API Number: Permit A rov I See cover letter Number: f -'1 = 5 i� 5 0 -t�� L l ' a, , 4 - f ! z ` c- Date: / / i 1 for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coa urethan , gas hydrates, or gas contained in shales: d 4 Psi 17bP % 1` Samples req'd: Yes ❑ No U Mud log req'd: Yes ❑ No Other: ^ H2S measures: Yes 2 No ❑ Directional svy req'd: Yes [ No ❑ 4 s F ri- / w. �s C ,) 6 , / APPROVED BY THE COMMISSION - .„,,,, 3� / D ATE: / y ro val , COMMISSIONER Subt in Dup Lca Form 10-401 (Revised 7/2009) This permit is valid fo + � . f ' d eiofu (20 AAC 25.005(g)) p� / / JL�je � • • RECEIVED Conoco Phillips s o p JUN m 1 2010 Alaska P.O. BOX 100360 Alaska Oi U Gas Cons. Commission ANCHORAGE, ALASKA 99510 -0360 Anchorage June 11, 2010 Commissioner- State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill three lateral sidetracks out of Kuparuk Well 31 -11 using the coiled tubing drilling rig, Nabors CDR2 -AC. Work is scheduled to begin on 31 -11 as early as July 2010. The CTD objective is to drill three lateral sidetracks (31 -11A, 31- 11AL1, 31- 11AL2) to access reserves in the Al, A2 and A3 sands south of 31 -11 that are currently unswept. In October 2009, Permit to Drill (PTD) applications were approved for CTD sidetracks 31-11L1 (PTD# 209 - 1210), 3I- 11L1 -01 (PTD# 209 - 1220), and 3I- 11L1 -02 (PTD# 209 -1230) with the same objectives as the laterals proposed in the attached applications. Work on those sidetracks began in January 2010, however, due to . operational issues, only the 31-11L1 lateral was drilled and completed. The approved permits for the 31-11L1- 01 and L1 -02 laterals were officially withdrawn on June 3, 2010. Because the first attempt at drilling the CTD sidetracks was unsuccessful, the work proposed in this application packet is essentially the same as previously permitted. The reservoir targets and objectives have not changed, nor have the rig operations. The only difference is that production from the parent wellbore will be isolated prior to drilling the proposed laterals. Plugging the parent wellbore perforations is necessary because of the need to isolate the 31-11L1 lateral to prevent solids production from the unlined, openhole section. Sundry applications for the plugging of the two wellbores have been submitted separately from these PTD applications. Attached to this application are the following documents: — Permit to Drill Application Forms for 31 -11A, 31- 11AL1, and 31 -11AL2 — Detailed Summary of Operations — Proposed Schematic — Directional Plans — BOP Schematic If you have any questions or require additional information please contact me at my office 907 - 263 -4093 or on my cell phone 907 - 230 -7550. Sincerely, Jill Long Coiled Tubing Drilling Engineer • • Permit to Drill Summary of Operations KRU 31-1 1A, 31-1 1AL1, & 31-1 1AL2 Laterals Coiled Tubing Drilling Well History Well 31 -11 was originally drilled and completed as an A -sand producing, single completion well in 1989 with 2- 7/8" tubing. A workover was performed in May 2009 to replace leaking tubing. At that time the well had already been identified as a CTD candidate so the tubing was upsized from 2 -7/8" to 3 -1/2" and a subsurface safety valve (SSSV) was installed in preparation for the sidetracks. The original objective of the CTD sidetracks was to drill three lateral sidetracks out of the 31 -11 parent wellbore targeting the Al, A2 and A3 sands to access reserves from currently undrained areas to the south. The laterals were planned and permitted as 31-11L1 (PTD# 209 - 1210), 3I-11L1-01 (PTD# 209 - 1220), and 31-11L1-02 (PTD# 209 -1230) because the perforations in the parent wellbore were going to remain open to production. Nabors CDR2 rigged up on 31 -11 in January 2010 and began drilling operations. Unfortunately, after drilling the - 31 -11 L1 lateral and partially lining what had been drilled, the window became inaccessible. Drilling operations were suspended on February 13, 2010, to diagnose the problem with the window and acquire additional 13.1 ppg potassium formate completion fluid. Laterals 3I-11L1-01 (PTD# 209 -1220) and 3I-11L1-02 (PTD# 209- 1230) were neither drilled or completed prior to rig release. Post -rig diagnostics confirmed the whipstock had . released and moved downhole. After completing diagnostics on the window, 3I-11L1 was opened to flow to tanks in an attempt to bring the well pressure down before returning with the rig again. Initial production tests had -850 BLPD at 62.4% WC, 21.5 API, 0.75% solids at 950 WHP. As drawdown on the well was increased, the openhole lateral eventually collapsed and the tubing filled with solids. A fill cleanout was performed in April 2010 and the well has remained shut -in since then. Plan Forward The plan forward for this well is to set a plug in the 3 -1/2" tubing above the previously drilled window prior to attempting the CTD sidetracks again. This will isolate the 31 -11 parent wellbore perforations in addition to the 31- • 11L1 lateral and prevent solids production which could potentially plug the tubing again and prohibit production from the new sidetracked laterals. A whipstock will also be set pre -rig. Once the CTD rig arrives, a dual string window (3 -1/2" x 7 ") will be milled from which the three lateral sidetracks • will then be drilled. The laterals will be named and permitted as 3I -11A, 3I- 11AL1, and 3I- 11AL2. Operational Outline Pre -Rig Work Remaining 1. Tag fill and obtain a SBHP survey 2. Set a cast iron bridge plug in the 3.5" tubing at -6406' 3. Set a 3.5" monobore whipstock at -6397' 4. Prepare wellsite for rig arrival. Rig Work 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU 7- 1/16" BOPE, test. 2. 31 -11A Lateral (A2 Sand) - a. Mill 2.80" 2- string window with high -side orientation off of the whipstock set at 6397' MD. b. Drill 2.70" x 3" bi- center lateral in the A2 sand to a TD of 9170' MD. Page 1 of 4 Q R GIN L 6/11/2010 • • PTD Applications KRU 31 -11A, 31- 11AL1, and 31 -11AL2 c. Load well with completion kill weight fluid. Run 2%" slotted liner from TD at 9170' MD up to 7400' MD. An anchored aluminum billet will be set at 7400' MD for kicking off the 31 -11AL1 lateral. 3. 31 -11AL1 Lateral (Al Sand) a. Kick off of the anchored aluminum billet set in the 31 -11A lateral at 7400' MD. • -, b. Drill 2.70" x 3" bi- center lateral in the Al sand to a TD of 9160' MD • c. Load well with completion kill weight fluid. Run 2 %" slotted liner from TD up to 7360' MD. An aluminum liner -top billet placed at 7360' MD for kicking off the 31 -11AL2 lateral. 4. 31 -11AL2 Lateral (A3 Sand) a. Kick off of the aluminum billet set in the 31 -11AL1 lateral at 7360' MD. b. Drill 2.70" x 3" bi- center lateral in the A3 sand to a TD of 9180' MD. c. Load well with kill weight fluid. Run 2%" slotted liner from TD up to 6385' MD, inside the 3W tubing. A deployment sleeve will be placed on top of the liner. 5. Freeze protect. ND BOPE. RDMO Nabors CRD2 -AC. Handover to Production group. Post - Rig Work 1. Obtain SBHP 2. Flowback for well cleanup 3. Begin production Operational Details Hazards - The window exit will occur in the top of the C4 sands, very close to the D shale. - The close proximity to the previously drilled 31 -11L1 wellbore is an important risk to be aware of when kicking out of 31 -11 and drilling the build section of 3I -11A. The center -to- center separation of the directional plans has been reviewed and the separation is within the range that past wells having similar circumstances have been drilled. - Shale stability is a potential problem, particularly in the build section where the AS sand will be encountered. Potential sloughing problems will be mitigated by drilling this interval at a hole angle less than 60° and by holding a constant 13.2 ppg EMW on the formation throughout drilling operations. - Lost circulation was not a significant issue while drilling 31-11L1 and thus is not expected to be an issue in 3I -11A, AL1, orAL2. - Over - pressured zones are a potential hazard in 31 -11. Choke pressure will be maintained while drilling, . both for maintaining well control and borehole stability. - Well 31 -11 has 150 ppm H as measured on 6/22/09. Well 31 -12 is located 25' to the left side and 31 -10 • is 25' to the right side of the 31 -11 surface location. The 31 -12 has no measured H since it is an injector. The H measured in 31 -10 is 120 ppm (1/2/09). The maximum H level on the pad is 160 ppm from wells 31 -04 (12/17/08) and 31 -17 (1/10/09). All H monitoring equipment will be operational. Page 2 of 4 6/11/2010 PTD Applications KRU 31 -11A 31- 11AL1, and 31 -11AL2 Fluids Program - Chloride -based Biozan brine (8.6 ppg) will be used for window milling operations. - Chloride -based Flo -Pro mud (10.0 ppg) for drilling operations. - The SSSV in 31 -11 is inoperable so completion kill weight fluid will be needed. Due to the high reservoir pressures, 13.1 ppg Potassium Formate will be used for running completions. Disposal - No annular injection on this well. - Class II liquids to KRU 1R Pad Class II disposal well - Class II drill solids to Grind & Inject at PBU Drill site 4 - Class I wastes will go to Pad 3 for disposal. New Completion Details Lateral Name Liner Liner Liner Liner Liner Details Top Btm Top Btm MD MD SSTVD SSTVD 31 -11A 7400' 9200' 6151' 6158' 2�/ , 4.7 #, L -80, ST -L slotted liner; aluminum billet on top. 31 -11AL1 7360' 9165' 6152' 6193' 2 % ", 4.7 #, L -80, ST -L slotted liner; , aluminum billet on top. 31 -11AL2 6300' 9180' 6042' 6140' 2 , 4.7 #, L -80, ST -L solid /slotted liner; deployment sleeve on top. Existing Casing /Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 65 H -40 Welded 0 116 0 116 1640 630 Surface 9 %" 36 J -55 BTC 0 3383 0 3383 3520 2020 Casing 7" 26 J -55 BTC 0 6762 0 6550 4980 4320 Tubing 3 1 /2" 9.3 L -80 EUE 0 6438 0 6246 10160 10540 Directional Planning - See attached directional plans for each of the three laterals. - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 31 -11A 18560 31 -11AL1 18560 ' 31-1 AL2 18560 - Distance to Nearest Well within Pool (toe measured to offset well) Lateral Name Distance Offset Well 31 -11A 1500 31 -13 • 31 -11AL1 1342 31 -13 31 -11AL2 1450 31 -13 Page 3 of 4 ', " a 6/11/2010 PTD Applications • KRU 3I -1, 31- 11AL1, and 31 -11AL2 Logging MWD directional, resistivity, and gamma ray will be run over the entire openhole section. Reservoir Pressure - The most recent static BHP survey in well 31 -11 was taken February 16, 2009, after 31 -11 L1 was drilled. The reservoir pressure was measured at 4150 psi at 6400 'MD/ 6135' TVDSS, corresponding to 13.0 ppg EMW. — The highest pressure from surrounding wells is 4250 psi at 6168 TVDSS in offset injector 31 -13. The . pressure reading was taken in December 2009. Well 31 -13 had been shut -in since May 2009 to assist in reducing the pressure in the area. Well Control — Two well bore volumes ( -223 bbl) of KWF will be within a short drive to the rig during drilling operations. • — BOP diagram is attached for operations with 2" coil tubing. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4500 psi. Maximum potential surface pressure expected while sidetracking out of 31 -11 is 3800 psi assuming a gas gradient to surface and maximum potential formation pressure. Maximum potential formation pressure is based on the highest, most recent measured bottomhole pressure in the vicinity, which is from offset injector 31 -13. The annular preventer will be tested to 250 psi and 2500 psi. Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottomhole pressure by using 10.0 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allows use of less expensive drilling fluid and minimizes fluid losses and /or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure is installed between the BOPE choke manifold and the mud pits, and is independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the 2 %" BHA will be accomplished utilizing the 2%," pipe rams and slip rams. The annular preventer will act as a secondary containment during deployment and not as a stripper. The well will be loaded with overbalanced fluid prior to running completions. Operating parameters and fluid densities will be adjusted based on real -time bottom hole pressure measurements while drilling and shale behavior. Page4of4 OR t O INAL 6/11/2010 S Conoc�Philli Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 31 Pad 31 -11 31-1 1AL1 Plan: 31 -11AL1 wp01 Standard Planning Report 10 June, 2010 Fan BAKER HUGHES • 0 - ConocoPhillips ratio , , Conoco Phillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: > Well 31 -11 Company: ConocoPhillips(Alaska) Inc. TVD Reference: " Mean Sea Level Project Kuparuk River Unit MD Reference: 31 -11 © 76.00ft (31 -11) Site: Kuparuk 31 Pad North Reference: True Well: 31 -11 Survey Calculation Methods Minimum Curvature Wellbore: 31 -11AL1 Design: 3f -11AL1 wp01 Project Kuparuk River Unit Map System: US State Plane 1927 (Exact solution). System Datum: Mean Sea Level • Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor ... -... _ -... -_ Site Kuparuk 31 Pad Site Position: Northing: 6,007,285.49ft Latitude: 70° 25"52.059 N From: Map Easting: 508,056.44ft Longitude: 149° 56' 3.597 W Position Uncertainty: 0.00 ft Slot Radius: It Grid Convergence: 0.06 ° Well 31 -11 Well Position +N / -S 0.00 ft Northing: 6,007,088.16 ft • Latitude: 70° 25' 50.121 N +E/ -W 0.00 ft Easting: 507,830.23 ft • Longitude: 149° 56' 10.241 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Weilbore _ 31 -11AL1 Magnetics Model Name Sample Date Declination Dip Angle " Field Strength - (°) r) (III) - BGGM2009 7/15/2010 17.05 79.85 57,388 Design 31 -11AL1 wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,400.00 Vertical Section: Depth From (TVD) +NI-S +E!-W Direction : - (ft) (ft) (ft) C) 0.00 0.00 0.00 200.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +W$ +E/ -W Rate Rate ` Rate TED (ft) (°) (°) (ft) (ft) (ft) (1100ft) ( °MOOR) ( ° /100ft) (°) . ` 7,400.00 89.20 236.09 6,150.95 - 1,258.56 - 1,284.92 0.00 0.00 0.00 0.00 7,430.00 85.31 238.34 6,152.39 - 1,274.78 - 1,310.11 15.00 -12.98 7.52 150.00 7,460.00 80.81 238.34 6,156.01 - 1,290.41 - 1,335.45 15.00 -15.00 0.00 180.00 7,490.00 76.92 236.03 6,161.81 - 1,306.35 - 1,360.19 15.00 -12.96 -7.69 210.00 7,560.00 77.14 225.26 6,177.57 - 1,349.54 - 1,412.85 15.00 0.32 -15.39 270.00 7,650.00 89.85 220.68 6,187.75 - 1,414.84 - 1,473.62 15.00 14.13 -5.09 340.00 7,745.00 89.37 206.44 6,188.40 - 1,493.80 - 1,526.00 15.00 -0.51 -14.99 268.00 7,831.00 90.50 193.59 6,188.50 - 1,574.44 - 1,555.38 15.00 1.31 -14.94 275.00 8,001.00 96.85 168.83 6,177.45 - 1,742.63 - 1,559.06 15.00 3.74 -14.57 285.00 8,081.00 94.63 156.97 6,169.41 - 1,818.57 - 1,535.68 15.00 -2.77 -14.82 260.00 8,181.00 94.48 172.02 6,161.43 - 1,914.35 - 1,509.12 15.00 -0.16 15.05 90.00 8,308.00 89.09 190.31 6,157.45 - 2,040.67 - 1,511.71 15.00 -4.24 14.40 106.00 8,568.00 88.03 229.31 6,164.25 - 2,261.87 - 1,638.42 15.00 -0.41 15.00 92.00 8,830.00 86.58 189.99 6,177.07 - 2,484.83 - 1,765.38 15.00 -0.56 -15.01 267.00 8,930.00 87.47 204.98 6,182.30 - 2,579.81 - 1,795.31 15.00 0.89 14.99 87.00 9,165.00 87.36 169.70 6,193.25 - 2,808.96 - 1,824.82 15.00 -0.05 -15.02 269.00 6/10/2010 11.33:36AM Page 2 COMPASS 2003.16 Build 69 1 ' b i ", 1 Yaw.•. 4 ♦ " Sf, a . i'. . • ConocoPhillips • Conoco Phillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: " - Well 31 -11 Company: ConocoPhillips(Alaska) Inc. TVD Reference: - Mean Sea Level Project Kuparuk River Unit MD Reference: ' 31 -11 © 76.00ft (31 -11) Site: Kuparuk 31 Pad North Reference: True Well: - 31 -11 Survey Calculation Method: Minimum Curvature Wellbore: 31 -11AL1 Design: 31-1 1 AL1 _wp01 Planned Survey Mea sured ND Below Vertical Dogleg Toolface Map Map DepNe Inclination Azimuth System +N/-S +E/ W Section Rate Azimuth Northing Easting (ft) ( °) ( ^y (ft) (ft) (ft) (ft) (° /loon) ( ° I (i = int_ 7,400.00 89.20 236.09 6,150.95 - 1,258.56 - 1,284.92 1,622.13 0.00 0.00 6,005,828.38 506,546.76 TIP / KOP 7,430.00 85.31 238.34 6,152.39 - 1,274.78 - 1,310.11 1,645.99 15.00 150.00 6,005,812.13 506,521.59 2 7,460.00 80.81 238.34 6,156.01 - 1,290.41 - 1,335.45 1,669.34 15.00 - 180.00 6,005,796.48 506,496.27 3 7,490.00 76.92 236.03 6,161.81 - 1,306.35 - 1,360.19 1,692.78 15.00 - 150.00 6,005,780.51 506,471.55 4 7,500.00 76.92 234.49 6,164.07 - 1,311.90 - 1,368.19 1,700.73 15.00 -90.00 6,005,774.96 506,463.55 7,560.00 77.14 225.26 6,177.57 - 1,349.54 - 1,412.85 1,751.37 15.00 -89.65 6,005,737.28 506,418.94 5 7,600.00 82.78 223.20 6,184.54 - 1,377.75 - 1,440.30 1,787.27 15.00 -20.00 6,005,709.04 506,391.52 7,650.00 89.85 220.68 6,187.75 - 1,414.84 - 1,473.62 1,833.53 15.00 -19.64 6,005,671.91 506,358.24 6 7,700.00 89.59 213.19 6,187.99 - 1,454.78 - 1,503.65 1,881.32 15.00 -92.00 6,005,631.95 506,328.26 7,745.00 89.37 206.44 6,188.40 - 1,493.80 - 1,526.00 1,925.64 15.00 -91.96 6,005,592.91 506,305.95 7 7,800.00 90.09 198.22 6,188.66 - 1,544.63 - 1,546.88 1,980.54 15.00 -85.00 6,005,542.06 506,285.12 7,831.00 90.50 193.59 6,188.50 - 1,574.44 - 1,555.38 2,011.46 15.00 -84.96 6,005,512.25 506,276.66 8 7,900.00 93.15 183.58 6,186.30 - 1,642.54 - 1,565.66 2,078.97 15.00 -75.00 6,005,444.15 506,266.45 8,000.00 96.81 168.98 6,177.56 - 1,741.66 - 1,559.25 2,169.92 15.00 -75.32 6,005,345.04 506,272.97 8,001.00 96.85 168.83 6,177.45 - 1,742.63 - 1,559.06 2,170.77 15.00 -76.60 6,005,344.06 506,273.16 9 8,081.00 94.63 156.97 6,169.41 - 1,818.57 - 1,535.68 2,234.13 15.00 - 100.00 6,005,268.16 506,296.61 10 8,100.00 94.63 159.83 6,167.88 - 1,836.17 - 1,528.71 2,248.29 15.00 90.00 6,005,250.57 506,303.60 8,181.00 94.48 172.02 6,161.43 - 1,914.35 - 1,509.12 2,315.04 15.00 90.23 6,005,172.42 506,323.27 11 8,200.00 93.69 174.77 6,160.08 - 1,933.17 - 1,506.94 2,331.99 15.00 106.00 6,005,153.60 506,325.47 8,300.00 89.43 189.16 6,157.34 - 2,032.79 - 1,510.36 2,426.77 15.00 106.20 6,005,053.99 506,322.15 8,308.00 89.09 190.31 6,157.45 - 2,040.67 - 1,511.71 2,434.64 15.00 106.59 6,005,046.11 506,320.81 12 8,400.00 88.64 204.10 6,159.28 - 2,128.33 - 1,538.86 2,526.29 15.00 92.00 6,004,958.43 506,293.76 8,500.00 88.24 219.10 6,162.03 - 2,213.22 - 1,591.09 2,623.93 15.00 91.72 6,004,873.49 506,241.62 8,568.00 88.03 229.31 6,164.25 - 2,261.87 - 1,638.42 2,685.84 15.00 91.31 6,004,824.79 506,194.35 13 8,600.00 87.79 224.51 6,165.41 - 2,283.71 - 1,661.76 2,714.35 15.00 -93.00 6,004,802.93 506,171.03 8,700.00 87.13 209.51 6,169.87 - 2,363.26 - 1,721.73 2,809.60 15.00 -92.82 6,004,723.33 506,111.15 8,800.00 86.67 194.50 6,175.31 - 2,455.57 - 1,759.03 2,909.11 15.00 -92.16 6,004,630.99 506,073.95 8,830.00 86.58 189.99 6,177.07 - 2,484.83 - 1,765.38 2,938.77 15.00 -91.34 6,004,601.73 506,067.63 14 8,900.00 87.18 200.49 6,180.90 - 2,552.17 - 1,783.73 3,008.33 15.00 87.00 6,004,534.37 506,049.36 8,930.00 87.47 204.98 6,182.30 - 2,579.81 - 1,795.31 3,038.26 15.00 86.43 6,004,506.73 506,037.81 15 9,000.00 87.33 194.47 6,185.48 - 2,645.54 - 1,818.88 3,108.08 15.00 -91.00 6,004,440.98 506,014.31 9,100.00 87.29 179.46 6,190.20 - 2,744.40 - 1,830.95 3,205.12 15.00 -90.52 6,004,342.11 506,002.34 9,165.00 ' 87.36 169.70 6,193.25 • - 2,808.96 - 1,824.82 3,263.69 15.00 -89.81 6,004,277.56 506,008.54 TD 6/10/2010 11:33:36AM Page 3 COMPASS 2003.16 Build 69 • ConocoPhillips ratio ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Well 31 - 11 Company ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Projec Kuparuk River Unit MD Reference: 31 -11 @ 76.00ft (31 -11) Site: " Kuparuk 31 Pad North Reference: True Well :.. 31 - 11 Survey Calculation Method: Minimum Curvature Wellbore: 31 -11 AL1 Design: 31 - 11 AL1_wp01 Targets Target Name <hittmiss target _ Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting Shape (e) ( °) (ft) (ft) (ft) (ft) (ft Latitude Longitude = T: 31 -11AL1 t2 0.00 0.00 6,157.00 - 2,032.21 - 1,510.30 6,005,054.57 506,322.21 70° 25 30.133 N 149° 56' 54.540 W - plan hits target center - Point 31 -11A, AL1, AL1 -01 F 0.00 0.00 0.00 - 790.15 - 523.89 6,006,297.54 507,307.22 70° 25' 42.349 N 149° 56' 25.610 W - plan misses target center by 6215.53ft at 7400.00ft MD (6150.95 ND, - 1258.56 N, - 1284.92 E) - Polygon Point 1 0.00 - 790.15 - 523.89 6,006,297.54 507,307.22 Point 2 0.00 - 1,143.27 - 1,441.33 6,005,943.49 506,390.24 Point 3 0.00 - 1,783.03 - 1,750.00 6,005,303.47 506,082.28 Point 4 0.00 - 2,991.73 - 2,167.25 6,004,094.45 505,666.34 Point 5 0.00 - 3,170.18 - 1,736.39 6,003,916.47 506,097.34 Point6 0.00 - 1,875.47 - 1,311.05 6,005,211.50 506,521.28 Point 7 0.00 - 1,398.60 - 1,140.56 6,005,688.50 506,691.25 Point 8 0.00 - 1,175.14 - 570.28 6,005,912.54 507,261.24 31 -11A, AL1 fault 5 0.00 0.00 0.00 - 2,306.63 - 2,081.65 6,004,779.58 505,751.21 70° 25' 27.433 N 149° 57' 11.297 W - plan misses target center by 6179.74ft at 8600.00ft MD (6165.41 ND, - 2283.71 N, - 1661.76 E) - Polygon Point 1 0.00 - 2,306.63 - 2,081.65 6,004,779.58 505,751.21 Point 2 0.00 - 2,432.98 - 1,745.74 6,004,653.59 506,087.22 Point 3 0.00 - 2,576.36 - 1,373.85 6,004,510.62 506,459.22 Point 4 0.00 - 2,432.98 - 1,745.74 6,004,653.59 506,087.22 31 -11AL1 t1 0.00 0.00 6,189.00 - 1,544.13 - 1,546.79 6,005,542.56 506,285.22 70° 25' 34.933 N 149° 56' 55.613 W - plan hits target center - Point 31 -11A AL1 fault 1 0.00 0.00 0.00 - 912.76 - 902.05 6,006,174.54 506,929.22 70° 25' 41.143 N 149° 56' 36.703 W - plan misses target center by 6172.55ft at 7400.00ft MD (6150.95 ND, - 1258.56 N, - 1284.92 E) - Polygon Point 1 0.00 - 912.76 - 902.05 6,006,174.54 506,929.22 Point 2 0.00 - 1,382.78 - 932.52 6,005,704.54 506,899.25 Point 3 0.00 - 1,197.74 - 948.34 6,005,889.54 506,883.24 Point 4 0.00 - 1,382.78 - 932.52 6,005,704.54 506,899.25 31 -11A, AL1 fault 2 0.00 0.00 0.00 - 2,022.61 - 1,134.26 6,005,064.56 506,698.21 70° 25' 30.228 N 149° 56' 43.510 W - plan misses target center by 6168.83ft at 8300.00ft MD (6157.34 ND, - 2032.79 N, - 1510.36 E) - Polygon Point 1 0.00 - 2,022.61 - 1,134.26 6,005,064.56 506,698.21 Point 2 0.00 - 1,137.61 - 1,040.37 6,005,949.57 506,791.16 Point 3 0.00 512.11 - 599.68 6,007,599.59 507,230.07 Point4 0.00 - 1,137.61 - 1,040.37 6,005,949.57 506,791.16 31 -11AL1 t3 0.00 0.00 6,193.00 - 2,808.95 - 1,825.16 6,004,277.58 506,008.20 70° 25' 22.493 N 149° 57' 3.770 W - plan hits target center - Point 31 -11A, AL1 fault 3 0.00 0.00 0.00 - 2,059.83 - 1,873.37 6,005,026.57 505,959.21 70° 25' 29.860 N 149° 57' 5.189 W - plan misses target center by 6168.09ft at 8310.07ft MD (6157.48 TVD, - 2042.71 N, - 1512.09 E) - Polygon Point 1 0.00 - 2,059.83 - 1,873.37 6,005,026.57 505,959.21 Point 2 0.00 - 2,206.22 - 1,500.48 6,004,880.59 506,332.22 Point 3 0.00 - 2,330.62 - 1,111.56 6,004,756.61 506,721.23 Point 4 0.00 - 2,206.22 - 1,500.48 6,004,880.59 506,332.22 31 -11A, AL1 fault 4 0.00 0.00 0.00 - 2,213.81 - 1,904.53 6,004,872.57 505,928.21 70° 25' 28.346 N 149° 57' 6.102 W - plan misses target center by 6169.99ft at 8517.47ft MD (6162.57 ND, - 2226.51 N, - 1602.41 E) - Polygon Point 1 0.00 - 2,213.81 - 1,904.53 6,004,872.57 505,928.21 Point 2 0.00 - 2,335.11 - 1,618.62 6,004,751.58 506,214.22 Point 3 0.00 - 2,453.49 - 1,249.70 6,004,633.60 506,583.23 6/10/2010 11:33:36AM Page 4 COMPASS 2003.16 Build 69 ORIGINAL • • ConocoPhillips l ConocoPhillips Planning Report BAKER A Alaska Databases EDM Alaska Prod v16 Local Co- ordinate Reference _ _.- Well 31- -11 Company:; " ConocoPhillips(Alaska) Inc. TVD Reference :. Mean Sea Level Project: Kuparuk River Unit MD Reference: 31 -11 @ 76.00ft (31 -11) Site Kuparuk 31 Pad North Reference: True Welh 31 -11 Survey Calculation Method: Minimum Curvature Welibore: 31-11A1_1 Design: 31 -11 AL1 _wp01 Point 4 0.00 - 2,335.11 - 1,618.62 6,004,751.58 506,214.22 Casing Points Measured Vertical Casing Hole , ' r Depth Depth Diameter- Diameter (ft) (ft) Name ( ") ( ") 9,165.00 6,193.25 2 3/8' 2 - 3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NJ-s +E!-W (ft) (ft) (ft) (ft) Comment 7,400.00 6,150.95 - 1,258.56 - 1,284.92 TIP / KOP 7,430.00 6,152.39 - 1,274.78 - 1,310.11 2 7,460.00 6,156.01 - 1,290.41 - 1,335.45 3 7,490.00 6,161.81 - 1,306.35 - 1,360.19 4 7,560.00 6,177.57 - 1,349.54 - 1,412.85 5 7,650.00 6,187.75 - 1,414.84 - 1,473.62 6 7,745.00 6,188.40 - 1,493.80 - 1,526.00 7 7,831.00 6,188.50 - 1,574.44 - 1,555.38 8 8,001.00 6,177.45 - 1,742.63 - 1,559.06 9 8,081.00 6,169.41 - 1,818.57 - 1,535.68 10 8,181.00 6,161.43 - 1,914.35 - 1,509.12 11 8,308.00 6,157.45 - 2,040.67 - 1,511.71 12 8,568.00 6,164.25 - 2,261.87 - 1,638.42 13 8,830.00 6,177.07 - 2,484.83 - 1,765.38 14 8,930.00 6,182.30 - 2,579.81 - 1,795.31 15 9,165.00 6,193.25 - 2,808.96 - 1,824.82 TD 6/10/2010 11:33:36AM Page 5 COMPASS 2003.16 Build 69 ORIGINAL ft.." b T..N.th WELLBORE DETAILS: 31 -11AL1 REFERENCE INFORMATION Project: Kuparuk River Unit Magnetic Norm2157" Site: Kuparuk 3IPad ela9 Parent r Wellbore: 31 -11A Co (N E) Reference: Well 31 - 11, True North 57b88,3en radii Well: 31 - Vertical (1VD) Reference: Mean Sea Level BAKE iilllff E apM Tie on MD: 7400:00 Section (VS) Reference: sbt•(SOON, 0.00E) R Welber.: 31 -11AL1 Date n152m �C)I ocoP� i1 �1 35 Plan: 3I- IIAL1_wp01(31- 11131.11AL1) t Measured Depth Reference: 31 -11 76.00ft (31 -11) 111,142H ES Calculation Method Minimum Curvature -1050- -, TIP /KOP m i n i 3 2 \ 0 WELL DETAILS: 31 -11 - 1200 - 4 - 5 Ground Level: 0.00 +N / -S +E / -W Northing Easting Latittude Longitude Slot 6 0.00 0.00 6007088.16 507830.23 70° 25 50.121 N 149° 56' 10.241 W 7. SECTION DETAILS ANNOTATIONS - 1500 • 8 Sec MD Inc Azi TVDSS +N /- - -S +E/-W DLeg TFace ; VSec Target Annotation _1650 1 7400.00 89.20 236.09 6150.95 - 1258.56 - 1284.92 0.00 0.00 - 1622.13 TIP / KOP 2 7430.00 85.31 238.34 6152.39 - 1274.78 - 1310.11 15.00 150.00 1645.99 2 9 3 7460.00 80.81 238.34 6156.01 - 1290.41 -1335.45 15.00 180.00 1669.34 3 c 1800 to 4 7490,00 76.92 236.03 6161.81 - 1306.35 - 1360.19 15.00 210.00 1692.78 4 5 7560.00 77.14 225.26 6177.57 - 1349.54 - 1412.85 15.00 270.00 1751.37 5 _ 1950 - u 6 - 7650.00 `89.85 220.68 6187.75 - 1414.84 - 1473.62 15.00 340.00 1833.53 6 0 7 7745.00 89.37 206.44 6188.40 - 1493.80 - 1526.00 15.00 268.00 1925.64 7 12 8 7831.00 90.50 193.59 6188.50 - 1574.44 - 1555.38 15.00 275.00 2011.46 8 ` -2100 9 8001.00 96.85 168.83 6177.45 - 1742.63 - 1559.06 15.00 285.00 2170.77 9 + 1 imp • 0 8081.00 94.63 156.97 6169.41 - 1818.57 - 1535.68 15.00 260.00 2234.13 10 _2250- 11 8181.00 94.46 172.02 6161.43 - 1914.35 -1509.12 15.00 90.00 2315.04 11 c 12 8308.00 89.09 190.31 6157.45 - 2040.67 - 1511.71 15.00 106.00 2434.64 12 13 8568.00 88.03 229.31 6164.25 - 2261.87 - 1638.42 15.00 92.00 2685.84 13 -2400 - } 14 8830.00 86.58 189.99 6177.07 - 2484.83 - 1765.38 15.00 267.00 2938.77 14 `. 14 , 15 8930.00 87.47 204.98 6182.30 - 2579.81 - 1795.31 15.00 87.00 3038.26 15 5 .2550 - • t s ° i 16 9165.00 87.36 169.70 6193.25 - 2808.96 - 1824.82 15.00 269.00 3263.69 TD p f cip - - 3I- 11/31 -11 AL1 - 2850 - ,>.,. -, ' -3000 _...... _..... __ _ _ ;.., .. ,.. >:1e -3150 �v -2700 -2550 -2400 -2250 -2100 -1950 -1800 -1650 -1500 -1350 -1200 -1050 -900 -750 -600 -450 -300 -150 0 West( -) /East( +) (150 ft/in) 6000 ,. - 6050 _...... ! _ _..... __ _.... ma 6100 y", _ __ _.... _... _ _.... _ __.... 1 :.... _ _. __. _. __ - ..._.. it l l "il- 6150 6200 TIP /KOP 2 3 4 a 1 . 11 12 13 i 4 -TD Q m _ 5 6 7 8 9 ] U ''., 14 1.5 6250 J cC af0i 31- 11/31 -11 All W 6300 : • C - 6350 _. : N - . ! 6400 6450 6500 -_.. 1450 1500 1550 1600 1650 1700 1750 1800 1850 1900 1950 2000 2050 2100 2150 2200 2250 2300 2350 2400 2450 2500 2550 2600 2650 2700 2750 2800 2850 2900 2950 3000 3050 3100 3150 3200 3250 3300 3350 Vertical Section at 200.00° (50 ft/in) Project: K Azimu"sb True Nadh WELLBORE DETAILS: 31 -11A REFERENCEINIFORMNTON °°' Pro / fatI uparuk River Unit Magnetic North 21 S7' Site: Kuparuk3l P Magreecreld Parent Wellbare: 31 -11 Co-ordinate (N(E) Reference: Well 31-11, True North r Well: 31-11 Strength .57E5e.an7 Vertical (ND) Refere 31 -11 5 76.00ft (31 -11) Tie on M17: 6300 j ^ f+��,rr� *] Wellbore: 31 - 11A Date 7/1 e0 .a3° Sec (VS) Reference: 61ot- (o.00µ O.o0E7 74.�r1 I�v+'b. �1'� PWn: DO M& (31 11/SI - 11A�: B� Measured Depth Reference: 31- 11576.0011(0 -11) Calculation Method: Minimum Curvature HUGHES 1200 ;I -a. I - 1 I — .:/ /.._.. _ _ -. _ 11-06/11-96 _._ .. / v 1000 9 ,o 800 /' r 51 12 //1 -1z 600 .. .... 400 • : /� .. . / 200 .. .... /! .. -200. .. : - ... -400 / i y i / -600 _. __. ... _.. _.. j - / .._ _.. ,-... "..� -800 /- / 1 �11/ 5 2 pe i ee .rte `/ , k 31- 04/31 -04 -1000 F u O 1 N -1200 /' : , d -1400. 4, , . 31- 13/31 -1? / , - ` Li 600 - : �:0 1�'� ; i� / . 800 .. 000 ! -2 200 ,. _. \ -2400 _.. _.._ ___ __ ___ -2600 ' 31 11/31 - 11A , -2800 ... .. ... _ _ '. #I 613 -- - -' - 3000 ; 31 II /31 111.1 600 - 3200 , . •' 31 12111 - 17 -3400 / i -3600 - • is ,, - 3800 : c`S - '.. -4000 _..... ..__ • 6-2,110 • __. .... :... _...... 31 -11 @ 76.0011(31 -11 � r 31- u/31 -(5 __ c -4200- — 642 - x111 -4400 - 4200 -4000 -3800 -3600 -3400 -3200 -3000 -2800 -2600 -2400 -2200 -2000 -1800 -1600 -1400 -1200 -1000 -800 -600 -400 -200 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 West( -) /East( +) (200 ft/in) 31 -11A, Ali, & AL2 Proposed CTD Sidetrack Revision Updated: 10- Jun -10 Camco TRMAXX -5E SSSV @ 2212 MD (2.813" min ID, X- profile) rlh3xiii KEY _ 3 -1/2 ", 9.3# L -80 EUE 8rd -Mod Tubing to surface Equipment and perforations set in parent wellbore — 3 -112" Camco MMG gas lift mandrels (5) @ 2512', 3702', 4760', 5668', & 6074' Equipment set and lateral drilled 16" 62#1-I-40 shoe during first CTD project @ 116' MD IMI X' landing nipple @ 6123' MD (2.813" min ID) Equipment set and laterals drilled �/ during second CTD project 9 -5/8" 36# J -55 Baker 3 -1/2" seal assembly 6131' - 6143' MD shoe © 3383' MD 80-40 PBR at 6132' - 6145' Baker KBH Anchor Seal Assy at 6145' MD BOW Baker SAB 40 -32 packer @ 6146' MD 1111 Whipstock @ 6397' 'X' landing nipple @ 6156' MD (2.813" min ID) 31.11A L2 MD ME Holes shot in 3 -1/2" straddle at –6408' -6413' & 6213' MD ( sand, w Kickolf from 4 7360' (Baker monobore Full deployment ent sleeve e @ 6300' whipstock) I.PSECE.461Vinaln _ Baker F1 permanent packer @ 6422 MD (e -line set) Solid liner from 6300-6450' ill - 80 -40 Sealbore extension (6425'- 6430') Slotted liner from 6450' to To 3 -1/2 "straddle TD @ 9180' cemented in place 'D' landing nipple © 6433' MD (2.750" min ID) Cast Iro Bridge Plug . r WLEG @ 6438' MD CD FISH: 3 S{ fkit monobore ni 31 -11A whipstock at 6422' �i'ss ', (A sand, wp10) ■•■• (TOWS) ,<, I '�.* _ – ": ®. - "� – -- .._- ------- ...... . ....... - . - . ...... ........ - " Kickoff from 31-11 @6397' '-� " _ - - •-' . - Liner lop billet @ 7400' Sl liner from 7400' to TD FISH: 3 -1/2 � �_ ` '• ° . monobore TD @ 9200 • whipstock @ `�' �`�j'� ' ' unknown depth ■ _ r r. m. A sand perfs _ _ f A3: 6437' - 6454' 31.11 L1 A2. 6457' - 6486' ^ (A2 31 3 sand, w 1 Al: 6494' - 6503' _ Kickoff from 31 -11 @ 6409' (A1 sand, wp05) Kickoff from 31 @ 7400' Shorty deployment sleeve @ 7590' Liner lop billet ltel @ 7360' 0' Sloped liner from 7590' to TD Sloped liner from 7360' -10. L TD @ 9437' TD @ 9165' • 7" 26# J -55 shoe @ 6761' MD • . Nabors CDR -2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing cfq) I 1 Lubricator Riser \ Annular/ Blind /Shear 2" Pipe / Slip (CT) Pump into Lubricator J L i l above BHA rams 1 F Choke 1 2 -3/8" Pipe / Slip (BHA) I' Choke Equalize Manifold 2 -3/8 " Pipe / Slip (BHA) L 'P Kill � � 1 r 8 lr Blind / Shear 2" Pipe / Slip (CT) Choke 2 1 Swab Valves Wing Valves 1 ® � ®4 Tree Flow Cross 0 Surface Safety Valve BOPE: 7- 1/16 ", 5M psi, TOT Choke Line: 2- 1/16 ", 5M psi 9Q Master Valve Kill Line: 2- 1/16 ", 5M psi 77 �� Equalizing Lines: 2- 1/16 ", 5M psi Choke Manifold: 3 -1/8 ", 5M psi Riser: 7- 1/16 ", 5M psi, C062 Union '''' rl I elm AI ,, ■ '' 'N i t I V, ,, .— 1 • • TRANSMITTAL LETTER CHECKLIST ` WELL NAME < l / PTD# 2- /0 C' Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: K/.4 /C 0 POOL: / J ( (J 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 l (If last two digits in Permit No. 2/) Ci7 t; API No. 50 -6 - -61 . 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(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 - WELL PERMIT CHECKLField & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 - Well Name: KUPARUK RIV UNIT 31 -11AL1 - Program DEV Well bore seg 0 PTD #: 2100750 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV / PEND GeoArea 890 Unit 11160 On /Off Shore On —__ Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes Lateral: kick - offpoint, top prod interval & TD all lie within ADL 25631. 3 Unique well name and number Yes . 4 Well located in a defined pool Yes Kuparuk River Oil Pool, govemed by Conservation Order No. 432C 5 Well located proper distance from drilling unit boundary Yes Conservation Order No. 432C contains no spacing restrictions with respect to drilling unit 6 Well located proper distance from other wells Yes boundaries and no interwell spacing restrictions. Wellbore will be more than 4 miles 7 Sufficient acreage available in drilling unit Yes from an external property line where ownership or landownership changes. _ 8 If deviated, is wellbore plat included Yes 9 Operator only affected party _ Yes 10 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes SFD 6/15/2010 13 Can permit be approved before 15 -day wait Yes • 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre-produced injector: duration of pre production less than 3 months (For service well only) NA _ 17 Nonconven, gas conforms to AS31.05.03Q(y1 -D) NA 18 Conductor string provided NA Conductor set in 31 -11 Engineering 19 Surface casing protects all known USDWs NA Surface casing set 31 -11 20 CMT vol adequate to circulate on conductor & surf csg NA _ - _ - _ Surface casing cemented in 31 -11 21 CMT vol adequate to tie -in long string to surf csg NA Production casing set in 31 -11 22 CMT will over all known productive horizons No Openhole slotted liner is planned. 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. 25 If are- drill, has a 10 -403 for abandonment been approved Yes 310 -177 and 310 -178 26 Adequate wellbore separation proposed Yes Proximity analysis performed . No issues. 27 Ifdiverter required, does it meet regulations NA Wellhead in place... BOP to be placed on production tree. _ Appr Date 28 Drilling fluid program schematic & equip list adequate - Yes Max formation press = 4452 psi ( 13.9 ppg) Will drill with 10 ppg FloPro mud and use MPD technique. GLS 6/30/2010 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP = 3800 psi will test BOP to 4500 psi • 31 Choke manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S on 3I pad. Rig has sensors and alarms. 34 Mechanical condition of wells within APR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No 31 - 11 measured 150 ppm H25 in June 2009; measures required 1 Geology 36 Data presented on potential overpressure zones Yes Expected reservoirpressure is between 13.0 and 13.2 to as high as 13.9 ppg EMW. Appr Date 37 Seismic analysis of shallow gas zones NA Wellbore will be drilled using coiled tubing, 10.0 ppg mud, and Managed Pressure SFD 6/15/2010 38 Seabed condition survey (if off - shore) NA Drilling technique to maintain well control and wellbore stability. 39 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering P 0, Commissioner: Date: Commissioner: Date er Date ta, 4 -0n -049 I 6-30-to 1 r
