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Home My WebLink About212-1881. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Braiden head repair ConocoPhillips Alaska, Inc.Development Exploratory 3. Address:Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11135 feet feet true vertical 6511 feet feet Effective Depth measured feet 8127 feet true vertical feet 6246 feet Perforation depth Measured depth 9087-11134 feet True Vertical depth 6489-6511 feet Tubing (size, grade, measured and true vertical depth)3 1/2" L-80 8120 6241 3 1/2" L-80 8487 6478 Packers and SSSV (type, measured and true vertical depth)Baker FHL Retrievable Packer 8128 6246 Camco Trmaxx-cmt-sr-5 Safety Valve 1795 1774 12. Stimulation or cement squeeze summary:N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: 8/3/2021 Contact Phone: N/A Authorized Name: Authorized Signature with date: Senior Engineer:Senior Res. Engineer: 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283 WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Roger Mouser / Roger Winter n1927@conocophillips.com 659-7506 Well Integrity Field Supervisor ----- ----- N/A Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Liner 2059 2 3/8"11135 6511 Production 8416 7"8460 6465 Conductor 44 16"80 80 Intermediate Surface 4435 9 5/8"4470 3799 Packer measured true vertical Casing Length Size MD TVD N/A Kuparuk River/Kuparuk River Oil Plugs measured Junk measured Burst Collapse 212-188 500-292-1357-01-00 ADL0025628/ADL0025629/ADL0025634 Kuparuk Riv Unit 3C-11A P.O. Box 100630, Anchorage, Alaska 99508 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name 4. Well Class Before Work:5. Permit to Drill Number: ntt e Fra O g g g l g y e 6. A y G L PG AAC 25 R r Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 8:36 am, Aug 03, 2021 Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2021.08.03 05:59:40-08'00' Foxit PhantomPDF Version: 10.1.3 Roger Winter DSR-8/3/21VTL 8/9/21 RBDMS HEW 8/5/2021 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 03 August 2021 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-404 for ConocoPhillips Alaska, Inc. well KUP 3C-11 (PTD 212-188) to repair Braiden head. Summary: Braiden head was leaking from thread area – seal welded area. Please contact Roger Winter or Roger Mouser at 659-7506 if you have any questions. Sincerely, Roger Winter Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2021.08.03 05:59:14-08'00' Foxit PhantomPDF Version: 10.1.3 Roger Winter Date Event Summary Executive Summary Repair braiden head by seal welding leak area. 06/13/21 Prep leaking area with wire wheel. 07/30/21 Purge OA w/N2 and welders made 3 seal welds in leaking area. 08/02/21 DHD confirmed weld repair with MITOA to 1800 psi. Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 8,442.0 2/21/2013 3C-11A hipshkf Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Install new GLD 10/10/2019 3C-11A fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 80.0 Set Depth (TVD) … 80.0 Wt/Len (l… 65.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 34.6 Set Depth (ftKB) 4,469.5 Set Depth (TVD) … 3,798.6 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION Post S/T OD (in) 7 ID (in) 6.28 Top (ftKB) 43.6 Set Depth (ftKB) 8,460.0 Set Depth (TVD) … 6,464.9 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Casing Description WINDOW AL1 OD (in) 7 ID (in) 6.00 Top (ftKB) 8,443.0 Set Depth (ftKB) 8,450.0 Set Depth (TVD) … 6,459.1 Wt/Len (l… 26.00 Grade Top Thread Casing Description LINER A OD (in) 2 3/8 ID (in) 2.00 Top (ftKB) 9,075.7 Set Depth (ftKB) 11,135.0 Set Depth (TVD) … 6,511.3 Wt/Len (l… 4.60 Grade L-80 Top Thread ST-L Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 9,075.7 6,489.7 96.20 BILLET ANCHORED BILLET 1.000 9,702.6 6,494.3 87.40 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.910 Tubing Strings Tubing Description TUBING WO Upper String Ma… 3 1/2 ID (in) 2.92 Top (ftKB) 32.6 Set Depth (ft… 8,120.1 Set Depth (TVD) (… 6,240.5 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 32.6 32.6 0.00 HANGER TUBING HANGER 3.500 1,794.6 1,773.8 22.14 SAFETY VLV CAMCO TRMAXX-CMT-SR-5 SAFETY VALVE w/ 2.813" X- PROFILE 2.922 8,097.4 6,225.6 48.91 LOCATOR BAKER SEAL LOCATOR 2.960 8,097.7 6,225.8 48.92 SEAL ASSY BAKER 80-40 PBR SEAL ASSEMBLY 2.990 Tubing Description TUBING WO Lower String Ma… 3 1/2 ID (in) 2.92 Top (ftKB) 8,104.7 Set Depth (ft… 8,487.0 Set Depth (TVD) (… 6,477.8 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 8,104.7 6,230.4 48.90 PBR BAKER 80-40 PBR 2.980 8,127.8 6,245.7 48.39 PACKER BAKER FHL RETRIEVABLE PACKER 2.940 8,147.5 6,258.8 48.19 NIPPLE HES X NIPPLE 2.812 8,478.9 6,474.4 63.43 OVERSHOT BAKER POORBOY TUBING STUB OVERSHOT w/ PACKING 2.980 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 8,437.0 6,450.7 48.81 CTD Liner 3C-11 AL1 Liner Top 2/4/2013 1.992 8,442.0 6,454.0 48.86 WHIPSTOCK THRU-TUBING WHIPSTOCK FOR CTD LATERALS 1/23/2013 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 9,087.0 9,689.0 6,488.5 6,493.7 A-3, 3C-11A 1/29/2013 32.0 SLOTS 9,703.0 11,134.0 6,494.3 6,511.4 A-3, 3C-11A 1/29/2013 32.0 SLOTS Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,737.1 2,544.9 47.28 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,264.0 10/10/2019 2 4,676.3 3,942.3 46.73 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,268.0 10/9/2019 3 6,177.9 4,942.2 46.12 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,269.0 10/9/2019 4 7,278.3 5,686.9 47.83 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,263.0 10/9/2019 5 8,012.3 6,169.7 49.15 CAMCO MMG 1 1/2 GAS LIFT OPEN OPEN 6/7/2021 Notes: General & Safety End Date Annotation 2/5/2013 NOTE: WELL SIDETRACKED TO A, AL1 (AL1 OFF THE MAIN WELLBORE) DEVIATED, 3C-11A, 6/8/2021 7:42:17 AM Vertical schematic (actual) LINER A; 9,075.7-11,135.0 SLOTS; 9,703.0-11,134.0 SLOTS; 9,087.0-9,689.0 LINER AL1; 8,437.5-11,152.0 SLOTS; 8,751.0-9,651.0 OVERSHOT; 8,478.9 PRODUCTION Post S/T; 43.6-8,460.0 WINDOW AL1; 8,443.0-8,450.0 WHIPSTOCK; 8,442.0 CMT SQZ; 8,440.0-8,448.0 IPERF; 8,386.0-8,400.0 CMT SQZ; 8,364.0-8,368.0 CMT SQZ; 8,355.0 ftKB NIPPLE; 8,147.4 PX PLUG W/ GAUGE; 8,139.0 PACKER; 8,127.8 PBR; 8,104.7 SEAL ASSY; 8,097.7 LOCATOR; 8,097.4 GAS LIFT; 8,012.3 GAS LIFT; 7,278.3 GAS LIFT; 6,177.9 GAS LIFT; 4,676.3 SURFACE; 34.6-4,469.5 GAS LIFT; 2,737.1 SAFETY VLV; 1,794.6 CONDUCTOR; 36.0-80.0 HANGER; 32.6 KUP PROD KB-Grd (ft) 34.69 Rig Release Date 6/25/1985 3C-11A ... TD Act Btm (ftKB) 11,135.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292135701 Wellbore Status PROD Max Angle & MD Incl (°) 97.05 MD (ftKB) 8,900.33 WELLNAME WELLBORE3C-11A Annotation Last WO: End Date 11/30/2012 H2S (ppm) DateComment SSSV: TRDP 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. Sfq, Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RE AN: OVERSIZED: NOTES: Color Items: ❑ Maps: rayscale Items: gs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: Date: 1 J 5' /s/ mP Project Proofing BY: Maria Date: J/c?//cS' /s/ Scanning Preparation I x 30 = 30 + a(to =TOTAL PAGES 56) (Count does not include cover sheet) BY: Maria Date: I/7 /s /s/ Production Scanning Stage 1 Page Count from Scanned File: (5 7 (Count does include cover heet) Page Count Matches Number in Scan in Preparation: YES NO BY: Date: 7 IS /s/ vvif" Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: 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 9o I r CO N E /Q 4 a Eci z z z v) as as m r) Z c E Co E a >- >- I N E >. E (1) I[o) III N a p- C U 5 a) N C ,1 ,/, V, a V, U O) Q 1 Z 2 a) ani c aa) a 0- 0 0 1-cce ••••-• a aEl 0 a I Q 1 s y I 0 o m c O a) a) o CK m o rn O 0 0 _1 .imi6O1lIllpr J U o I rii a a O) a O `� c '.3 Z ° 'di otlIli U o o coo ap) p o 0) o a z p oily) �.s 7 E �J V a+ 715 • oa) �� .� o m � Z �Z ' u, o .o = E tea) > E O E Q (A J U N COT c0 O i7 J a <oIm ° IX < o o 2CL i-Ce 2CL 2w o 67 O d ca _ d O C -0 c,-) M M M coa+' 1 CL 0 m E _ ru d co 7 Q ,Jj Y > O O O O O W co y N N N N N I w m v v v v U) Z CO a) Q 0 N V V V a7 a E W z 1 — �, �; 2 21 a a a a a m as rn a V U -C.3. OU 1O O 0 0 0 1 E E Z a 0 in in In in va ) ucu ? re 0 ONQ 0ao - C) J G. c r r r r 7 oo 5 I a (� V' vv 2o z1 , i O 14- E o. I , 1 U7 � i ail � Z ~ V) i J � < o • � z >- } >- / co / g /Q M cr, ti 2 1 p IF— F_ M O d J2 O O O 0 0 0 �o y co cZ E m> N,n a)o D in a7 • cn C a) E V) CO / N J N to to N C o E Nkl: > > c, t _ - cn Cl) ce Q TE co 13 CD c C Co , a Q a co I— a '21 c° cOcaQ czEOLu o c Q U wwww a) T a) N • Io m > > 5 > o 2 0 I h.E • N CO 1/, N • Z 7 (n a) a) a) N a) N a a a a , d • / c E; o o 0 0 0 1E 1 /Q 7 03 p Z (moo ,'I Z; aa) > > > > Ii rn I oCFoo E o p , z o ° c T co _1 .a.; . / o / ,1 m zO O O W ° Z N N N N E 0 O O 3 N re Qca , W C ma) a) Ire oc y O € E E E ; z a 17, aeg ,o ° 0 u 5 0).z a H ' F- c c yr o .. �� W LL mto ° � 0 1 2 o o V c co O I ce z W 0 v a)H ' 0 a = 0 E a a j 0 1- 3 -J c 1 ' ' ' w 3 z 0 a` i� 0 0 iii / RECEIVED ,A& BAKER PRINT DISTRIBUTIONTAPR 0 4 2013 LIS HUGHES AOGCC COMPANY ConocoPhillips,Alaska Inc. INTERMEDIATE FINAL Yes (mandatory) WELL NAME 3C-11A RUN NUMBER (mandatory) 225 1 FIELD Kuparuk BH SALESMAN Anyanwu,Okechukwu(OKEY) (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF (mandatory) LOG DATE: January 30,2013 TODAYS DATE: 4/3/2013 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY FIELD FINAL (digitalCD / ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OFPRINTS #Or PHIN IS #OF COPIES #OF COPIES V V v 1 ConocoPhillips Alaska,Inc. I 1 I I NSK Wells Aide,NSK 69 ATTN:MAIL ROOM 700 G Street, Anchorage,AK 99501 2 AOGCC 1 1 Christine Mahnken 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 3BP I 1 I 1 I I Petrotechnical Data Center,MB33 David Douglas 900 East Benson Blvd Anchorage,Alaska 99508 4 Chevron/KRU REP I 1 I 1 I I Glenn Fredrick 3800 Center Point Drive,Suite 100 Anchorage,Alaska 99503 5 Brandon Tucker,NRT I I 1 I I I State of Alaska;DNR,Div.of Oil and Gas 550 W.7th Ave,Suite 800 Anchorage,Alaska 99501-3510 TOTALS FOR THIS PAGE: 0 4 4 0 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a.Well Status: Oil 0 . Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 1b.Well Class 20AAC 25.105 20AAC 25.110 Development ❑✓ ' Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions. Service ❑ StratigraphicTest❑ 2.Operator Name. 5 Date Comp,Susp., 12 Permit to Drill Number ConocoPhillips Alaska,Inc. or Aband.: February 5,2013 212-188/ 3.Address: 6 Date Spudded 13 API Number: P.O. Box 100360,Anchorage,AK 99510-0360 January 23,2013 50-029-21357-01 I 4a.Location of Well(Governmental Section): 7.Date TD Reached. 14.Well Name and Number Surface: 1177'FNL,876'FEL,Sec. 14,T12N, R9E, UM • January 29,2013 3C-11A- Top of Productive Horizon 8. KB(ft above MSL): 82'RKB 15.Field/Pool(s): 1392'FNL,843'FEL,Sec. 13,T12N, R9E,UM GL(ft above MSL): 47'AMSL Kuparuk River Field' Total Depth. 9 Plug Back Depth(MD+TVD) 386'FSL, 134'FWL,Sec.7,T12N, R10E, UM 11135'MD/6511'TVD • Kupuruk River Oil Pool' 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation. Surface: x-528698 y- 5995255 Zone-4 11135'MD/6511'TVD • ADL 25634,25628,25629 TPI: x-534011 y- 5995063 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit Total Depth: x-534980 y- 5996845 Zone-4 1795'MD/1774'TVD • 2567,2581,2562 18 Directional Survey: Yes ❑✓ No❑ 19.Water Depth,if Offshore 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1715'MD/1700'ND 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25 071) 22.Re-dnll/Lateral Top Window MD/TVD GR/Res 8442'MD/6454'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" 62.5# H-40 36' 116' 36' 116' 24" 215 sx CS II 9.625" 36# J-55 35' 4470' 35' 3799' 12.25" 1360 sx AS III,320 sx Class G 7" 26# J-55 44' 8859' 44' 6729' 8.5" 325 sx Class G 2.375" 4.7# L-80 9076' 11135' ' 6490' 6511' 3.25" slotted liner 24 Open to production or injection? Yes ❑ No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number) SIZE DEPTH SET(MD) PACKER SET(MD/IVO) 3.5" 8487' 8128'MD/6246'ND and • slotted liner from 9076-11135'MD 4 6490'-6511'ND 8487'MD/6484'ND i� ��ED 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. y Was hydraulic fracturing used during completion? Yes❑ No a ...f:-i, i''_` .,cps ' to A �g 2 6 2012 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED pOGGG , 27 PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting on facility hook-up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28 CORE DATA Conventional Core(s)Acquired? Yes ❑ No 2, Sidewall Cores Acquired? Yes ❑ No 0• If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE RBDMS FEB 2 6 2013 8i6 * Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original only /eft ,- ;67.5.' 513 �'b\� G 29 GEOLOGIC MARKERS(List all formations and mark,.,encountered): 30 FORMATION TESTS NAME MD TVD Well tested? Yes Q No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1715' 1700' needed,and submit detailed test information per 20 AAC 25.071. Kuparuk A3 8952' 6502' N/A Formation at total depth: Kuparuk A3 31. LIST OF ATTACHMENTS Summary of Daily Operations,schematic 32 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kai Starck @ 263-4093 Email: Kai.Starck@conocoohillios.com Pnnted Name Lamar Gantt Title: CTD Supervisor Signature tu [°k,L ( AiWk) Phone 263-4021 Date Z/ZS//3 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25 071. Form 10-407 Revised 10/2012 t KUP 3C-11A• ConocoPhillips 0; Well Attributes Max Angle&MD TD Alaska Inc Wellbore API)UWI Field Name Well Status Incl(°) MD MKS) Act Btm(RKB) conoarP,yt 500292135701 KUPARUK RIVER UNIT PROD 97.05 8,900.33 11,135.0 "'° Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date "' Well Conry,:-3C-17A,2/21/2013 2.14:43 PM SSSV:TRDP 100 12/13/2011 Last WO: 11/30/2012 34.69 6/25/1985 Schema9c-Actual Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag:SLM Rev Reason:WELL SIDETRACKED TO A,AL1 osborl 2/21/2013 HANGER,33 .^" Casing Strings Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd CONDUCTOR 16 15.062 36.0 80.0 80.0 65.50 H-40 WELDED v a,. Cuing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String WL..String...String Top Thrd SURFACE 9 5/8 8.921 34.6 4,469.5 3,798.6 36.00 J-55 BTC Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String WL..String...String Top Thrd PRODUCTION 7 6.276 43.6 8,460.0 6,464.2 26.00 J-55 BTC Post S/T Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd WINDOW AL1 7 6.000 8,443.0 8,450.0 6,458.9 26.00 CONDUCTOR. Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd 36-80 LINER A 2 3/8 1.995 9,075.7 11,135.0 6,511.3 4.60 L-80 ST-L Liner Details - Top Depth (ND) Top Incl 5005... Top(RKB) (RKB) (°) Item Description Comment ID(In) SAFETYLv,V - 1 I 9075.7 6,489.7 96.20 BILLET ANCHORED BILLET 1.000 95 1 9,702.6 6,494.3 87.30 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.910- Tubing .910Tubing Strings -- Tubing Description String 0... String ID...Top(RKB) Set Depth(t...Set Depth(ND)... String Wt...String...String Top Thrd GAS LIFT, TUBING WO Upper 31/2 2.922 32.6 8,120.1 6,240.4 9.30 L-80 EUE-8rd 2,737 Completion Details • Top Depth (ND) Topincl Nomi... (n� Top(RKB) (RKB) )°) Item Description Comment ID(in) I' 32.6 32.6 -0.11 HANGER TUBING HANGER 3.500 1,794.6 1,773.8 22.14 SAFETY VLV CAMCO TRMA)O(-CMT-SR-5 SAFETY VALVE w/2.813"X-PROFILE 2.922 SURFACE,__-4 & 8,097.4 6,225.6 49.04 LOCATOR BAKER SEAL LOCATOR 2.960 I 35 4,470 8,097.7 6,225.8 49.03 SEAL ASSY BAKER 80-40 PBR SEAL ASSEMBLY 2.990 _J Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String WL..String...String Top Thrd GAS L J 4 TUBING WO Lower 3 1/2 2.922 8,104.7 8,487.0 6,477.5 9.30 L-80 EUE-8rd Completion Details Top Depth (ND) Top Incl Komi... Top(RKB) (*KB) (') Rem Description Comment ID(In) GAS LIFT. - 8,104.7 6,230.4 48.90 PBR BAKER 80-40 PBR 2.980 0-t78 8,127.8 6,245.6 47.82 PACKER BAKER FHL RETRIEVABLE PACKER 2.940 8,147.5 6,258.7 48.19 NIPPLE HESXNIPPLE 2.812 8,478.9 6,473.6 64.76 OVERSHOT BAKER POORBOY TUBING STUB OVERSHOT w/PACKING 2.980 GAS LIFT, _ ; ze Other In Hole ireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (ND) Top Incl Top(RKB) (RKB) (°) Description Comment Run Date ID(in) 8,442.0 6,454.0 48.86 WHIPSTOCK THRU-TUBING WHIPSTOCK FOR CTD LATERALS 1/23/2013 0.000 GAS LIFT. - Perforations&Slots Shot Top(ND) Btm(TVD) Dens Top(RKB)Btm(RKB) (MB) . (RKB) Zone Date (sh... Type Comment LOCATOR, 9,087.0 9,689.0 6,488. 6,493.69 - 1/29/2013 32.0 SLOTS 8.097 9,703.0 11,134.0 6,494.3 6,511.4 1/29/2013 32.0 SLOTS SEAL ASSY. ,098 Notes:General&Safety 8 FOR,8,105 2 End Date Annotation 2/5/2013 NOTE:WELL SIDETRACKED TO A,AL1(AL1 OFF THE MAIN WELLBORE) PACKER.8,128 NIPPLE.8,147 fill CMT SOZ, 8,384-8.388 IPERF, \ 11,388-0,400 CMT SOZ. 8,440-0.448 WHIPSTOCK, 8,442 • WINDOW AL1, • 8,443-8,450 PRODUCTION i Pop SR. 448.355 �': CMT SOZ, 8,355 III OVERSHOT, 25 Mandrel Details .-. 8'479 ,® Top Depth Top Port S... (ND) Incl OD Valve Latch Size TRO Run N.„Top MB) MKS) (°) Make Model (in) Sere Type Type (in)• (psi) Run Date Corn... 1 2,737.1 2,544.9 47.24 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 11/28/2012 SLOTS, 2 4,676.3 3,942.3 46.73'CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 11/28/2012 9.087-9.689 3 6,177.9 4,942.2 46.10 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 11/28/2012 . 4 7,278.3 5,686.9 47.83 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 11/28/2012 5 8,012.3 6,169.8-49.78'CAMCO MMG ' 1 12 GAS LIFT OPEN 0.000 0.0 12/14/2012 SLOTS. 9,703-11,134 LINER A, 9,076-11,135 TD(3C-11A), 11,136 co Q E O O QN n.,- iv I- o 0 31c) II II 3 coCo .6 Y ti eo m p Q � I Ug ,. 1` - a) o co N 2 oo C_ N H N E M F- Ln O to o 0 N N io N Y iy a) (0 cco - Ni C) 0co - Q co Y II II _ L1.,_ it 0) `C N- - '0' CO0 N co Co L) N CO o d, 7 -c F- F- •ct co�l N N O to c 2 o N CO v 0 N O �` � c y V CoC° cn U O tn.., O o �/-om X � � �fr Q � 0 (Ca) NC II < F- -0 'c • ,c„ u = a o_o)� II C J C W 'd P CO c N N U CO d(V 1 2 Q N r O 0 c 62 - co N D v U y L M ` 0 N 'O.N O _ 3 Y V \ \ `- � � N (n C N O co cF7 N O co �Y N i w _c co = - 2 - 0 ' a 0 a o .o it > cO coi N co c i N C O _ _C O M co `_"i N O O 0 ?. 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J ) § § \ : O %U O . io C / � 0 U ( / k = } ; u 0- (/) & & ! % :: -4C-11 Pre-Rig Well Work DATE SUMMARY 12/11/2012 (PRE-CTD) RIG WORK, BPV IN PROFILE, MV, SSV, SV PASSED PT, SSV, SV PASSED DDT. 12/13/2012 ASSIST VALVE CREW PULL BPV. DRIFT TO RHC PLUG W/ PULLING TOOL AND CONFIRM NO BALL & ROD IN PLUG. IN PROGRESS. 12/14/2012 TAG RHC PLUG BODY WITH LIB; PULL SOV FROM @ 8012' RKB. PERFORM NO FLOW CLOSURE TEST ON TRSSSV . ( GOOD TEST ). LAY DOWN EQUIPMENT DUE TO COLD WEATHER. IN PROGRESS. 12/16/2012 SET DV© 8012' RKB; MIT-IA 2500 ( PASS ) PULLED RHCM BODY @ 8147' RKB; TAG FILL @ 8480' RKB ( EST 27' FILL ON CATCHER ). JOB COMPLETE 12/29/2012 PERFORATE INTERVAL 8460'-8464' USING 2.5" HSC LOADED 6 SPF, PHASED 60 DEG. LOG CORRELATED TO SLB CET LOG DATED 29 JUN 1985. TUBING DETAIL RECORD APPEARS TO BE 13' SHALLOW IN RELATION TO THE CET LOG. JOB IN PROGRESS. 12/30/2012 PERFORATE INTERVAL 8364'-8368' USING 2.5" HSC LOADED 6 SPF, PHASED 60 DEG, MILLENIUM HMX CHARGES. NO PRESSURE CHANGE AFTER PERFORATING. LOG CORRELATED TO SLB CET LOG DATED 29 JUN 1985. LOG BOTTOM HOLE PRESSURE SURVEY. 8450' -3731 PSI, 154.4 F, 8299' - 3647.62 PSI, 152.9 F. WAITED ON BOTTOM FOR WELL TO STABILIZE AND APPEARS TO STILL BE EQUALIZING DURING LOG PASSES. READY FOR LRS. 12/31/2012 (PRE-CTD) MV DDT PASSED, SSV DDT PASSED, SV DDT PASSED. LRS INJECTIVITY TEST RESULTS: 2850 PSI AT 0.5 BPM, 3000 PSI AT 0.7 BPM. PUMPED TOTAL 43 BBLS DIESEL DOWN TUBING. 1/6/2013 STANDBY TILL 12:00 WAITING ON WEATHER. MOBILIZE CTU TO LOCATION AND STAGE EQUIPMENT. WAITING ON ASRC TO RIG UP HARDLINE TO SUPPORT THE OPERATION. 1/7/2013 PERFOMED SQUEEZE USING 15.8 PPG CEMENT. SQUEEZED APPROXIMATELY 3 BBLS BEHIND PIPE. ACHIEVED SQUEEZE PRESSURE OF 1800 PSI. WASHED DOWN TO TOP OF CEMENT AT 8355'. TRAPPED 1300 PSI ON SURFACE. WELL FREEZE PROTECTED JOB IN PROGRESS. 1/8/2013 PERFORMED BOPE TEST. MILLED CEMENT FROM TAG AT 8360' CORRECTED DEPTH TO 8470' USING 2.68" -2.98" BICENTER BIT. SAW GOOD MOTOR WORK THROUGHOUT JOB. MAINTAINED 1:1 RETURNS THROUGHOUT JOB. WELL FREEZE PROTECTED TO 2000' TVD. JOB COMPLETE. 1/10/2013 TAG TOC @ 8478' RKB. DRIFT TBG BAKER DUMMY WHIPSTOCK TO TOC @ 8478' RKB; MITT AGAINST CEMENT PLUG TO 2000 PSI ( PASSED ) READY FOR BPV AND CTD. ConocoPhitlips Time Log & Summary WefNlew Web Reporting Report Well Name: 3C-11 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 1/21/2013 10:30:00 PM Rig Release: 2/5/2013 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/21/2013 24 hr Summary Arrive 3C pad 4:15am.Spot rig, Rig up and safe out rig for operations.Start BOPE testing.State Witness Waived By Chuck Sheve 00:00 07:00 7.00 MIRU MOVE MOB P Moving rig from 3Q-06 to 3C-11 07:00 11:00 4.00 MIRU MOVE MOB P Spot rig modules on 3C-11,spot shop, 11:00 17:00 6.00 MIRU MOVE MOB P RU Putz,berm up around cellar.RU interconnect,steam,landings,load pits. 17:00 22:30 5.50 MIRU WHDBO NUND P NU BOPE equipment,hammer up all flanges,found several loose flanges. 22:30 00:00 1.50 MIRU WHDBO BOPE P Start full BOPE test 250/4000 annular 2500 psi.Test witness waived by Chuck Shieve,AOGCC. Rig Accept 22:30 01/22/2013 Finished BOP test,C-9 and C-10 failed. Unfreeze TT line. PT PDL's and TT line. 00:00 08:30 8.50 0 0 MIRU WHDBO BOPE P Cont.testing BOP's. 08:30 09:00 0.50 0 0 MIRU WHDBO BOPE P BOP test complete.2 failures.C9, C10,Choke manifold.Valves replaced.Passed retest 09:00 15:30 6.50 0 0 MIRU WHDBOCTOP P RD/LD BOP test joint,blow down test pump.Cut CTC off,MU to well, fill CT,reverse circ.for slackmanagement.Cut 6'CT to find E-line.Cut a total of 20'for clean pipe.MU CTC,pull test 35k.Tiger tank line froze up,Thaw out.MU drilling head,psi test 4K. 15:30 16:30 1.00 0 0 MIRU WHDBO BOPE P Pull BPV. 16:30 17:30 1.00 0 0 MIRU WHDBO CTOP P MU nozzle,stab onto well and pump slack forward,Cont.to thaw tiger tank line. 17:30 18:00 0.50 0 0 MIRU WHDBOCTOP P Crew change, PJSM 18:00 20:30 2.50 0 0 MIRU WHDBO CTOP T Call Dispatch to swap TT out. Continue working on thawing tiger tank line. 20:30 21:00 0.50 0 0 MIRU WHDBO CTOP P Cancel TT swap through dispatch.TT line free of ice. Round up crew for PJSM on plan forward. 21:00 00:00 3.00 0 0 MIRU WHDBO CTOP P Unstab INJH,Test TT line and PDL's. 01/23/2013 Trip in hole and set TOWS at 8442ft. POOH,M/U,and RIH with first milling BHA. Mill 6ft of dual string exit. Page 1 of 15 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:30 1.50 0 0 PROD1 RPEQP1PULD P Rig back PDL's. Bleed 140 well head pressure off to tiger tank.install fuseable cab onto SSV. Stab INJH, Test BHI tools 01:30 05:00 3.50 72 8,000 PROD1 RPEQPI TRIP P RIH w WS setting BHA#1 05:00 06:00 1.00 8,000 8,452 PROD1 RPEQP1 DLOG P Tie in depth+1'correction, Perform CCL 8000'-8460' 06:00 06:30 0.50 8,452 8,452 PROD1 RPEQPI WPST P WS on depth,8442'TOWS,8452.29 MD.Close EDC,Set whipstock highside,3700psi CTP,4k wob.set down 2k wob. PU,WS set. 06:30 08:45 2.25 8,452 0 PROD1 RPEQP1TRIP P POOH displacing SW out of hole with 9.6ppg Flo-Pro 08:45 09:00 0.25 0 0 PROD1 RPEQPI SFTY P At surface, PJSM,flow check 09:00 09:30 0.50 0 0 PROD1 RPEQP1 PULD P LD BHA 09:30 10:15 0.75 0 0 PROD1 WHPST PULD P PU milling BHA(.6 ako,2.8 whipstock mill,w/string reamer) 10:15 12:15 2.00 73 8,050 PROD1 WHPST TRIP P RIH 12:15 12:30 0.25 8,050 8,050 PROD1 WHPST DLOG P Tie in depth to K1. +2.5'correction 12:30 12:45 0.25 8,442 8,442 PROD1 WHPST TRIP P RIH,dry tag TOWS 8442.6'.PU 35K. Online with pumps 1.37 bpm,3866 4 ctp off bottom, 19k ctw 12:45 14:45 2.00 8,442 8,444 PROD1 WHPST MILL P Start Time milling 8442.2'A 1 fph 1.37 bpm,3925psi ctp,on bottom, 1.5k wob. 14:45 20:45 6.00 8,444 8,446 PROD1 WHPST MILL P Stall.Clean PU. RBIH cont milling, slow down ROP.6-.8 fph,Weight transfer looking good,with good trend of milling off. 1.4 bpm,3811 is ctp,3831 bhp,2k wob 20:45 22:45 2.00 8,446 8,448 PROD1 WHPST MILL P OB milling 8446.28ft. milling 1 fph. 2.2k WOB.8448.2ft TD first WS milling run with BOT. 22:45 23:30 0.75 8,448 8,440 PROD1 WHPST MILL P Performed 3 reaming passes at 1fph. Looks clean. 23:30 00:00 0.50 8,440 7,022 PROD1 WHPST TRIP P POOH 01/24/2013 Finish milling dual string window exit. POOH and Undeploy milling BHA#3 00:00 02:00 2.00 7,022 0 PROD1 WHPST TRIP P Continue POOH with EDC open 02:00 02:15 0.25 0 0 PROD1 WHPST SFTY P PJSM-for UD BHI tools.Check well for flow. No flow unstab INJH. 02:15 03:45 1.50 0 0 PROD1 WHPST PULD P UD BHI tools, gauged mills both 2.79OD no-go. M/U weatherford motor to BHI tools,stab INJH onto stump and test tools. 03:45 06:00 2.25 0 8,050 PROD1 WHPST TRIP P RIH w/second milling BHA with fixed 2°bend motor and fat radius mill. 06:00 06:15 0.25 8,050 8,050 PROD1 WHPST DLOG P Tie in depth+3'correction 06:15 06:45 0.50 8,050 8,450 PROD1 WHPST DLOG P RIH dry tag 8450'. PU online with pumps. 1.4 bpm,3819 ctp off bottom. Page 2 of 15 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 06:45 11:15 4.50 8,449 8,452 PROD1 WHPST MILL P Start time milling @ 8448.8'following time schedule in program.Good amount of metal and cement across shakers. 11:15 13:15 2.00 8,452 8,454 PROD1 WHPST MILL P Abrupt decrease in WOB. 8451.8- BOW.Cont. milling 1 fph 13:15 15:00 1.75 8,454 8,457 PROD1 WHPST MILL P Increase ROP to 2 fph. 1.44bpm, 4065 ctp,4015bhp, 100 whp, 15:00 16:30 1.50 8,457 8,467 PROD1 WHPST DRLG P Drill ahead 1.4 bpm,4197 ctp,4031 bhp, 17k ctw, 111whp.30-40% formation in returns. 16:30 18:00 1.50 8,467 8,767 PROD1 WHPST DRLG P PU backreaming window HS,30 LOHS and ROHS OOH, HS on all down passes @ 1 fpm. 18:00 20:30 2.50 8,767 0 PROD1 WHPST TRIP P POOH with milling BHA#3 20:30 20:45 0.25 0 0 PROD1 WHPST SFTY P PJSM-for undeploying and L/D Milling BHA#3 weathford motor 20:45 22:15 1.50 0 0 PROD1 WHPST PULD P Start Undeploying BHA.Tools OOH. Mill gauged at 2.79 no-go,2.80 go. 22:15 2315 1.00 0 0 PROD1 DRILL PULD P M/U Build BHA,Stab on PDL P/T. Leak on quick test sub. 23:15 23:30 0.25 0 0 PROD1 DRILL SFTY P Pre-Spud with crew on tour. 23:30 00:00 0.50 0 0 PROD1 DRILL PULD P Inspect and change out O-ring on quick test sub 01/25/2013 POOH with second dual string milling BHA. M/U and RIH with build section BHA.Tagged at 8452ft bottom of window and couldn't get oast. POOH to swap BHA to a crayola mill. RIH and dressed window exit area. 00:00 00:15 0.25 0 0 PROD1 DRILL PULD P PJSM-Change out BHI checks in Upper Quick Connect. 00:15 01:15 1.00 0 0 PROD1 DRILL SVRG P PJSM-Stab INJH and P/T new o-ring 250psi low and 4K high.Good Test. Rig back INJH and stab PDL's. 01:15 02:30 1.25 0 0 PROD1 DRILL PULD P PJSM-deploy build BHA#4 02:30 04:45 2.25 0 8,055 PROD1 DRILL TRIP P Trip in hole with build BHA#4 with 1.8°bend motor/3.25"bi-center bit. 04:45 05:00 0.25 8,055 8,081 PROD1 DRILL DLOG P Tie into K1 marker correction of+1ft, PUW31k 05:00 05:30 0.50 8,081 8,452 PROD1 DRILL TRIP P Continue in hole to bottom 05:30 06:30 1.00 8,452 8,452 PROD1 DRILL DRLG T Tao 8452'. HS toolface.Clean PU. 33K. Attempt to RIH thru window,5 fpm-35 fpm HS toolface. No luck. Orient 10,20,30 LOHS, 10-25 fpm, No Luck. Orient 15,30 ROHS, 10-20 fpm, No luck. Hard tag everytime 8452',correlates to Bottom of Window 06:30 08:30 2.00 8,452 0 PROD1 DRILL TRIP T Open EDC, POOH 08:30 08:45 0.25 0 0 PROD1 DRILL SFTY T At surface, PJSM 08.45 10:15 1.50 0 0 PROD1 DRILL PULD T Undeploy BHA 3 10:15 11:45 1.50 0 0 PROD1 DRILL PULD T Deploy BHA 4 11:45 13:45 2.00 72 8,056 PROD1 DRILL TRIP T RIH 13:45 14:00 0.25 8,056 8,056 PROD1 DRILL DLOG T Tie in depth to K1. +2 5'correction Page 3 of 15 • Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 14:00 14:30 0.50 8,056 8,450 PROD1 DRILL TRIP T RIH to dress window.wt chk 33K PUW 14:30 14:45 0.25 8,450 8,450 PROD1 DRILL REAM T Dry tag 8451.5'. PU online with pumps, 1.4 bpm, 3780 ctp, RIH .5 fpm,stopping CT movement when seeing motorwork. 14:45 15:15 0.50 8,442 8,450 PROD1 DRILL REAM T Stall 8450.6', @.5 fpm. PU 35k puw. RBIH.5 fpm.stopping CT movement with motorwork. 15:15 15:45 0.50 8,450 8,450 PROD1 DRILL REAM T Stall 8450.94' @.5 fpm PU 33k puw. RBIH.5 fpm.slow down to.1 fpm @ 8450.8'. 15:45 18:45 3.00 8,450 8,452 PROD1 DRILL REAM T Stall 8450.98'.1 fpm, PU 35k till weight breaks over stop CT.Online with pumps RIH.5 fpm down 8450.4', slow down to.1 fpm.Stop CT 8450.93'for 7 minutes. RIH .05'to 8450.98'get motorwork,milled off nicely.Sit 6 minutes. RIH .05 every 6 minutes getting good motorwork, milling off. Cont.time schedule. 18:45 20:15 1.50 8,452 8,454 PROD1 DRILL REAM T 8452 1ft increase speed to 1 fph with no change in parameters. 20:15 20:30 0.25 8,454 8,454 PROD1 DRILL REAM T 8453.5ft Notice practically no motor work. Increase ROP to 2 fph. 20:30 20:45 0.25 8,454 8,455 PROD1 DRILL REAM T 8454ft Increase ROP to 5 fph 20:45 21:00 0.25 8,455 8,440 PROD1 DRILL REAM T 8455ft-PU and Back ream window area at 60 fph 0°(High Side)PUW 31k. Seen motor work and little over pull at 8450ft. 21:00 21:21 0.35 8,440 8,451 PROD1 DRILL REAM T 8451ft-0°Ream in hole down to 8449ft time mill down at 3 fph past 8450ft to 8451ft 21:21 22:15 0.90 8,451 8,455 PROD1 DRILL REAM T Continue reaming down at 60fph. 22:15 00:00 1.75 8,455 8,453 PROD1 DRILL REAM T Perform down passes at 0°at 1 FPM Up pass 45°R clean Up pass 45°L 85 psi-Motor work Up pass 90°L 120 psi-Motor work 01/26/2013 Finished deploying build BHA. RIH Tied into the K1 marker w/+1.5ft.TD build section at 8515ft. POOH and undeploy build BHA. Deploy, RIH,and started drilling lateral section. 00:00 00:15 0.25 8,453 8,439 PROD1 DRILL REAM T Continue back reaming 90°L at 1 FPH, PUW 31k 00:15 00:30 0.25 8,439 8,455 PROD1 DRILL REAM T Ream down 0°at 1 FPH 00:30 00:45 0.25 8,455 8,440 PROD1 DRILL REAM T Back ream 90° R at 1 FPM, PUW 32k 00:45 01:00 0.25 8,440 8,455 PROD1 DRILL REAM T Ream down 0°at 1 FPH 01:00 01:15 0.25 8,455 8,425 PROD1 DRILL REAM T Back ream 180°at 1 FPM, PUW 31k 01:15 01:30 0.25 8,425 8,456 PROD1 DRILL REAM T Dry drift window 01:30 01:45 0.25 8,456 8,440 PROD1 DRILL REAM T Tagged up at 8456ft, Picked up to 8440ft PUW 33k 01:45 02:00 0.25 8,440 8,457 PROD1 DRILL REAM T RIH pumping full rate,Tag up at 8457ft. PUW 02:00 02:15 0.25 8,457 8,440 PROD1 DRILL REAM T Ream up at 0°at 1 FPM Page 4 of 15 Time Logs Date From To Dur S. Deoth E. Depth Phase Code Subcode T Comment 02:15 04:15 2.00 8,440 0 PROD1 DRILL REAM T Open EDC, POOH 04:15 04:30 0.25 0 0 PROD1 DRILL SFTY T PJSM-undeploy and L/D window dressing BHA#5 04:30 06:00 1.50 0 0 PROD1 DRILL PULD T Undeploy window dressing BHA#5. Mill gauge-2.79 No-Go,2.80-Go 06:00 07:30 1.50 0 0 PROD1 DRILL SVRG P Service injector head&reel. Secure shims on reel hubs,torq saddle bolts,check inner reel iron. 07:30 07:45 0.25 0 0 PROD1 DRILL SFTY T PJSM 07:45 08:45 1.00 0 0 PROD1 DRILL PULD T Deploy BHA 6. (1.8 ako, 3.25 Bi-Center) 08:45 10:45 2.00 62 8,050 PROD1 DRILL TRIP T RIH 10:45 11:00 0.25 8,050 8,050 PROD1 DRILL DLOG T Tie in depth depth+2.5'correction. 11:00 11:30 0.50 8,050 8,467 PROD1 DRILL TRIP T Log CCL,8100-8400'. Log looks good compared to CCL logged on WS run. RIH to drill 11:30 12:30 1.00 8,467 8,515 PROD1 DRILL DRLG P Drift thru window no problem.Cont RIH,small set down at 8457'.Online with pumps 1.4 bpm, 18k ctw,77 whp,4027 bhp. Drilling ahead @ 9467'. 12:30 15:00 2.50 8,515 0 PROD1 DRILL TRIP P Land build section,8515'. Higher than anticipated DLS. POOH. Slight Overpull at 9457' 15:00 16:30 1.50 0 0 PROD1 DRILL PULD P Undeploy BHA 16:30 18:00 1.50 0 0 PROD1 DRILL PULD P Deploy BHA#7 18:00 18:30 0.50 0 0 PROD1 DRILL SVRG P Service reel stand, reinstall shimes on reel hub. 18:30 20:00 1.50 0 0 PROD1 DRILL PULD P Continue deploying BHA#7 20:00 22:00 2.00 0 8,055 PROD1 DRILL TRIP P RIH-with lateral BHA#7 22:00 22:15 0.25 8,055 8,072 PROD1 DRILL DLOG P Tie into K1 Marker correction of+1 ft. Close EDC 22:15 22:30 0.25 8,072 8,515 PROD1 DRILL TRIP P Continue in hole 22:30 22:45 0.25 8,515 8,549 PROD1 DRILL DRLG P OBD- 1.37 bpm at 3741 psi. BHP 4032 with open choke. WOB 1.6k ROP 70fph WHP 0 IA 39,OA 284 22:45 23:00 0.25 8,549 8,552 PROD1 DRILL DRLG P 8552ft OBD-1.4bpm at 3930psi. BHP 4062 full returns after losing partical returns BHP 3886 WOB 2.3k ROP 39 fph IA 161, OA 283 23:00 23:15 0.25 8,552 8,497 PROD1 DRILL WPRT P 8552ft-Lost returns wiper up hole PUW 32k. Lost 5.0 bbls to formation In rate 1.36 bpm Out rate.36 bpm 23:15 23:30 0.25 8,497 8,552 PROD1 DRILL WPRT P Wiper back in hole In rate 1.36 bpm Out rate 1.29 bpm Losses 6.0 bph Page 5 of 15 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 8,552 8,590 PROD1 DRILL DRLG P OBD -1.36bpm at 3764psi. BHP 4063,WHP 93 WOB 2.3k, ROP 42 fph IA 168,OA 283 01/27/2013 Drilled Lateral Section as per plan. 00:00 01:30 1.50 8,590 8,665 PROD1 DRILL DRLG P OBD-1.34bpm at 4130psi. BHP 4067,WHP 75 WOB 2.4k, ROP 31fph IA 220,OA 300 Losses 3.0bph 01:30 02:00 0.50 8,665 8,463 PROD1 DRILL WPRT P 8665ft-Wiper up hole to window 8463ft. PUW 32k 02:00 02:15 0.25 8,463 8,665 PROD1 DRILL WPRT P 8463ft-Wiper back in hole. RIW 18k 02:15 05:00 2.75 8,665 8,815 PROD1 DRILL DRLG P BOBD-1.36bpm at 3773psi. BHP 4032,WHP 0. Open choke WOB 1.5k, ROP 50 IA 285,OA 310 Losses 0 05:00 05:15 0.25 8,815 8,463 PROD1 DRILL WPRT P 8815ft-Wiper up hole to the bottom of the window 8463ft. PUW 33k. 05:15 05:30 0.25 8,463 8,815 PROD1 DRILL WPRT P 8463ft-Wiper back in hole RIW 19k 05:30 06:30 1.00 8,815 8,865 PROD1 DRILL DRLG P BOBD-1.4bpm at 3835psi. BHP 4160,WHP 0 WOB 1 5k, ROP 70fph IA 379,OA 314 06:30 08:30 2.00 8,865 8,935 PROD1 DRILL DRLG P Drilling ahead 1.4bpm,4250-4300 ctp,4066 bhp, 1-1.5k wob. 08:30 09:30 1.00 8,935 8,965 PROD1 DRILL DRLG P Cont drilling,swap out drilling mud. Pressures still abnormally high after mud swap. Mud temp 58 deg on in MM,65 out MM.All surface equipment checks out to be good. Cont.to monitor pressures. Mud check wt 9.6. LSRV 44k,when heated up to 100 deg for bench test LSRV 25k. Place steam line in pits to warm up mud. 09:30 10:00 0.50 8,965 8,470 PROD1 DRILL WPRT P Wiper trip to window 33K puw 10:00 10:15 0.25 8,470 8,470 PROD1 DRILL DLOG P Tie in depth to RA marker-.5' correction 10:15 10:30 0.25 8,470 8,965 PROD1 DRILL WPRT P RBIH 10:30 14:15 3.75 8,965 9,115 PROD1 DRILL DRLG P Drill ahead 1.35 bpm,4200 ctp, 144 whp,4106 bhp 14:15 14:45 0.50 9,115 8,495 PROD1 DRILL WPRT P Wiper trip to window,34k puw 14:45 15:15 0.50 8,495 9,115 PROD1 DRILL WPRT P RBIH 15:15 17:15 2.00 !9,115 9,265 PROD1 DRILL DRLG P Drill ahead 1.35,4100, 138 whp, 4113 bhp, 14k ctw 17:15 18:00 0.75 9,265 8,525 PROD1 DRILL WPRT P 9265ft-Wiper trip up hole 8525ft 18:00 18:30 0.50 8,525 9,265 PROD1 DRILL WPRT P 8525ft-Wiper back in hole. RIW 19k Page 6 of 15 Time Logs Date From To Dur S.Death E. Depth Phase Code Subcode T Comment 18:30 21:00 2.50 9,265 9,415 PROD1 DRILL DRLG P BOBD-1.37bpm at 3750psi. BHP 4123,WHP 169 WOB 2k, ROP 113 IA 415,OA 324 21:00 21:30 0.50 9,415 8,463 PROD1 DRILL WPRT P 9415ft-Wiper trip up hole 8463ft, PUW 31k 21:30 21:45 0.25 8,468 8,472 PROD1 DRILL DLOG P Tie in correction of+1ft. 21:45 22:00 0.25 8,472 9,415 PROD1 DRILL WPRT P 8472ft-Continue wiper trip to bottom RIW 18k 22:00 00:00 2.00 9,415 9,538 PROD1 DRILL DRLG P 9415ft-BOBD 1.38bpm at 3750psi. BHP 4114,WHP 173 WOB 1.3k, ROP 81fph Surface Weight 17k IA 486,OA 332 01/28/2013 Drilled lateral Section as per plan 00:00 00:30 0.50 9,538 9,565 PROD1 DRILL DRLG P 9538ft-OBD 1.38bpm at 3754psi. BHP 4150,WHP 202 WOB 2.25k, ROP 50fph Coil Surface Weight 15k IA 535, OA 332 00:30 01:00 0.50 9,565 8,517 PROD1 DRILL WPRT P 9565ft-Wiper up hole 8517ft. PUW 32k 01:00 01:30 0.50 8,517 9,565 PROD1 DRILL WPRT P 8517ft-Wiper back in hole. RIW 19 01:30 04:45 3.25 9,565 9,715 PROD1 DRILL DRLG P 9565ft-BOBD 1.38bpm at 3774psi. BHP 4160,WHP 211 WOB 1.8k, ROP 43 Coil Surface Weight 17k IA 557, OA 343 04:45 05:15 0.50 9,715 8,525 PROD1 DRILL WPRT P 9715ft- Wiper up hole PUW 32k 05:15 05:45 0.50 8,525 9,715 PROD1 DRILL WPRT P 8525ft-Wiper back in hole RIW 18k 05:45 08:30 2.75 9,715 9,865 PROD1 DRILL DRLG P Drill Ahead 1.4 bpm,4000 ctp,244 whp,4180 bhp 08:30 09:15 0.75 9,865 8,467 PROD1 DRILL WPRT P Wiper trip back to window 35k puw 09.15 09:30 0.25 8,467 8,467 PROD1 DRILL DLOG P Tie in depth to RA marker,+1' correction 09:30 10:15 0.75 8,467 9,865 PROD1 DRILL WPRT P RBIH 10:15 12:45 2.50 9,865 10,015 PROD1 DRILL DRLG P Drill ahead 1.4 bpm,4130 ctp,250 whp,4200 12:45 13:30 0.75 10,015 9,500 PROD1 DRILL WPRT P 500'wiper trip,chase 5 x 5 low/high sweeps OOH. 33k puw.20 fpm OOH,40 fpm in. 13:30 13:45 0.25 9,500 10,015 PROD1 DRILL WPRT P RBIH, Large increase in cuttings at bottoms up sweeps. 13:45 15:15 1.50 10,015 10,165 PROD1 DRILL DRLG P Drill ahead 1.4 bpm,4100 ctp,231 whp,4220 bhp 15:15 15:45 0.50 10,165 9,700 PROD1 DRILL WPRT P 450'wiper, Increase pump rate 1.5 bpm,chase 5 x 5 low/high sweeps OOH. 15:45 16:15 0.50 9,700 10,165 PROD1 DRILL WPRT P RBIH. @ 10000'Pick back up 200' performing jog for bottoms up. Increase of cuttings on bottoms up with sweeps. Page 7 of 15 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 16:15 18:15 2.00 10,165 10,315 PROD1 DRILL DRLG P Drill Ahead 1.4 bpm,4000ctp, 200whp,4210bhp, 17k ctw 18:15 19:15 1.00 10,315 8,467 PROD1 DRILL WPRT P Wiper trip back to window 34k puw. 35fpm 19:15 19:21 0.10 8,467 8,467 PROD1 DRILL DLOG P Tie in depth to RA marker+.5' correction 19:21 20:06 0.75 8,467 10,315 PROD1 DRILL WPRT P RBIH-40fpm 20:06 23:00 2.90 10,315 10,465 PROD1 DRILL DRLG P Drill Ahead 1.35 bpm,4093 ctp, 221whp,4247 bhp, 14k ctw 23:00 23:30 0.50 10,465 9,853 PROD1 DRILL WPRT P 10465ft-Wiper up to 9853ft. PUW 34k 23:30 23:45 0.25 9,853 10,465 PROD1 DRILL WPRT P 9853ft-Wiper back in hole RIW 16k 23:45 00:00 0.25 10,465 10,502 PROD1 DRILL DRLG P 10465ft-BOBD 1.39bpm at 3827psi BHP 4739,WHP 221 WOB 1.3k, ROP 120fph IA 639,OA 393 01/29/2013 fZrilled"A"lateral to TD 11135,Condition hole for liner run 00:00 00:15 0.25 10,502 10,525 PROD1 DRILL DRLG P 10502ft-OBD 1.39bpm at 4051psi. FS 3827 BHP 4243,WHP 222 WOB 1.7k, ROP 81 Surface weight 15k IA 637,OA 391 00:15 00:30 0.25 10,525 10,425 PROD1 DRILL WPRT P 10525ft-BHA Wiper lost motor work. PUW 45k 00:30 00:45 0.25 10,425 10,525 PROD1 DRILL WPRT P 10425ft-Wiper back in hole. RIW 17k 00:45 01:30 0.75 10,525 10,615 PROD1 DRILL DRLG P 10525ft-BOBD 1.39bpm at 3827psi BHP 4243,WHP 222 WOB 1.4, ROP 88 Surface weight 14k IA 636, OA 392 01:30 02:00 0.50 10,615 9,516 PROD1 DRILL WPRT P 10615ft-Wiper up to 9516ft. PUW 32k 02:00 02:30 0.50 9,516 10,615 PROD1 DRILL WPRT P 9516ft-Wiper back in hole. RIW 17k 02:30 04:00 1.50 10,615 10,765 PROD1 DRILL DRLG P 10615ft-BOBD 1.37 bpm at 3739psi. BHP 4225,WHP 197 WOB 1.5, ROP 80fph IA 656,OA 391 04:00 05:15 1.25 10,765 8,470 PROD1 DRILL WPRT P 10765ft-Wiper to the window for a tie in. PUW 32k 05:15 05:30 0.25 8,470 8,482 PROD1 DRILL DLOG P 8470ft-Tie into RA marker no correction 05:30 06:30 1.00 8,482 10,765 PROD1 DRILL WPRT P 8482ft-Wiper back in hole. RIW 18k 06:30 09:00 2.50 10,765 10,915 PROD1 DRILL DRLG P 10765ft-BOBD 1.35bpm at 3850psi BHP 4765,WHP 178 WOB 2k, ROP 107 Surface Coil Weight 15k IA 681,OA 401 09:00 10:00 1.00 10,915 8,700 PROD1 DRILL WPRT P 10915ft-Wiper up hole PUW 10.00 11:00 1.00 8,700 10,915 PROD1 DRILL WPRT P 8700ft-wiper back in hole. RIW 17k Page 8 of 15 • Time Logs J I Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 13:00 2.00 10,915 11,065 PROD1 DRILL DRLG P 10915ft-BOBD 1.39bpm at 3840psi. BHP 4758,WHP 162 WOB 1.7k, ROP 106 Surface Coil Weight 14k IA 324,OA 420 13:00 13:45 0.75 11,065 9,500 PROD1 DRILL WPRT P 11065ft-wiper up hole. PUW 32k 13:45 14:30 0.75 9,500 11,065 PROD1 DRILL WPRT P 9500ft-wiper back in hole RIW 16k 14:30 17:00 2.50 11,065 11,133 PROD1 DRILL DRLG P 11065ft-BOBD 1.33bpm at 3900psi. BHP 4339,WHP 173 WOB 1.4k, ROP 62fph Surface Coil Weight 15k IA 325,OA 423 17:00 17:30 0.50 11,133 11,330 PROD1 DRILL WPRT P 11133ft-Town Called TD. PUH and start 10x10 sweep down coil 17:30 18:48 1.30 11,330 8,470 PROD1 DRILL WPRT P 10&10 sweeps out of coil,Chase to window, PUW=32K 18:48 18:54 0.10 8,470 8,499 PROD1 DRILL DLOG P Log RA Marker for+3.5'correction 18:54 20:00 1.10 8,499 11,135 PROD1 DRILL WPRT P Continue wiper to bottom,Corrected TD@11135' 20:00 23:36 3.60 11,135 75 PROD1 DRILL TRIP P 11135,Trip out laying in 9.7 PPG Beaded liner running pill followed by 9.7 PPG drilling fluid. Paint EOP flags @ 9500', and 6800' 23:36 00:00 0.40 75 75 PROD1 DRILL PULD P At surface, PJSM,S/I SSSV and flow check well, Pass No flo test, Unstab injector and park.Warm up top drive 01/30/2013 Function test BOPE, Run A lateral liner 11135 to 9075 00:00 01:30 1.50 75 0 PROD1 DRILL PULD P Lay down BHA after top drive thawed out 01:30 02:00 0.50 0 0 PROD1 DRILL BOPE P Function test BOPE 02:00 02:30 0.50 0 0 COMPZ CASING PULD P Rig up floor to run liner section#1 02:30 04:12 1.70 0 1,431 COMPZ CASING PUTB P PSJM,M/U BHA#8"A"lawer lower liner run, Non ported bullnose,43 Jts 2 3/8 slotted liner, Shorty deployment sleeve 04:12 04:48 0.60 1,431 1,476 COMPZ CASING PULD P M/U Coil track to liner, M/U to coil and surface test,strip injector on well 04:48 06:45 1.95 1,476 8,231 COMPZ CASING TRIP P RIH with A Lateral liner lower section 06:45 07:00 0.25 8,231 8,231 COMPZ CASING DLOG P Correct to the upper flag a correction of+6.6ft. 07:00 07:30 0.50 8,231 9,465 COMPZ CASING TRIP P 8231ft-Continue in hole. 07:30 0745 0.25 9,465 9,500 COMPZ CASING DLOG P Tie into K1 marker correction of+1ft. 07:45 08:30 0.75 9,500 11,135 COMPZ CASING TRIP P Continue in hole. 08:30 08:45 0.25 11,135 9,691 COMPZ CASING TRIP P 11135ft-Liner on bottom Weight check 35.5k RBIH 3k down, online with pump 4000psi. PU 30k PUW, Liner released on bottom. Remove liner length from BHA TOL 9698 36' Page 9 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:45 09:00 0.25 9,691 7,744 COMPZ CASING TRIP P 9691ft-POOH 09:00 09:15 0.25 7,744 7,744 COMPZ CASING TRIP P Paint EOP 7700ft Yellow 09:15 11:45 2.50 7,744 1,800 COMPZ CASING TRIP P POOH 11:45 12:00 0.25 1,800 1,780 COMPZ CASING TRIP P 1795ft-Jet SSSV twice at 1.4bpm. 12:00 12:15 0.25 1,780 0 COMPZ CASING TRIP P 1780ft-Continue OOH 12:15 12:30 0.25 0 0 COMPZ CASING TRIP P Close SSSV,Good flow check, PJSM 12:30 1300 0.50 0 0 COMPZ CASING PULD P Unstab Injector Head.and L/D liner running tools 13:00 1330 0.50 0 0 COMPZ CASING SFTY P PJSM-Running Liner, Prep Rig floor 13:30 15:30 2.00 0 0 COMPZ CASING PULD P Start M/U upper liner assy. 15:30 18:36 3.10 0 8,388 COMPZ CASING TRIP P RIH-Upper liner section for lateral A Anchored Billet 18 jts of 2 3/8"slotted liner 18:36 18:42 0.10 8,388 8,388 COMPZ CASING DLOG P Tie into EOP flag for no correction, PUW=32K 18:42 19:00 0.30 8,388 8,680 COMPZ CASING TRIP P Continue in well 19:00 19:12 0.20 8,680 8,710 COMPZ CASING DLOG P Log K1 marker for no correction 19:12 19:36 0.40 8,710 9,702 COMPZ CASING TRIP P RIH with liner 19:36 19:48 0.20 9,702 9,702 COMPZ CASING TRIP P Set down @ 9702', PUW=34K,Set back down,oriented to 170 RHS and release from liner. See setting tool shift @ 3900 PSI, PUW=32K 19:48 22:00 2.20 9,702 64 COMPZ CASING TRIP P trip out after setting liner 22:00 23:30 1.50 64 0 COMPZ CASING PULD P At surface, PSJM,Space out and PUD BHA#9, Liner running tools 23:30 00:00 0.50 0 0 PROD2 STK PULD P PD BHA CO Drill by BHA W/1.8° Motor and re run 3.25"bi center 01/31/2013 Drill off liner top billet @ 9075,.TD Build turn @ 9450. C/O BHA for lateral section Drill to 9595 00:00 00:36 0.60 0 72 PROD2 STK PULD P Continue PD BHA#10, M/U to coil and surface test tool,Tag up and set counters 00:36 02:30 1.90 72 8,060 PROD2 STK TRIP P RIH to drill AL1 turn section, EDC open 02:30 02:42 0.20 8,060 8,075 PROD2 STK DLOG P Log tie into K1 for+.5', PUW=29K, Shut EDC 02:42 03:06 0.40 8,075 9,076 PROD2 STK TRIP P RIH to drill off Billet, clean pass through window,clean trip to LTB. Dry tag @ 9075.5, PUW=33K 03:06 03:36 0.50 9,076 9,075 PROD2 STK KOST P 9075, 1.35 BPM @ 3800PSI FS, BHP=4115,Start milling procedure, stall at 9075.38, PUW=33K, TF=140° 03:36 04:24 0.80 9,075 9,076 PROD2 STK KOST P 1.35 BPM @ 3880 PSI FS, RIW=19K, BHP=4119,see motor work @ 9075.2 04:24 04:54 0.50 9,076 9,077 PROD2 STK KOST P Go to 2 FPH Page 10 of 15 • Time Logs Date From To Dur S.Death E.Death Phase Code Subcode T Comment 04:54 05:30 0.61 9,077 9,100 PROD2 DRILL DRLG P Goto Drilling, 1.35 BPM @ 3880 PSI FS, BHP=4115 05:30 05:45 0.25 9,100 9,000 PROD2 DRILL WPRT P Dry drift KOP,Clean 05:45 06:00 0.25 9,000 9,100 PROD2 DRILL WPRT P Clean on down pass 06:00 07:00 1.00 9,100 9,225 PROD2 DRILL DRLG P OBD-1.35bpm at 3850psi. BHP 4616,WHP 29 WOB 1k, ROP 107fph Coil Surface Weight 18k IA 0,OA 37 07:00 07:15 0.25 9,225 8,910 PROD2 DRILL WPRT P 9225ft-Wiper to window, PUW 33K, clean passing billet area. 07:15 07:30 0.25 8,910 8,460 PROD2 DRILL WPRT P Packing off,work pipe and clean up hole. Pump 5x5 sweep 07:30 08:00 0.50 8,460 9,225 PROD2 DRILL WPRT P Wiper back in hole. RIW 18k 08:00 10:00 2.00 9,225 9,377 PROD2 DRILL DRLG P 9225ft-OBD 1.35bpm at 3725psi. BHP 4120,WHP 50 WOB 1.9k, ROP 80fph IA 10,OA 384 10:00 10:30 0.50 9,377 9,129 PROD2 DRILL WPRT P 9377ft-Wiper up hole to bottom of billet 9129ft. PUW 33k 10:30 10:45 0.25 9,129 9,377 PROD2 DRILL WPRT P 9129ft-Wiper back in hole. RIW 14k 10:45 11:30 0.75 9,377 9,450 PROD2 DRILL DRLG P 9377ft-BOBD 1.35bpm at 3750psi BHP 4168,WHP 98 WOB 1.9k, ROP 88 Coil Surface Weight 16k IA 14,OA 382 11:30 12:00 0.50 9,450 8,400 PROD2 DRILL TRIP P 9450ft-TD Build,pump 5x5 sweep, PUH chasing sweep to window. Billet area clean 12:00 14:30 2.50 8,400 0 PROD2 DRILL TRIP P POOH 14:30 14:45 0.25 0 0 PROD2 DRILL SFTY P OOH, PJSM for UD build BHA 14:45 15:45 1.00 0 0 PROD2 DRILL PULD P Undeploy AL1 build BHA#10 15:45 16:15 0.50 0 0 PROD2 DRILL SFTY P PJSM-L/D-M/U 16:15 17:27 1.20 0 72 PROD2 DRILL PULD P Deploy Lateral BHA#11,AL1 ;ateral section with.8°Motor and new 3.25 Bo Center bit,Surface test tool 17:27 19:21 1.90 72 8,065 PROD2 DRILL TRIP P RIH, EDC open 19:21 19:33 0.20 8,065 8,090 PROD2 DRILL DLOG P Log into K1 for+2', PUW=32K, Shut _ EDC 19:33 20:09 0.60 8,090 9,450 PROD2 DRILL TRIP P Continue trip in well,Clean pass through window,clean trip to bottom 20:09 23:45 3.60 9,450 9,595 PROD2 DRILL DRLG P Drill Ahead, 1.38 BPM @ 3970 PSI FS, RIW=17.6, BHP=4150 23:45 23:59 0.24 9,595 9,000 PROD2 DRILL WPRT P Wiper to window, PUW=32K 02/01/2013 Drilled from 9595 to 10080' 00:00 00:48 0.80 9,595 9,595 PROD2 DRILL WPRT P Continue wiper to window from 9595 00:48 02:42 1.90 9,595 9,745 PROD2 DRILL DRLG P 9595', Drill Ahead, 1.4 BPM @ 3820 PSI FS, RIW=18.4K, BHP=4080, Clean trip our and in Page 11 of 15 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:42 03:48 1.10 9,745 9,745 PROD2 DRILL WPRT P 9745,Wiper to billet, Never saw well unload,continue up to 8530,Saw 8755 on way back in not full setdown but good speed bump 03:48 07:30 3.70 9,745 9,787 PROD2 DRILL DRLG P 9745', Drill ahead, 1.36 BPM @ 3830 PSI FS, BHP=4190 07:30 07:45 0.25 9,787 9,680 PROD2 DRILL WPRT P PUH,Call town Geo,try and get plan forward looks like we faulted into the unknown. 07:45 08:00 0.25 9,680 9,787 PROD2 DRILL WPRT P Wiper back in hole,Call town GEO, Town wants to drop to 84°inc. 08:00 09:00 1.00 9,787 9,800 PROD2 DRILL DRLG P 9787ft-BOBD 1.36bpm at 3840psi. BHP 4197,WHP 152 WOB 1.8k, ROP 7 fph Coil Surface weight 15k IA 215,OA 419 09:00 09:15 0.25 9,800 9,685 PROD2 DRILL WPRT P 9800ft-PUH and Pump 5x5 sweep 09:15 09:30 0.25 9,685 9,800 PROD2 DRILL WPRT P 9685ft-RBIH RIW 18k 09:30 13:30 4.00 9,800 9,850 PROD2 DRILL DRLG P BOB trying to drill ahead 13:30 14:30 1.00 9,850 9,895 PROD2 DRILL DRLG P 9850ft-Drilling break BHP 4214,WHP 109 WOB 1.95k, ROP 65fph Coil Surface Weight 14k IA 262,OA 424 14:30 15:00 0.50 9,895 8,470 PROD2 DRILL WPRT P 9895ft-Wiper to the window. PUW 33k 15:00 15:15 0.25 8,470 8,483 PROD2 DRILL DLOG P 8470ft-Tie into RA marker correction of+3ft. 15:15 15:45 0.50 8,483 9,895 PROD2 DRILL WPRT P 8483ft-Wiper back in hole. RIW 18k 15:45 19:09 3.40 9,895 10,004 PROD2 DRILL DRLG P 9895ft-BOBD 1.38bpm at 3845psi BHP 4199,WHP 107 WOB 1.5k, ROP 85fph 15k Coil Surface Weight IA 243,OA 421 19:09 19:21 0.20 10,004 10,004 PROD2 DRILL WPRT P Mini BHA wiper PUW=37K,Clear BHA, not much motor work, 1921 22:21 3.00 10,004 10,045 PROD2 DRILL DRLG P Drill ahead, 1.39 BPM @ 3800 PSI FS, BHP=4190 22:21 22:45 0.40 10,045 10,045 PROD2 DRILL WPRT P Wiper trip to 8550,Well done unloading there, PUW=34K 22:45 00:00 1.25 10,045 10,080 PROD2 DRILL DRLG P 1.37BPM @ 3890 PSI FS, BHP=4210 02/02/2013 Drilled from 10080 to 10756, Performed Mud swap 00:00 00:18 0.30 10,080 10,089 PROD2 DRILL DRLG P Drilling ahead, @ 10085 pumped 5X5 sweeps,Geo reports no sand in samples 00:18 00:24 0.10 10,089 10,089 PROD2 DRILL WPRT P BHA Wiper,stacking, PUW=32K 00:24 03:18 2.90 10,089 10,195 PROD2 DRILL DRLG P 10089, Drill Ahead, 1.38 BPM @ 3850 PSI FS, BHP=4226 03:18 04:36 1.30 10,195 10,195 PROD2 DRILL WPRT P Wiper trip, PUW=35K,well unloaded 9400'Speed bump with motorwork @ 9800 on way in 04:36 07:30 2.90 10,195 10,305 PROD2 DRILL DRLG P 10195', Drill Ahead, 1.37 BPM @ 3850 PSI FS, BHP=4217,WHP=20 Page 12 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 07:45 0.25 10,307 10,177 PROD2 DRILL WPRT P PUH-BHA wiper, PU little sticky, losing weight transfer, high circ pressure,start new mud down coil.PUW 41k 07:45 08:00 0.25 10,177 10,307 PROD2 DRILL WPRT P 10177ft-Wiper back in hole. 08:00 08:15 0.25 10,307 10,345 PROD2 DRILL DRLG P Drill Ahead 1.31 bpm at 4020psi. New Mud 10310ft BHP 4710,WHP 49 WOB 1.3k, ROP 50fph 15k Coil Surface weight IA 280,OA 444 08:15 09:00 0.75 10,345 8,470 PROD2 DRILL WPRT P 10345ft-Tie in wiper to the window PUW 32k 09:00 09:15 0.25 8,470 8,500 PROD2 DRILL DLOG P 8470ft-Tie into the RA marker correction of 0. 09:15 10:15 1.00 8,500 10,345 PROD2 DRILL WPRT P Continue wiper in hole. RIW 18k 10:15 13:30 3.25 10,345 10,495 PROD2 DRILL DRLG P 10345ft-OBD 1.32bpm at 4000psi BHP 4230,WHP 50 WOB 1.6k, ROP 15k Coil Surface Weight IA 214,OA 432 13:30 14:30 1.00 10,495 8,525 PROD2 DRILL WPRT P 10495ft-Wiper PUW 32k 14:30 15:30 1.00 8,525 10,495 PROD2 DRILL WPRT P 8525ft-Wiper back in hole RIW 18k 15:30 19:18 3.80 10,495 10,645 PROD2 DRILL DRLG P 10495ft-BOBD 1.33bpm at 3906psi. BHP 4258,WHP 54 WOB 1.7k, ROP 65fph 16k Coil Surface Weight IA 229,OA 434 19:18 21:18 2.00 10,645 10,645 PROD2 DRILL WPRT P Wiper to window, PUW=35K,Speed bump with slight motor work @ -9775-9800 while RIH 21:18 00:00 2.70 10,645 10,756 PROD2 DRILL DRLG P 10645, Drill Ahead, 1.38 BPM @ 3850 PSI FS, BHP=4275,WHP=60 02/03/2013 Drilled 10756 to TD @ 11152,Condition hole for liner 00:00 00:39 0.65 10,756 10,795 PROD2 DRILL DRLG P Drill ahead(cont) 00:39 02:00 1.35 10,795 8,470 PROD2 DRILL WPRT P Wiper trip to window with tie in, PUW=34.5K, BHP=4300 02:00 02:06 0.10 8,470 8,488 PROD2 DRILL DLOG P Log RA Marker for+1.5'correction 02:06 03:24 1.30 8,488 10,795 PROD2 DRILL WPRT P RBIH to drill 03:24 07:30 4.10 10,795 10,945 PROD2 DRILL DRLG P 10795, Drill ahead, 1.37 BPM @ 3980PSI FS, BHP=4300, RIW=15.6K,WHP=46 07:30 08:00 0.50 10,945 9,104 PROD2 DRILL WPRT P 10945ft-Wiper to the bottom of billet 08:00 09:00 1.00 9,104 10,945 PROD2 DRILL WPRT P 9104ft-Wiper back in hole. RIW 18k 09:00 14.00 5.00 10,945 11,045 PROD2 DRILL DRLG P 10945ft-BOBD 1.40bpm at 3950psi BHP 4251,WHP 0 WOB 2K, ROP 80fph 15k Surface Coil Weight IA 384,OA 45 14:00 14:15 0.25 11,045 10,500 PROD2 DRILL WPRT P 11045ft-Wiper trip to 10500ft PUW 32k Page 13 of 15 Time Logs Date From To Dur S. Death E.Death Phase Code Subcode T Comment 14:15 14:30 0.25 10,500 11,045 PROD2 DRILL WPRT P 10500ft-Wiper back in hole and try and drill. 14:30 17:15 2.75 11,045 11,078 PROD2 DRILL DRLG P 11045ft-BOBD 1.36bpm at 3961psi BHP 4343,WHP 44 WOB 1.8, ROP 18fph 11k Coil Surface Weight IA 385,OA 46 17:15 17:21 0.10 11,078 11,078 PROD2 DRILL WPRT P BHA Wiper, PUW=34K 17:21 18:51 1.50 11,078 11,088 PROD2 DRILL DRLG P 10078', Drill ahead, 1.38 BPM @ 3840 PSI FS, BHP=4350 18:51 20:03 1.20 11,088 11,150 PROD2 DRILL DRLG P 11088', Drilling break, ROP increase to 50-70 FPH from 6 FPH, Drill past wiper for gamma data,send sweeps down 20:03 21:39 1.60 11,150 8,470 PROD2 DRILL WPRT P 11150',Call TD,Wipe to window with tie in 21:39 21:45 0.10 8,470 8,490 PROD2 DRILL DLOG P Log RA marker for+1.7 ft 21:45 23:21 1.60 8,490 11,152 PROD2 DRILL WPRT P Wipe back to bottom.Corrected TD @ 11152 23:21 23:36 0.25 11,152 9,610 PROD2 DRILL TRIP P Trip out laying in beaded liner running pill 02/04/2013 Run AL1 Liner,TOL=8437, BOL=11152, Freeze Protect well to 2500' 00:00 03:00 3.00 9,610 75 PROD2 DRILL TRIP P Trip out of well, Paint EOP Ftags @ 9400 and 6700' 03:00 03:24 0.40 75 75 PROD2 DRILL SFTY P PJSM, Lay down BHA on dead well while flow checking well 03:24 04:12 0.80 75 0 PROD2 DRILL PULD P Lay down BHA#11 04:12 04:54 0.70 0 0 COMPZ CASING PULD P Prep floor for running liner 04:54 05:30 0.60 0 0 COMPZ CASING PUTB P PJSM, Pick up liner 05:30 08:00 2.50 0 0 COMPZ CASING PUTB P Start making up 45jts liner 08:00 08:15 0.25 0 0 COMPZ CASING PUTB P M/U BHI tools to liner BHA and test. 08:15 10:15 2.00 0 8,232 COMPZ CASING TRIP P RIH-with AL1 lower liner section Shorty Deployment Sleeve 45 jts of slotted liner non-ported bull nose 10:15 11:00 0.75 8,232 11,152 COMPZ CASING DLOG P 8232ft,Correct at flag+10.7'(EOP 6698.4)Tie into the K1 marker with no correction. 11:00 11:15 0.25 11,152 11,152 COMPZ CASING TRIP P Liner on bottom,weight check 39k, RBIH 3k down,online with pump. 4000psi. PUW 31k, liner released on bottom. Remove liner length from BHA.TOL 9650.98ft. 11:15 13:45 2.50 11,152 0 COMPZ CASING TRIP P POOH 13:45 14:00 0.25 0 0 COMPZ CASING SFTY P PJSM-L/D running tools. 14:00 14:15 0.25 0 0 COMPZ CASING PULD P L/D BHA tools 14:15 14:30 0.25 0 0 COMPZ CASING PULD P Prep floor for running liner 14:30 14:45 0.25 0 0 COMPZ CASING PULD P PJSM-M/U upper AL1 liner section. Page 14 of 15 • w, • Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 14:45 17:45 3.00 0 0 COMPZ CASING PUTB P P/U and M/U AL1 upper liner section. 17:45 18:30 0.75 0 1,257 COMPZ CASING PULD P M/U INJH to BHI tools and test 18:30 21:24 2.90 1,257 8,350 COMPZ CASING TRIP P RIH-Upper AL1 liner section. 27 jts of 2 3/8"slotted 10 jts of solild 511 21:24 21:48 0.40 8,350 9,260 COMPZ CASING TRIP P Tie into EOP flag for+6.8, PUW=34K, RIW=17.5 21:48 21:54 0.10 9,260 9,267 COMPZ CASING DLOG P Log K1, +1'correction, RIH without making correction on counters 21:54 22:06 0.20 9,267 9,650 COMPZ CASING TRIP P RIH to tag @ 9650, PUW=38K,Set back down, Pumps on 1 BPM @ 3900 PSI, Pick up off liner @ 31K, PUH to 9624,TOL=8437, BOL=11152 22:06 23:06 1.00 9,650 8,413 COMPZ CASING CIRC P Swap well to Seawater, remove liner length from counters 23:06 00:00 0.90 8,413 4,256 COMPZ CASING TRIP P Trip out of well 02/05/2013 Complete Trip out of well with freeze protect 00:00 01:24 1.40 4,256 33 COMPZ CASING TRIP P Trip out continued, Freeze protect from 2500' 01:24 02:24 1.00 33 0 COMPZ CASING PULD P At surface,lay down BHA#13, FSITP=799 02:24 06:00 3.61 0 0 DEMOB WHDBO NUND P Set BPV, PJSM pump corrosion inhibitor,jet stack,flush rig lines 06:00 08:00 2.00 0 0 DEMOB WHDBO NUND P Blow down rig iron and CT reel with rig air. 08:00 08:30 0.50 0 0 DEMOB WHDBO NUND P Prep rig floor and hydraulic cutter for cutting coil. 08:30 11:00 2.50 0 0 DEMOB WHDBO NUND P Cut 2200ft of coil for pipe management. 11:00 12:00 1.00 0 0 DEMOB WHDBO NUND P Nipple down BOPE. install tree cap. XXXXXX RIG RELEASE 12 noon XXXXXXX Page 15 of 15 RECEIVED FEB 062013 AOGCC Letter of Transmittal r 'I BAKER Date: February 4, 2013 HUGHES To: From: Christine Mahnken Carl Ulrich/Michael Soper AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 3C-11A f 2..- 1 2 3C-11AL1 ' - 1 B sfl (2) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return 1. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BakerHughes.com Carl.Ulrich, Baker Hughes, Survey Manager Carl.Ulrich@BakerHughes.com �w\��\�j/jos. THE STATE Alaska Oil and Gas ti44 '�� ofLASKA Conservation Commission Tit =_- �' z-= - GOVERNOR SEAN PARNELL 333 West Seventh Avenue Op Anchorage,Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Lamar Gantt CTD Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3C-11A ConocoPhillips Alaska, Inc. Permit No: 212-188 Surface Location: 1177' FNL, 876' FEL, SEC. 14, T12N, R9E, UM Bottomhole Location: 457' FSL, 171' FWL, SEC. 7, T12N, R10E, UM Dear Mr. Gantt: 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, 0// I Daniel T. Seamount, Jr. Commissioner DATED this day of December, 2012. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL V DEC 14 2012 20 AAC 25.005 '-'9�y'1( AoGr/G la Type of Work lb.Proposed Well Class Development-Oil Q• Service-Winj ❑ Single Zone 1 c Specifyif v elrs proposed for Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redd' ❑, • Reentry❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ 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 3C-11A 3.Address 6.Proposed Depth: 12.Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD 11200' TVDSS. 6447' Kuparuk River Field 4a. Location of Well(Governmental Section) 7.Property Designation(Lease Number) Surface' 1177'FNL,876'FEL, Sec 14,T12N, R9E, UM - ADL 25634,25628 L',471-- Kuparuk River Oil Pool Top of Productive Horizon 8.Land Use Permit. / p r Z 0--13.Approximate Spud Date: 1433'FNL, 1019'FEL,Sec 13,T12N, R9E, UM 2567,2581 ry 1/12/2013 Total Depth: 9.Acres in Property. 14.Distance to 457'FSL, 171'FWL, Sec.7,T12N, R10E, UM 489 Nearest Property: 20250 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL' , 82 feet 15.Distance to Nearest Well Open Surface:x- 528698 - y- 5995255 Zone- 4 GL Elevation above MSL: 47 feet to Same Pool: 1R-17,1250' 16 Deviated wells: Kickoff depth: 8455 ft. • 17.Maximum Anticipated Pressures in psig(see 20 MC 25 035) Maximum Hole Angle' 93.6° deg, Downhole:3882 psig r Surface 3243 psig • 18 Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c f or sacks Hole Casing Weight Grade Coupling Length MD TVDSS MD s TVDSS (including stage data) 3" 2 375 4 7# L-80 ST-L 2430' 8770' 6510' 11200' 6527' 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) 8862 6731 8147', 8511' 8771' 6671' none Casing • Length Size Cement Volume MD TVD Conductor/Structural 44' 16" 215 sx CS II 80' 80' Surface 4435' 9.625" 1360 sx AS III,320 sx Class G 4470' 3800' Intermediate Production • 8812' 7" 325 sx Class G 8856' 6728' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 8386'-8400', 8582'-8590', 8595'-8640' 6417'-6426', 6546'-6552', 6555'-6585' 20.Attachments' Property Plat❑ BOP Sketch❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25 050 requirements Q 21.Verbal Approval: Commission Representative Date 22. I hereby certify that the foregoing is true and correct. Contact Kai Starck @ 263-4093 Email Kai Starck(a conocophillips.com Printed Name Lamar Gantt Title CTD Supervisor 0 Signature \ � LI , Phone 10 Z/ Date I 2-/01/ Commission Use Only Permit to Drill API Number. Permit Approval See cover letter Number. 2 ( Z /EU 50- 62-4-, ()/ Date. I Z I�I t for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed mejhane,gas hydrates,or gas contained in shales: d Other: j.'4000 44); /5147 �S f-- Samples req'd: Yes ❑ No © Mud log req'd: Yes No RIS n.a.la.r, � -7 H2S measures: Yes d No Directional svy req'd: Yes d No❑ Spacing exception req'd: Yes ❑ No Inclination-only svy req'd: Yes/20/9z— --2 // ❑ No /-:.)/ APPROVED BY THE !�/z O/J�_ Approved by: COMMISC tetSfk,O Date /// L (Revised ) permitt ti�� P� pP ( AA (g)) //$i ( I�Form 10-401 10/201 This is valid r n t atr frov� 20 AAC 25.005�9'/2 A-7-- ConocoPhillips p Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 December 12, 2012 Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Permit to Drill (PTD) applications to drill and complete 3C-11A and 3C-11AL1 from Kuparuk well 3C-11 (PTD# 185-102). Coiled tubing drilling (CTD) operations are scheduled to begin January 12, 2013 using the Nabors CDR2-AC rig. Producer 3C-11 is part of a redevelopment concept of moving the offtake point to the east to help produce bypassed oil from the 1 R-09 and 1 R-10 injection patterns that have insufficient offtake points A RWO has recently been completed that replaced the 2-7/8"tubing with 3-1/2"tubing. i„- Prior Prior to commencing CTD operations all of the original C-sand perforations will be squeezed. There is a tubing tail plug that isolates the original A-sand perforations which will have a cement plug above it. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to plug the A-sand perfs in this manner. There is insufficient room to meet these plugging requirements while still accommodating a sidetrack from 8455' MD. Attached to this application are the following documents that explain the proposed job operations. A BOP schematic for slimhole CTD operations from Nabors CDR2 is already on file with the Commission. — Drilling program summary — Permit to Drill application forms for 3C-11A and 3C-11AL1 — Directional plans for 3C-11A and 3C-11AL1 — Current wellbore schematic following the RWO setup — Proposed wellbore schematic after CTD operations If you have any questions or require additional information please contact me at my office 907-263-4093. Sincerely, Kai Starck ConocoPhillips Alaska Coiled Tubing Drilling Specialist Kuparuk CTD Laterals NABORS ALASKA Y^ z3 L<< 3C-11A and 3C-11AL1 CD Application for Permit to Drill Document 2nc 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 Pressure Deployment of BHA 5 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 6 (Requirements of 20 AAC 25.050(b)) 6 16. Construction of Injection Wells (Requirements of 20 AAC 25.412) Attachment 1: Directional Plans for 3C-11A, 3C-11AL1 6 Attachment 2: Current Well Schematic for 3C-11 6 Attachment 3: Proposed Well Schematic for 3C-11 CTD Laterals 6 Page 1 of 6 t t t t i`r December 12,2012 PTD App._.ation for KRU 3C-11A, AL1 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) There are two proposed laterals described in this document: KRU 3C-11A and 3C-11AL1. 3C-11 was recently worked over and the original perforations will be plugged prior to commencing the drilling of the CTD laterals. ' The A sidetrack will be drilled off the motherbore and the AL1 lateral will be drilled off the A sidetrack. Both laterals will be classified as"Development-Oil"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) The 3C-11A sidetrack is planned to target the Kuparuk A3 sand to north of the existing well. The 3C-11AL1 lateral is planned to target the Kuparuk A3 sand to the south. See the attached 10-401 forms for surface and subsurface coordinates of each of the 3C-11 laterals. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and 4000 psi. Using a maximum potential formation pressure of 3882 psi, the maximum potential surface pressure is 3243 psi assuming a gas gradient of 0.1 psi/ft. See the"Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 A AC-R5.005(c)(4)(a)) The final mud weight during the workover operations on 3C-11 November 2012 was 11.1 ppg. The proposed laterals will approach existing injector wells 1R-09 (3939 psi, 11.7 EMW on 9/26/.12)-grid 1R-10 (3729 psi, 11.1 EMW on 12/11/12) to the east so our expectation is that we may encounter elevated formation pressures. Maximum potential formation pressure is based on the September 2012 pressure from 1 R-09, to the east, which had a measured formation pressure of 3939 psi in the A3 sands, or 11.7 EMW at 6480' TVD. For 3C-11A this equates to a maximum potential formation pressure of 3882 psi (8455'MD, 6380'TVD)and a maximum potential surface pressure of 3243 psi assuming a gas gradient to surface. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled. The injector wells 1R-09 and 1 R-10 were last on MI injection in April of 2010. It is unlikely that an influx while drilling will produce a significant amount of gas. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The major expected downhole risk in the 3C-11 laterals is hole stability due to interbedded shales and silts in the A-sand. We will mitigate hole instability by maintaining a minimum ECD target of 12.0 ppg EMW at the window while drilling the CTD laterals, as well as using mud additives that minimize ch mica) tability. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) Each of the 3C-11 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so formation integrity tests are not required. Page 2 of 6 ORIGINAL December 12,2012 PTD Api,__..ation for KRU 3C-11A, AL1 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Liner Liner Liner Liner Lateral Name Top MD Btm Top Btm Liner Details MD SSTVD SSTVD 3C-IIA 8770' 11200' 6510' 6527' 23/8', 4.7#, L-80, ST-L slotted liner; aluminum billet on top 3C-11AL1 8455' 10850' 6462' 6518' 23/8', 4.7#, L-80, ST-L 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" 62 H-40 Welded 0' 80' 0' 80' Surface 9%" 36 J-55 BTC 0' 4469' 0' 3798' 3520 2020 Casing 7" 26 J-55 _ BTC 0' 8855' 0' 6726' 4980 4320 Tubing 3W 9.3 L-80 EUE 8rd-Mod 0' 8487' 0' 6483' 10,160 10,530 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC will be operating under 20 AAC 25.036 for thru-tubing drilling operations so no diverter system is required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. . Description of Drilling Fluid System a. Window milling operations: Chloride-based Biozan brine or used drilling mud (-9.6 ppg) b. Drilling operations: Chloride-based Flo-Pro Flo Vis mud(9.61Dpg). This mud weight alone will not hydrostatically overbalance formation pressure in the 3C-11 motherbore, but overbalanced conditions will be maintained using MPD practices described below. L C. Completion operations: 3C-11 contains a subsurface safety valve (SSSV) at 1794' MD. ✓The SSSV will be used to pressure deploy the liner in lieu of loading the well with completion fluid. In the event that the SSSV becomes inoperable, the well will be loaded with 12.0 ppg sodium bromide completion fluid in order to maintain pressure over-balance while picking up liner. — Emergency Kill Weight fluid: Two well bore volumes (-200 bbl) of 13.1 ppg emergency kill weight fluid will be within a short drive of the rig during drilling operations. Page 3 of 6 0 1.-1 I"'\ C `"* December 12, 2012 PTD Api..__.ation for KRU 3C-11A, AL1 Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections, while at the same time prOViOng pressure over- balance to the formation. In the 3C-11 laterals we will target a constant BHP of 12.0 EMW at the window. If increased formation pressure is encountered, mud weight or choke pressure will beincreased to maintain overbalance. Additional choke pressure or increased mud weight may also be employed for improved borehole stability but not necessarily for well control. Pressure at the 3C-11A Window(8455' MD,' TVD, 6380' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (11.7 ppg) 3882 psi 3882 psi Mud Hydrostatic(9.6 ppg) 3185 psi 3185 psi Annular friction (i.e. ECD, 0.090 psi/ft) 760 psi 0 psi Mud + ECD Combined 3945 psi 3185 psi (no choke pressure) (overbalanced (underbalanced —63 psi) --697 psi) at Window(12.0 ppg) 3981 psi 3981 psi Choke Pressure Required to Maintain Target BHP 36 psi 796 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10.Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11.Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12.Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13.Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 3C-11 was originally completed in June 1985 as a single selective A and C sand producer that produces via gas lift. It has been on production since 1985 until the recent rig workover in preparation for the CTD sidetrack. A mechanical whipstock will be placed in the 3W tubing at the planned kickoff point. The 3C-11A sidetrack will exit the 3W tubing and the 7" casing at 8455' MD and target the A3 sand to the north of the existing well with a 2745' lateral. The hole will be completed with a 2%' slotted liner to the TD of 11,200' MD with an aluminum billet at 8770' MD. Page 4 of 6 December 12, 2012 PTD Api..___ation for KRU 3C-11A, AL1 The 3C-11AL1 lateral will kick off from the aluminum billet at 8770' MD and will target the A3 sand south of the existing well. The hole will be completed with a 2%" slotted liner to the TD of 10,800' MD with a liner top deployment sleeve at 8445' MD. Pre-CTD Work 1. MIRU slickline. Dummy all GLMs. Pull RHC plug. 2. MIRU e-line. Perforate 3-1/2"tubing at 8473-8477' and 8364'-8368'. 3. Perform injectivity test into open C-sand perfs. 4. MIRU coiled tubing. Cement squeeze the open C-sand perforations and lay in cement in the 3-1/2"X 7' annulus, leaving a cement plug in the 3-1/2" tubing. 5. Coiled tubing. Mill cement from —8355' to 8481'with a bi-center bit. This will leave a cement plug on top of the CA-2 plug set in the 2.25" nipple at 8511', plugging off the A-sand perforations. 6. MIRU slickline. Run whipstock dummy inside 3W liner. 7. Prep site for Nabors CDR2-AC, including setting BPV Rig Work ILik 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3C-11A Sidetrack (A3 sand, North) a. Set whipstock at 8455' MD with high-side orientation b. Mill 2.80"window through 3W Tubing and 7" casing at 8455' MD , c. Drill 2.70" x 3" bi-center lateral to TD of 11,200' MD d. Run 2%" slotted liner with an aluminum billet from TD up to 8770', using the SSSV as a barrier to formation pressure if available 3. 3C-11AL1 Lateral (A3 sand, south) a. Kick off of the aluminum billet at 8770' MD b. Drill 2.70"x 3" bi-center lateral to TD of 10,800' MD frD c. Run 2%" slotted liner with an aluminum billet from TD up to 8445' MD inside the 3W tubing, using the SSSV as a barrier to formation pressure if available. 4. Freeze protect. Set BPV, ND BOPE. 5. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP, Install gas lift valves 3. Put well on production Pressure Deployment of BHA The planned bottomhole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. Because of this, MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slickline lubricator. This pressure control equipment ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate Page 5 of 6 f` `- December 12, 2012 PTD Api..__.,ation for KRU 3C-11A, AL1 reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment the steps listed above are conducted in reverse. Liner Running a. Since 3C-11 is equipped with a SSSV, the CTD laterals will not need to be displaced to an over- balancing fluid prior to running liner unless the SSSV fails. In that case, fluid of sufficient density to over-balance the formation will be used to provide well control. See the"Drilling Fluids" section for more details. b. While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" pipe rams provide secondary well control while running 2%" liner. 14.Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) — 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. 15.Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — There are no other affected owners — Please see attached directional plans for each lateral. — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. — Distance to nearest property line and nearest well in the same pool. Distance Distance to Directional to Unit Nearest Lateral Name Plan Boundary Well Nearest Well 3C-11A 05 20,250' 1250' 1R-17 3C-11AL1 04 21,500' 700' 3C-13 Attachment 1: Directional Plans for 3C-11A, 3C-11AL1 Attachment 2: Current Well Schematic for 3C-11 Attachment 3: Proposed Well Schematic for 3C-11 CTD Laterals Page 6 of 6 tI December 12, 2012 I r •N o rJ t O p p o Q3O O U - OQ O O .j c O N N - O J 0V o co m Z U p 0o a) 0 U p co ~ N. 0 N O • co I— .0 .0 E H O Co E N n m mco r N Y CO COCS 2 Y CO CD (00 _a N ;.— Y '47 CO P 1,-. - N co m CO\ I- o U ea @. m �, °°N. Ut a I Y N t 0, cm II r cL Q N Ua Y .� N 'O CID U Q TiQ O]Q' _� -E co m Q N \ co Eco a a)` 0 rn �to a) p = © m O Nao \ a) oF2) in m U D co p er _Cti \, p M Q - a6 E 2 E _Li O _ Q O >a) a0 O 1 = It E `� i E 0 r E E co 5 co ca '7 = n3 >. N m 3 co O 0 M LL U m 0) U C I (a V N N Y Y N O N 0 (a n3 O X Co CO CO CO CO M d W N N I In O il O M / N ct E o / N fl . +� N CO a- I :k:\ ,k\, / C.) 7-4 V/ iiII o ' N � , Q 111 1y \o W N f OI a M p p o O N a) pp Q (Q m III m o Qp N o .4.6-.0 cc —7u) CC a r N uo ND oO0I� 't d7 'cY N I.D) r v m Y `� s� Qw CO CO V SY M � Um () CtcOCO -0 I i� cc M 4# 12 OD- Z:7) � ivir) Lo o - LO rn ac) o» < cc in io Es / / 0 / Z 3 0 > — / E I- as Cr / / C CO 7 Y I o - ƒ $ ® / 0 em _ 7 7 / # co/ % % 7 ¥ @ p cc / 7 U G = % vs a r- _�7 I \ k CC ~ o /ƒ I- 2 K / \ C® - / e E @ = d % 0 ECO /\ % / \ p s o G ƒ .\ E W a 2 % w 9 % g e p / 2 k $ a - - n co f% E e E I 0 - \ 0 > - 0 = 0) 3 k E $ 2 E o % E .E ƒ / 0 / I 0 % o 0E 9 § iN h Zr) $ - o . G \ n CO o 'x \ r"-- A / / 3 co A E L q A Aill _ t @ 1111111 I !!! I ' .7 R % / c2 $ I / / a � � $ \ Et a) a) CO a 8 $ $ e e o $ kO / / / - - ? $ § I / \ $ A c r / k $ k / ROD / \mo Rp •:r co ff M / / / / / / U)± / / / w » $ a) /$ e ƒ _ co & # < c c ƒ p � M A 1 Li (\ | r | iktL ........... ....._ .. . ii ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3C Pad 3C-11 3C-11A Plan: 3C-11A_wp05 Standard Planning Report 13 December, 2012 IFAii-i /1's BAKER HUGHES ConocoPhillips or its affiliates .N' ConocoPhillips Planning Report BAKER Alaska GHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3C-11 Company: ConocoPhillips(Alaska)Inc. ND Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3C-11 @ 82.00ft Site: Kuparuk 3C Pad North Reference: True Well: 3C-11 Survey Calculation Method: Minimum Curvature Wellbore: 3C-11A Design: 3C-11 A_wp05 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 3C Pad Site Position: Northing: 5,995,835.14 ft Latitude: 70°23'58.955 N From: Map Easting: 528,205.68 ft Longitude: 149°46'13.622 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.22° Well 3C-11 Well Position +NI-S 0.00 ft Northing: 5,995,255.22 ft • Latitude: 70°23'53.233 N +El-W 0.00 ft Easting: 528,697.61 ft . Longitude: 149°45'59.274 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 47.30 ft - Wellbore 3C-11A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGG M2011 12/1/2012 15.99 79.99 57,386 Design 3C-11A_wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,440.00 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (ft) (ft) (ft) (0) -47.30 0.00 0.00 40.00 Plan Sections Measured ND Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +El-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°1100ft) (°1100ft) (°/100ft) (°) Target 8,440.00 48.84 95.26 6,370.68 -236.93 4,817.76 0.00 0.00 0.00 0.00 8,455.00 49.03 95.03 6,380.54 -237.95 4,829.02 1.71 1.27 -1.53 -42.46 8,480.00 53.53 95.03 6,396.17 -239.66 4,848.44 18.00 18.00 0.00 0.00 8,575.00 79.18 95.03 6,433.95 -247.22 4,934.41 27.00 27.00 0.00 0.00 8,675.00 89.18 95.03 6,444.08 -255.94 5,033.39 10.00 10.00 0.00 0.00 8,875.00 90.25 75.06 6,445.08 -238.74 5,231.63 10.00 0.54 -9.99 273.00 9,075.00 93.64 55.33 6,438.21 -155.35 5,412.16 10.00 1.69 -9.86 280.00 9,225.00 92.23 70.29 6,430.48 -87.10 5,545.03 10.00 -0.94 9.97 95.00 9,825.00 90.25 10.30 6,416.17 349.86 5,915.36 10.00 -0.33 -10.00 269.00 10,100.00 87.91 37.71 6,420.67 598.65 6,026.12 10.00 -0.85 9.97 95.00 10,500.00 88.40 357.69 6,434.07 971.81 6,145.18 10.00 0.12 -10.00 270.00 10,850.00 88.69 32.70 6,443.23 1,304.23 6,235.46 10.00 0.08 10.00 90.00 11,010.00 89.57 16.72 6,445.67 1,449.09 6,302.12 10.00 0.55 -9.99 273.00 11,200.00 89.59 357.72 6,447.08 1,636.72 6,325.89 10.00 0.01 -10.00 270.00 12/13/2012 1:41:24PM Page 2 COMPASS 2003.16 Build 69 H1 • N-- ConocoPhillips or its affiliates Irei'- ConocoPhillipAlass Planning Report HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3C-11 Company: ConocoPhillips(Alaska)Inc. ND Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3C-11 @ 82.00ft Site: Kuparuk 3C Pad North Reference: True Well: 3C-11 Survey Calculation Method: Minimum Curvature Wellbore: 3C-11A Design: 3C-11 A_wp05 Planned Survey Measured ND Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NI-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°1100ft) (°) (ft) (ft) 8,440.00 48.84 95.26 6,370.68 -236.93 4,817.76 2,915.29 0.00 0.00 5,995,036.81 533,515.76 TIP 8,455.00 49.03 95.03 6,380.54 -237.95 4,829.02 2,921.75 1.71 -42.46 5,995,035.84 533,527.03 KOP 8,480.00 53.53 95.03 6,396.17 -239.66 4,848.44 2,932.93 18.00 0.00 5,995,034.20 533,546.46 End 27 DLS 8,500.00 58.93 95.03 6,407.28 -241.12 4,865.00 2,942.46 27.00 0.00 5,995,032.81 533,563.02 8,575.00 79.18 95.03 6,433.95 -247.22 4,934.41 2,982.39 27.00 0.00 5,995,026.97 533,632.45 Start 10 DLS 8,600.00 81.68 95.03 6,438.11 -249.39 4,958.97 2,996.52 10.00 0.00 5,995,024.90 533,657.01 8,675.00 89.18 95.03 6,444.08 -255.94 5,033.39 3,039.34 10.00 0.00 5,995,018.64 533,731.44 5 8,700.00 89.31 92.53 6,444.41 -257.58 5,058.33 3,054.11 10.00 -87.00 5,995,017.08 533,756.39 8,800.00 89.85 82.55 6,445.15 -253.30 5,158.11 3,121.53 10.00 -86.97 5,995,021.75 533,856.14 8,875.00 90.25 75.06 6,445.08 -238.74 5,231.63 3,179.94 10.00 -86.89 5,995,036.59 533,929.60 6 8,900.00 90.69 72.60 6,444.87 -231.78 5,255.64 3,200.70 10.00 -80.00 5,995,043.64 533,953.58 9,000.00 92.40 62.74 6,442.17 -193.85 5,347.99 3,289.12 10.00 -80.02 5,995,081.92 534,045.77 9,075.00 93.64 55.33 6,438.21 -155.35 5,412.16 3,359.87 10.00 -80.29 5,995,120.67 534,109.79 7 9,100.00 93.42 57.83 6,436.66 -141.61 5,432.99 3,383.78 10.00 95.00 5,995,134.49 534,130.56 9,200.00 92.48 67.80 6,431.50 -96.04 5,521.71 3,475.72 10.00 95.15 5,995,180.39 534,219.10 9,225.00 92.23 70.29 6,430.48 -87.10 5,545.03 3,497.55 10.00 95.67 5,995,189.41 534,242.39 8 9,300.00 92.08 62.78 6,427.65 -57.28 5,613.73 3,564.56 10.00 -91.00 5,995,219.50 534,310.97 9,400.00 91.83 52.78 6,424.24 -4.06 5,698.18 3,659.60 10.00 -91.28 5,995,273.03 534,395.20 9,500.00 91.52 42.78 6,421.32 63.02 5,772.11 3,758.52 10.00 -91.62 5,995,340.39 534,468.86 9,600.00 91.16 32.78 6,418.97 141.93 5,833.28 3,858.29 10.00 -91.92 5,995,419.53 534,529.73 9,700.00 90.77 22.79 6,417.29 230.28 5,879.83 3,955.89 10.00 -92.15 5,995,508.05 534,575.93 9,800.00 90.35 12.80 6,416.30 325.37 5,910.35 4,048.35 10.00 -92.32 5,995,603.24 534,606.09 9,825.00 90.25 10.30 6,416.17 349.86 5,915.36 4,070.33 10.00 -92.42 5,995,627.75 534,611.00 9 9,900.00 89.59 17.77 6,416.28 422.57 5,933.54 4,137.71 10.00 95.00 5,995,700.52 534,628.89 10,000.00 88.74 27.74 6,417.74 514.66 5,972.16 4,233.08 10.00 94.99 5,995,792.75 534,667.16 10,100.00 87.91 37.71 6,420.67 598.65 6,026.12 4,332.11 10.00 94.84 5,995,876.94 534,720.79 10 10,200.00 87.95 27.70 6,424.29 682.63 6,080.05 4,431.11 10.00 -90.00 5,995,961.12 534,774.39 10,300.00 88.04 17.69 6,427.80 774.71 6,118.56 4,526.40 10.00 -89.64 5,996,053.34 534,812.55 10,400.00 88.19 7.69 6,431.09 872.09 6,140.49 4,615.09 10.00 -89.29 5,996,150.80 534,834.10 10,500.00 88.40 357.69 6,434.07 971.81 6,145.18 4,694.49 10.00 -88.96 5,996,250.52 534,838.40 11 10,600.00 88.43 7.69 6,436.84 1,071.54 6,149.86 4,773.90 10.00 90.00 5,996,350.25 534,842.70 10,700.00 88.50 17.70 6,439.53 1,168.93 6,171.80 4,862.61 10.00 89.72 5,996,447.72 534,864.27 10,800.00 88.62 27.70 6,442.05 1,261.04 6,210.33 4,957.93 10.00 89.45 5,996,539.97 534,902.43 10,850.00 88.69 32.70 6,443.23 1,304.23 6,235.46 5,007.18 10.00 89.20 5,996,583.25 534,927.40 12 10,900.00 88.96 27.70 6,444.26 1,347.42 6,260.60 5,056.42 10.00 -87.00 5,996,626.53 534,952.37 11,000.00 89.51 17.72 6,445.59 1,439.54 6,299.16 5,151.77 10.00 -86.90 5,996,718.79 534,990.57 11,010.00 89.57 16.72 6,445.67 1,449.09 6,302.12 5,160.99 10.00 -86.76 5,996,728.36 534,993.49 13 11,100.00 89.57 7.72 6,446.35 1,536.96 6,321.15 5,240.54 10.00 -90.00 5,996,816.29 535,012.18 11,200.00 89.59 357.72 6,447.08 1,636.72 6,325.89 5,320.00 10.00 -89.93 5,996,916.05 535,016.54 12/13/2012 1:41:24PM Page 3 COMPASS 2003.16 Build 69 c: R b . , ConocoPhillips or its affiliates .d'" ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3C-11 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3C-11 @ 82.00ft Site: Kuparuk 3C Pad North Reference: True Well: 3C-11 Survey Calculation Method: Minimum Curvature Wellbore: 3C-11A Design: 3C-11 A_wp05 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +EI-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/lOOft) (°) (ft) (ft) TD at 11200.00 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (1 (ft) (ft) (ft) (ft) (ft) Latitude Longitude 3C-11A_Fault1 0.00 0.00 0.00 -268.46 5,056.40 5,995,006.20 533,754.50 70°23'50.576 N 149°43'31.162 W -plan misses target center by 6375.23ft at 8440.00ft MD(6370.68 TVD,-236.93 N,4817.76 E) -Rectangle(sides W300.00 H1.00 D0.00) 3C-11A_T2 0.00 0.00 6,444.00 -263.22 5,252.44 5,995,012.19 533,950.51 70°23'50.626 N 149°43'25.420 W -plan misses target center by 29.19ft at 8888.19ft MD(6444.99 TVD,-235.20 N,5244.33 E) -Point 3C-11A_T6 0.00 0.00 6,447.00 1,691.87 6,312.09 5,996,971.14 535,002.53 70°24'9.846 N 149:42'54.332 W -plan misses target center by 56.85ft at 11200.00ft MD(6447.08 TVD,1636.72 N,6325.89 E) -Point 3C-11 CTD Polygon_No 0.00 0.00 0.00 -187.98 4,932.70 5,995,086.20 533,630.51 70°23'51.368 N 149°43'34.784 W -plan misses target center by 6371.91ft at 8440.00ft MD(6370.68 TVD,-236.93 N,4817.76 E) -Polygon Point 1 0.00 -187.98 4,932.70 5,995,086.20 533,630.51 Point 2 0.00 -177.12 5,232.77 5,995,098.21 533,930.50 Point 3 0.00 416.10 5,721.07 5,995,693.24 534,416.47 Point4 0.00 1,162.27 5,960.92 5,996,440.25 534,653.43 Point 5 0.00 1,896.14 6,278.74 5,997,175.27 534,968.40 Point6 0.00 1,733.01 6,573.15 5,997,013.28 535,263.40 Point 7 0.00 645.18 6,232.99 5,995,924.26 534,927.46 Point 8 0.00 239.68 6,089.44 5,995,518.26 534,785.48 Point 9 0.00 -216.84 5,685.67 5,995,060.23 534,383.51 Point 10 0.00 -377.65 5,369.03 5,994,898.23 534,067.52 Point 11 0.00 -354.98 4,928.07 5,994,919.20 533,626.52 Point 12 0.00 -187.98 4,932.70 5,995,086.20 533,630.51 3C-11A T4 0.00 0.00 6,418.00 554.17 5,948.67 5,995,832.17 534,643.52 70°23'58.660 N 149°43'5.007 W -plan misses target center by 39.70ft at 10020.57ft MD(6418.22 TVD,532.68 N,5982.05 E) -Point 3C-11A_T1 0.00 0.00 6,444.00 -268.46 5,056.40 5,995,006.20 533,754.50 70°23'50.576 N 149°43'31.162 W -plan misses target center by 10.96ft at 8698.79ft MD(6444.40 TVD,-257.53 N,5057.12 E) -Point 3C-11A_T3 0.00 0.00 6,438.00 -156.86 5,420.87 5,995,119.19 534,118.51 70°23'51.671 N 149°43'20.484 W -plan misses target center by 6.17ft at 9081.44ft MD(6437.80 TVD,-151.72 N,5417.47 E) -Point 3C-11A_T5 0.00 0.00 6,440.00 1,226.50 6,137.28 5,996,505.15 534,829.53 70°24'5.270 N 149°42'59.465 W -plan misses target center by 51.97ft at 10739.84ft MD(6440.56 TVD,1206.42 N,6185.22 E) -Point 12/13/2012 1:41:24PM Page 4 COMPASS 2003.16 Build 69 d' ConocoPhillips or its affiliates IMP- ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3C-11 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3C-11 @ 82.00ft Site: Kuparuk 3C Pad North Reference: True Well: 3C-11 Survey Calculation Method: Minimum Curvature Wellbore: 3C-11A Design: 3C-11A_wp05 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name f') r) 4,470.00 3,716.94 9 5/8" 9-5/8 12-1/4 11,200.00 6,447.08 2 3/8" 2-3/8 3 Formations Measured Vertical Dip Depth Depth Dip Direction (ft) (ft) Name Lithology (0) (0) 8,599.24 6,438.00 Formation 2 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 8,440.00 6,370.68 -236.93 4,817.76 TIP 8,455.00 6,380.54 -237.95 4,829.02 KOP 8,480.00 6,396.17 -239.66 4,848.44 End 27 DLS 8,575.00 6,433.95 -247.22 4,934.41 Start 10 DLS 8,675.00 6,444.08 -255.94 5,033.39 5 8,875.00 6,445.08 -238.74 5,231.63 6 9,075.00 6,438.21 -155.35 5,412.16 7 9,225.00 6,430.48 -87.10 5,545.03 8 9,825.00 6,416.17 349.86 5,915.36 9 10,100.00 6,420.67 598.65 6,026.12 10 10,500.00 6,434.07 971.81 6,145.18 11 10,850.00 6,443.23 1,304.23 6,235.46 12 11,010.00 6,445.67 1,449.09 6,302.12 13 11,200.00 6,447.08 1,636.72 6,325.89 TD at 11200.00 12/13/2012 1:41:24PM Page 5 COMPASS 2003.16 Build 69 . 4 ( ..- t i e .t ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 3C Pad 3C-11 3C-11A 3C-11 A_wp05 Travelling Cylinder Report 13 December, 2012 BAKER HUGHES l rl ConocoPhillips or its affiliates irery ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3C-11 Project: Kuparuk River Unit TVD Reference: 3C-11 @ 82.00ft Reference Site: Kuparuk 3C Pad MD Reference: 3C-11 @ 82.00ft Site Error: 0.00ft North Reference: True Reference Well: 3C-11 Survey Calculation Method: Minimum Curvature Well Error: O.00ft Output errors are at 1.00 sigma Reference Wellbore 30-11A Database: EDM Alaska Prod v16 Reference Design: 3C-11A_wp05 Offset TVD Reference: Offset Datum Reference 30-11A_wp05 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 8,440.00 to 11,200.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,316.53ft Error Surface: Elliptical Conic Survey Tool Program Date 12/13/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description 40.00 8,440.00 3C-11 GyroData(3C-11) Copy of GYD-CT-CMS Gyrodata cont.casing m/s 8,440.00 11,200.00 3C-11A_wp05(3C-11A) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name 1") ("1 11,200.00 6,529.08 2 3/8" 2-3/8 3 1 4,470.00 3,798.94 9 5/8" 9-5/8 12-1/4 i Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 1R Pad 1R-17-1R-17-1R-17 Out of range Kuparuk 3C Pad 3C-10-3C-10-3C-10 Out of range 3C-11-3C-11-3C-11 8,450.00 8,450.00 0.00 0.64 -0.62 FAIL-Major Risk 3C-11-3C-11AL1-3C-11AL1_wp04 8,775.00 8,775.00 0.05 0.61 -0.56 FAIL-Major Risk 3C-13-3C-13-3C-13 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 12/13/2012 9:18:43AM Page 2 of 6 COMPASS 2003.16 Build 69 Cl ' � �' 6... yy‘ 5l5 i •.,-- ConocoPhillips or its affiliates VA'" ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3C-11 Project: Kuparuk River Unit TVD Reference: 3C-11 @ 82.00ft Reference Site: Kuparuk 3C Pad MD Reference: 3C-11 @ 82.00ft Site Error: 0.00ft North Reference: True Reference Well: 3C-11 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3C-11A Database: EDM Alaska Prod v16 Reference Design: 3C-11A_wp05 Offset TVD Reference: Offset Datum Offset Design Kuparuk 3C Pad- 3C-11-3C-11-3C-11 Offset Site Error: 0.00 ft Survey Program: 40-Copy of GYD-CT-CMS,8600-GCT-MS Rule Assigned:Major Risk Offset Well Error: 0.00 ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/S +E/-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ff) (ft) Iff) l°) (ft) (ft) (ft) (ft) (f) (ft) 8,450.00 6,459.26 8,450.00 6,459.26 0.09 0.05 -139.50 -237.62 4,825.26 0.22 0.00 0.64 -0.62 FAIL-Major Risk,CC,ES,SF 8,474.97 6,475.15 8,475.00 6,475.67 0.14 0.19 -85.94 -239.28 4,844.04 0.22 0.65 1.47 -0.49 FAIL-Major Risk 8,499.57 6,489.06 8,500.00 6,492.15 0.14 0.32 -86.52 -241.02 4,862.76 0.22 3.62 2.33 1.69 Pass-Major Risk 8,523.20 6,500.15 8,525.00 6,508.63 0.15 0.46 -86.01 -242.74 4,881.49 0.22 9.34 3.20 6.64 Pass-Major Risk 8,545.36 6,508.38 8,550.00 6,525.14 0.16 0.59 -85.66 -244.42 4,900.18 0.22 17.71 4.04 1429 Pass-Major Risk 8,565.74 6,514.02 8,575.00 6,541.68 0.16 0.68 -85.47 -246.10 4,918.85 0.22 28.43 5.27 23.62 Pass-Major Risk 8,585.32 6,517.80 8,600.00 6,558.17 0.17 0.74 -85.36 -247.78 4,937.56 0.22 40.97 6.79 34.49 Pass-Major Risk 8,604.82 6,520.79 8,625.00 6,574.63 0.17 0.75 -85.29 -249.46 4,956.31 0.22 54.35 7.25 47,44 Pass-Major Risk 8,623.48 6,523.03 8,650.00 6,591.09 0.17 0.75 -85.24 -251.12 4,975.05 0.22 68.43 7.70 61.10 Pass-Major Risk 8,641.33 6,524.61 8,675.00 6,607.54 0.19 0.75 -85.19 -252.77 4,993.81 0.22 83.15 8.13 75.43 Pass-Major Risk 8,658.38 6,525.60 8,700.00 6,623.98 021 0.75 -85.14 -254.40 5,012.57 022 98.47 8.54 90.38 Pass-Major Risk 8,675.00 6,526.08 8,725.00 6.640.44 024 0.76 -85.11 -256.03 5,031.32 022 114.37 8.94 105.91 Pass-Major Risk 8,693.38 6,526.33 8,750.00 6,656.91 027 0.76 -87.02 -257.66 5,050.05 022 130.60 9.34 121.90 Pass-Major Risk 8,712.07 6,526.55 8,775.00 6,673.41 0.31 0.77 -89.19 -259.29 5,068.76 0.22 146.88 9.78 137.93 Pass-Major Risk 8,730.60 6,526.73 8,800.00 6,689.94 0.35 0.77 -91.50 -260.93 5,087.45 0.22 163.23 10.23 154.02 Pass-Major Risk 8,748.96 6,526.89 8,825.00 6,706.47 0.39 0.78 -93.91 -262.57 5,106.13 022 179.65 8.98 172.37 Pass-Major Risk 8,767.11 6,527.01 8,850.00 6,723.00 0.43 0.78 -96.37 -264.21 5,124.81 0.22 196.14 8.27 190.80 Pass-Major Risk 8,773.58 6,527.04 8,859.00 6,728.95 0.45 0.78 -97.26 -264.80 5,131.53 0.22 202.10 8.22 19722 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 12/13/2012 9:18:43AM Page 3 of 6 COMPASS 2003.16 Build 69 ConocoPhillips or its affiliates FGil' ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3C-11 Project: Kuparuk River Unit TVD Reference: 3C-11 @ 82.00ft Reference Site: Kuparuk 3C Pad MD Reference: 3C-11 @ 82.0Oft Site Error: 0.008 North Reference: True Reference Well: 3C-11 Survey Calculation Method: Minimum Curvature Well Error: O.00ft Output errors are at 1.00 sigma Reference Wellbore 3C-11A Database: EDM Alaska Prod v16 Reference Design: 3C-11A_wp05 Offset ND Reference: Offset Datum Offset Design Kuparuk 3C Pad- 3C-11-3C-11AL1-3C-11AL1_wp04 Offset Site Error: 0.00 ft Survey Program: 40-Copy of GYD-CT-CMS,8440-MWD,8770-MWD Rule Assigned:Major Risk Offset Well Error: 0.0011 Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +NIS +EI-W Hole Size Centre Distance Deviation (ft) (ft) lrt) Ift) Ift) le) 1°) (ft) (ft) (ft) )ft) (ft) )ft) 8,772.71 6,527.04 10,325.00 6,511.74 0.00 9.01 174.56 -1,486.30 5,232.80 0.22 1,234.40 7.96 1,229.89 Pass-Major Risk 8,775.00 6,527.05 8,775.00 6,527.01 0.01 0.10 129.63 -256.04 5,133.26 0.22 0.05 0.61 -0.56 FAIL-Major Risk,CC,ES,SF 8,776.35 6,527.06 10,300.00 6,511.29 0.01 8.83 174.16 -1,463.15 5,242.23 0.22 1,212.16 8.10 1,207.42 Pass-Major Risk 8,780.43 6,527.08 10,275.00 6,510.85 0.02 8.63 173.72 -1,440.51 5,252.81 0.22 1,190.60 8.26 1,185.59 Pass-Major Risk 8,799.91 6,527.14 8,800.00 6,525.88 0.08 0.10 127.09 -254.56 5,158.18 0.22 1.80 1.02 0.85 Pass-Major Risk 8,800.00 6,527.15 10,000.00 6,508.90 0.08 6.34 171.42 -1,173.24 5,307.89 0.22 932.20 8.35 928.59 Pass-Major Risk 8,800.00 6,527.15 10,025.00 6,508.87 0.08 6.47 171.45 -1,196.38 5,298.26 0.22 953.62 8.38 948.00 Pass-Major Risk 8,800.00 6,527.15 10,050.00 6,508.88 0.08 6.63 171.47 -1,220.20 5,290.67 0.22 976.11 8.42 970.48 Pass-Major Risk 8,800.00 6,527.15 10,075.00 6,508.93 0.08 6.80 171.50 -1,244.53 5,284.97 0.22 999.48 8.48 993.82 Pass-Major Risk 8,800.00 6,527.15 10,100.00 6,509.02 0.08 7.00 171.53 -1269.24 5,281.20 0.22 1,023.53 8.58 1,017.81 Pass-Major Risk 8,800.00 6,527.15 10,125.00 6,509.14 0.08 7.21 171.57 -1,294.18 5,279.38 0.22 1,048.06 8.68 1,042.28 Pass-Major Risk 8,800.00 6,527.15 10,150.00 6,509.31 0.08 7.44 171.60 -1,319.16 5,279.21 0.22 1,072.87 8.79 1,087.00 Pass-Major Risk 8,800.00 6,527.15 10,175.00 8,509.52 0.08 7.70 171.63 -1,344.11 5,277.78 0.22 1,097.50 8.88 1,091.55 Pass-Major Risk 8,800.00 6,527.15 10,200.00 6,509.78 0.08 7.95 171.66 -1,368.88 5,274.40 0.22 1,121.76 8.95 1,115.76 Pass-Major Risk 8,800.00 8,527.15 10,225.00 6,510.09 0.08 8.18 171.70 -1,393.30 5,269.09 022 1,145.51 8.98 1,139.50 Pass-Major Risk 8,800.00 8,527.15 10,250.00 6,510.45 0.08 8.41 171.73 -1,417.22 5,261.88 0.22 1,168.66 8.99 1,162.67 Pass-Major Risk 8,816.61 6,527.18 9,975.00 6,508.97 0.12 6.22 169.74 -1,150.90 5,318.91 0.22 911.68 8.94 905.32 Pass-Major Risk 8,822.94 6,527.18 9,950.00 8,509.08 0.14 6.12 169.09 -1,129.52 5,331.85 0.22 892.71 9.14 886.05 Pass-Major Risk 8,824.40 6,527.18 8,825.00 6,523.16 0.15 0.11 129.16 -254.19 5,183.03 0.22 6.14 1.45 4.86 Pass-Major Risk 8,830.00 6,527.18 9,925.00 6,509.23 0.16 6.04 168.38 -1,109.21 5,346.42 0.22 875.27 9.36 868.30 Pass-Major Risk 8,848.10 6,527.16 8,850.00 6,519.51 0.21 0.13 131.95 -255.45 5,207.72 0.22 13.09 1.91 11.54 Pass-Major Risk 8,850.00 6,527.16 9,850.00 6,509.91 0.22 5.87 166.37 -1,055.47 5,398.56 022 83323 9.98 82528 Pass-Major Risk 8,850.00 6,527.18 9,875.00 6,509.64 0.22 5.92 166.37 -1,072.34 5,380.11 022 845.70 9.93 837.87 Pass-Major Risk 8,850.00 6,527.18 9,900.00 6,509.42 0.22 5.97 166.37 -1,090.12 5,362.54 0.22 859.76 9.95 851.97 Pass-Major Risk 8,863.52 6,527.12 9,825.00 6,510.29 0.26 5.81 165.03 -1,037.43 5,415.85 0.22 819.63 10.44 811.05 Pass-Major Risk 8,870.64 6,527.10 8,875.00 6,515.69 0.28 0.18 135.00 -258.62 5,232.22 0.22 22.48 2.43 20.31 Pass-Major Risk 8,875.00 6,527.08 9,775.00 6,511.41 0.29 5.63 163.92 -997.57 5,445.93 0.22 788.88 10.81 779.51 Pass-Major Risk 8,875.00 8,527.08 9,800.00 6,510.80 0.29 5.73 183.90 -1,018.08 5,431.67 0.22 804.77 10.80 795.67 Pass-Major Risk 8,887.59 6,527.00 9,750.00 6,512.14 0.34 5.52 182.71 -975.99 5,458.53 0.22 771.28 11.15 761.66 Pass-Major Risk 8,891.88 8,526.96 8,900.00 6,512.53 0.35 0.23 138.20 -263.59 5,258.51 0.22 33.90 2.96 31.18 Pass-Major Risk 8,900.00 6,526.87 9,675.00 6,514.29 0.38 5.11 161.60 -906.31 5,485.71 0.22 712.80 11.25 702.92 Pass-Major Risk 8,900.00 6,526.87 9,700.00 6,513.68 0.38 5.26 161.57 -930.23 5,478.48 022 73326 11.36 72327 Pass-Major Risk 8,900.00 6,526.87 9,725.00 6,512.95 0.38 5.40 161.53 -953.50 5,469.40 022 752.84 11.44 742.80 Pass-Major Risk 8,911.74 6,526.71 8,925.00 6,510.83 0.42 0.30 141.39 -270.01 5,280.58 022 46.91 3.48 43.67 Pass-Major Risk 8,913.88 6,526.68 9,650.00 6,514.76 0.42 4.94 160.24 -881.90 5,491.04 0.22 69123 11.48 680.99 Pass-Major Risk 8,919.09 6,526.59 9,625.00 6,515.10 0.44 4.76 159.73 -857.14 5,494.45 022 668.93 11.44 658.69 Pass-Major Risk 8,923.66 6,526.50 9,600.00 6,515.31 0.46 4.57 15927 -832.19 5,495.91 022 645.89 11.33 635.71 Pass-Major Risk 8,927.51 6,526.43 9,575.00 6,515.38 0.47 4-37 158.87 -80720 5,495.41 022 62223 11.18 612.17 Pass-Major Risk 8,930.01 6,526.37 8,950.00 6,510.12 0.48 0.36 144.31 -277.78 5,304.34 022 61.48 3.98 57.75 Pass-Major Risk 8,930.75 6,526.38 9,550.00 6,515.32 0.48 4.18 158.51 -782.30 5,493.27 022 598.13 11.00 58821 Pass-Major Risk 8,934.72 6,52627 9,525.00 6,51523 0.50 4.01 158.07 -757.32 5,492.38 022 574.44 10.85 584.64 Pass-Major Risk 8,946.52 6,525.99 8,975.00 6,510.74 0.54 0.44 146.70 -286.94 5,327.58 022 77.73 4.42 73.57 Pass-Major Risk 8,950.00 6,525.89 9,450.00 6,514.97 0.55 3.60 156.46 -683.04 5,501.46 022 508.83 10.53 49921 Pass-Major Risk 8,950.00 6,525.89 9,475.00 6,515.06 0.55 3.72 156.48 -707.54 5,496.49 022 529.61 10.76 519.78 Pass-Major Risk 8,950.00 6,525.89 9,500.00 6,515.15 0.55 3.86 156.50 -732.35 5,493.46 022 551.71 10.99 541.65 Pass-Major Risk 8,960.96 6,525.58 9,000.00 6,511.38 0.60 0.53 148.08 -297.85 5,350.06 022 96.01 4.79 91.49 Pass-Major Risk 8,981.72 6,525.56 9,425.00 6,514.88 0.80 3.47 155.26 -658.93 5,508,03 0.22 489.19 10.60 479.41 Pass-Major Risk 8,969.84 6,525.30 9,400.00 8,514.78 0.64 3.33 154.43 -634.51 5,513.39 0.22 469.03 10.55 459.23 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 12/13/2012 9:18:43AM Page 4 of 6 COMPASS 2003.16 Build 69 ' 1\1 4� , i �, • • ConocoPhillips or its affiliates E' ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3C-11 Project: Kuparuk River Unit TVD Reference: 3C-11 @ 82.00ft Reference Site: Kuparuk 3C Pad MD Reference: 3C-11 @ 82.00ft Site Error: 0.00ft North Reference: True Reference Well: 3C-11 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3C-11A Database: EDM Alaska Prod v16 Reference Design: 3C-11A_wp05 Offset TVD Reference: Offset Datum Offset Design Kuparuk 3C Pad- 3C-11-3C-11AL1-3C-11AL1_wp04 Offset Site Error: 0.00 ft Survey Program: 40-Copy of GYD-CT-CMS,8440-MVVD,8770-MWD Rule Assigned:Major Risk Offset Well Error: 0.00 ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +81-0 +E/-W Hole Size Centre Distance Deviation (n) (ft) (ft) (ff) (ft) (ft) l°) (ft) (ft) (ft) (ft) OH (ft) 8,973.30 6,525.18 9,025.00 6,511.91 0.65 0.64 148.80 -310.49 5,371.62 0.22 116.03 5.06 111.26 Pass-Major Risk 8,977.36 6,525.04 9,375.00 6,514.67 0.67 3.17 153.65 -609.76 5,516.81 022 447.95 10.44 43821 Pass-Major Risk 8,983.58 6,524.82 9,050.00 6,512.32 0.70 0.76 149.14 -324.78 5,392.12 0.22 137.47 5.15 132.64 Pass-Major Risk 8,984.24 6,524.79 9,350.00 6,514.54 0.70 3.00 152.92 -584.80 5,518.27 0.22 426.04 10.27 416.41 Pass-Major Risk 8,991.87 6,524.50 9,075.00 6,512.62 0.74 0.90 14928 -340.64 5,411.43 0.22 160.07 4.94 155.47 Pass-Major Risk 9,000.00 6,524.17 9,100.00 6,512.83 0.77 1.06 149.16 -357.96 5,429.45 0.22 183.57 5.86 178.06 Pass-Major Risk 9,000.00 6,524.17 9,125.00 6,513.02 0.77 123 149.71 -376.64 5,446.06 022 207.73 6.42 201.72 Pass-Major Risk 9,000.00 6,524.17 9,150.00 6,513.21 0.77 1.42 150.12 -396.56 5,461.14 0.22 232.42 6.95 225.91 Pass-Major Risk 9,000.00 6,524.17 9,175.00 6,513.40 0.77 1.61 150.44 -417.61 5,474.62 0.22 257.33 7.47 250.34 Pass-Major Risk 9,000.00 6,524.17 9,200.00 6,513.59 0.77 1.82 150.68 -439.65 5,486.41 022 282.29 7.99 274.81 Pass-Major Risk 9,000.00 6,524.17 9,225.00 6,513.77 0.77 2,02 150.87 -462.55 5,496.43 0.22 307.15 8.49 299.18 Pass-Major Risk 9,000,00 6,524.17 9,250.00 6,513.94 0.77 2.23 151.01 -486.16 5,504.62 0.22 331.79 8.97 323.34 Pass-Major Risk 9,000.00 6,524.17 9,275.00 6,514.10 0.77 2.43 151.12 -510.34 5,510.93 0.22 356.12 9.43 347.22 Pass-Major Risk 9,000.00 6,524.17 9,300.00 6,514.26 0.77 2.63 151.20 -534.94 5,515.33 0.22 380.06 9.87 370.73 Pass-Major Risk 9,000.00 6,524.17 9,325.00 6,514.41 0.77 2.82 151.26 -559.82 5,517.78 0.22 403.56 10.27 393.82 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 12/13/2012 9:18:43AM Page 5 of 6 COMPASS 2003.16 Build 69 • ConocoPhillips or its affiliates Fg COnOCOPUiilpS Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3C-11 Project: Kuparuk River Unit TVD Reference: 3C-11 @ 82.00ft Reference Site: Kuparuk 3C Pad MD Reference: 3C-11 @ 82.00ft Site Error: 0.00ft North Reference: True Reference Well: 3C-11 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3C-11A Database: EDM Alaska Prod v16 Reference Design: 3C-11A_wp05 Offset TVD Reference: Offset Datum Reference Depths are relative to 3C-11 @ 82.00ft Coordinates are relative to:3C-11 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927,Alaska Zone 4 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:0.22° Ladder Plot 1200 J 900 0 I I I C I I I e I I Q J J J J J ____J____ w I 1 I I I I a`) 600 U 0 a) J J ____J____ C a) U 300 I I I I I I J J _1 I I I I I I I 1 I 0 I I 0 1500 3000 4500 6000 7500 9000 Measured Depth LEGEND $ 3C-11,3C-11,3C-11 V3 -e- 30-11,3C-11AL1,3G-11AL1 wpO4V0 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 12/13/2012 9:18:43AM Page 6 of 6, A , COMPASS 2003.16 Build 69 t � L0 1 • o WOoooo 0it m o 0 N asM 0 \ o o o _ as FI \\ m Q \\\ m 6 , r1 m G e U M 0 F .,-,p4:.1 :@ i , , , CS ,„ C _ ao lis \ \ y F o b ¢ ^ v /uj cc 1 _ m M 3 r i g1-4 0' _ N g V ,g F. �r 4 0 Tr ''N& ¢ m a o - .O o c < 0 o 7 oN v M rn Li m -�\ 0 e 0 N v k m .-1 0 0 a 4 e Q oa q N 9 8• O Le) 7 mag 0 g o N aoo J mm 0 ._----- _ OW o m• m co 5 a - +' N un €''' § to a U z o 528 o E� ZUI N W <F—W tn1ncr .. �I- mm M F m h 8Rp a' N NNmm2c7-; 2(70 V QS7,7>(2N C 0 _S Ra C U O 0 0 0 0 0 0 0 0 0 0 0 0 O 0 Q m< o o 0 0 0 0 0 0 0 0 0 0 �v ,-G C9-000NNmN mNm NN Q . r v q Y_. m V m '_ M \ m :,-Qr' mo.-000000000000 as--n a3oa,,=t oto 000000 ^ 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TRANSMITTAL LETTER CHECKLIST WELL NAME /c—Lt`,-7 PTD# j ` /� Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: - POOL: �� LU Check Box for Appropriate Letter I 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. 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