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Home My WebLink About215-020C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-12-29_22204_KRU_1L-04B_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22204 KRU 1L-04B 50-029-21179-02 Caliper Survey w/ Log Data 29-Dec-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 215-020 T39914 1/7/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.07 11:12:54 -09'00' From:Wallace, Chris D (CED) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: A-29A (PTD #2152020) High IAP TIFL Failed Date:Wednesday, August 25, 2021 11:24:39 AM From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Tuesday, August 24, 2021 3:54 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Wallace, Chris D (CED) <chris.wallace@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: A-29A (PTD #2152020) High IAP TIFL Failed Mr. Regg, Producer A-29A (PTD #2152020) was reported by operations with 2110 psi inner annulus pressure and failed subsequent TIFL on 08/24/21. The failing TIFL confirms primary barrier failure. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Operations: POP 2. Downhole Diagnostics: Warm TIFL 3. Well Integrity: Further action as needed Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday, February 8, 2018 5:20 AM To: AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS GC1 Field O&M TL <AKOPSGC1FieldOMTL2@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS Well Pad AB <AKOPSWellPadAB@bp.com>; AK, OPS Well Pad CX <AKOPSWellPadCX@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Glasheen, Brian P <Brian.Glasheen@bp.com>; Von Tish, Douglas B <Douglas.VonTish@bp.com> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Romo, Louis A <Louis.Romo@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: OPERABLE A-29A (PTD #2152020) competent barriers, cellar no longer active All, Producer A-29A (PTD #2152020) was made Under Evaluation on 12/02/17 to investigate active bubbling in the cellar. After diagnostics proved the well had two competent barriers, it was put back online on 01/21/18 to monitor. Since the well has been back online, it has not exhibited any indication of bubbling or LEL’s in the conductor. The well meets operability criteria and will now be classified as OPERABLE. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization – Alaska Office: 907-659-8110 From: AK, GWO Well Integrity Engineer Sent: Saturday, January 27, 2018 12:32 PM To: AK, OPS EOC Specialists; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad AB; AK, OPS Well Pad CX; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Glasheen, Brian P; Von Tish, Douglas B Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: UNDER EVALUATION: A-29A (PTD #2152020) Under Evaluation Period Extended - 14 days All, Producer A-29A (PTD #2152020) has been Under Evaluation to diagnose an active cellar. After confirming the competency of two well barriers, the well would not flow on its own with dummy gas lift valves. A coil tubing nitrogen lift also proved to be unsuccessful. On 01/17/18 slickline installed live gas lift valves and on 01/21/18 the well was brought online and to date has not shown any signs of bubbling. Due to the fact it took ~7days for the cellar to become active after it was brought online last time, the Under Evaluation period will be extended for 14 more days to continue monitoring. Plan Forward: 1. DHD: Monitor daily Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization – Alaska Office: 907-659-8110 From: AK, GWO Well Integrity Engineer Sent: Saturday, December 30, 2017 3:12 PM To: AK, OPS EOC Specialists; AK, OPS GC1 Field O&M TL; AK, OPS GC3 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad AB; AK, OPS Well Pad CX; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Glasheen, Brian P; Von Tish, Douglas B Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: UNDER EVALUATION: A-29A (PTD #2152020) Under Evaluation Period Extended All, Producer A-29A (PTD #2152020) was put Under Evaluation on 12/02/17 after it was called in for bubbling in the cellar. On 12/02/17 fullbore performed a passing outer annulus integrity test. On 12/05/17 slickline set dummy gas lift valves and then on 12/06/17 fullbore performed a passing MIT- IA to 2,424 psi. The passing MIT-IA indicates the bubbling is from the thawing of shallow hydrates or a production casing leak to gas only. To rule out the production casing leak to gas, the well needs to be online with a fluid packed inner annulus. Inclement weather delayed the ability to bring the well online and when the weather finally subsided, operations tried to backflow the well to kick off production but it would not flow with dummy gas lift valves and the production tubing loaded with crude. The well will require a coil tubing nitrogen lift to assist in unloading. Because of the weather delay and the unforeseen need for nitrogen lift, the 28 day Under Evaluation clock will be reset to flow and monitor the well. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization – Alaska Office: 907-659-8110 Cell: 307-399-3816 From: AK, GWO Well Integrity Engineer Sent: Saturday, December 02, 2017 6:53 AM To: AK, OPS EOC Specialists; AK, OPS GC1 Field O&M TL; AK, OPS GC3 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad AB; AK, OPS Well Pad CX; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Glasheen, Brian P; Von Tish, Douglas B Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: UNDER EVALUATION: Producer A-29 (PTD #2152020) bubbling in cellar All, Producer A-29 ( PTD #2152020) was called in by operations for active bubbling in the cellar while the well was online. The well has been shut in and well head pressures bled. The well is now classified as Under Evaluation and is on the 28 day clock for diagnostics and repair or secure. The plan forward will be: 1. Fullbore - OA Integrity test 2. Well Integrity Engineer – Additional diagnostics as needed 3. Anchorage Engineer – Evaluate repair Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization – Alaska Office: 907-659-8110 Cell: 307-399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. DATA SUBMITTAL COMPLIANCE REPORT 4/25/2017 Permit to Drill 2150200 Well Name/No. KUPARUK RIV UNIT 1L -04B Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21179-02-00 MD 9635 TVD 6097 Completion Date 2/10/2015 Completion Status 1 -OIL Current Status 1 -OIL UIC No REQUIRED INFORMATION Mud Log No ✓ Samples No ✓ / Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/CCL (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 25399 Digital Data 2/13/2015 Electronic File: 1 L-04 CTD - Laterals NAD27.zip ED C 25399 Digital Data 2/13/2015 Electronic File: 1 L -04B EOW Survey Report - NAD27.pdf ED C 25399 Digital Data 2/13/2015 Electronic File: 1 L -04B EOW Surveys - NAD27.txt Log C 25399 Log Header Scans 0 0 2150200 KUPARUK RIV UNIT 1L -04B LOG HEADERS ED C 25432 Digital Data 7086 9635 2/20/2015 Electronic Data Set, Filename: 11--0413 GAMMA RES.las ED C 25432 Digital Data 2/20/2015 Electronic File: 1L -04B 21VID Final Log.cgm . ED C 25432 Digital Data 2/20/2015 Electronic File: 1L -04B 5MD Final Log.cgm ' ED C 25432 Digital Data 2/20/2015 Electronic File: 1L -04B 5TVDSS Final Log.cgm ED C 25432 Digital Data f 2/20/2015 Electronic File: 1L -04B 2MD Final Log.PDF ED C 25432 Digital Data \0 2/20/2015 Electronic File: 1L-046 51VID Final Log.PDF ED C 25432 Digital Data 2/20/2015 Electronic File: 1L -04B 5TVDSS Final Log.PDF ED C 25432 Digital Data 2/20/2015 Electronic File: 1L -04B EOW Survey Report - ' NAD27.pdf ED C 25432 Digital Data 2/20/2015 Electronic File: 1 L -04B EOW Surveys - . NAD27.csv ED C 25432 Digital Data 2/20/2015 Electronic File: 1 L -04B EOW Surveys - NAD27.txt ED C 25432 Digital Data 2/20/2015 Electronic File: 1 L -04B EOW Surveys - NAD27.xlsx ED C 25432 Digital Data 2/20/2015 Electronic File: 1L-04B_25_tapescan_6H1_CTK ED C 25432 Digital Data 2/20/2015 Electronic File: 1L-04B_5_tapescan_BHI_CTK.txt AOGCC Page] of 2 Tuesday, April 25, 2017 DATA SUBMITTAL COMPLIANCE REPORT 4/25/2017 Permit to Drill 2150200 Well Name/No. KUPARUK RIV UNIT 1L -04B Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21179-02-00 MD 9635 TVD 6097 Completion Date 2/10/2015 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 25432 Digital Data 2/20/2015 Electronic File: 1 L-04B_output.tap ED C 25432 Digital Data 2/20/2015 Electronic File: 1L -04B 2MD Final Log.tiff ED C 25432 Digital Data 2/20/2015 Electronic File: 1L -04B 5MD Final Log.tiff ED C 25432 Digital Data 2/20/2015 Electronic File: 1L -04B 5TVDSS Final Log.tiff Log C 25432 Log Header Scans 0 0 2141580 KUPARUK RIV UNIT 1L -04A LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report L) Production Test Information Y Geologic Markers/Tops D COMPLIANCE HISTORY Completion Date: 2/10/2015 Release Date: 2/3/2015 Description Comments: Directional / Inclination Data l:./ Mechanical Integrity Test Information Y Daily Operations Summary YO Compliance Reviewed By: Date Comments Mud Logs, Image Files, Digital Data Y /,�A� Core Chips Y ANA Composite Logs, Image, Data Files Y Core Photographs Y Cuttings Samples Y / 9 Laboratory Analyses Y NA Date: AOGCC Page 2 of 2 Tuesday, April 25, 2017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS Ing RECEIVED APR 14 2017 Form 10-407 Revised pZ,12,� ��L /2,f/` ED ON REVERSE ®B®MS L_� APR 19 2017toriginalonly 1a. Well Status: Oil ❑ . Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No_ of Completions: Development ❑✓ Exploratory ❑ Service ❑ StratigraphicTest❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: February 10, 2015 215-020 / . 3. Address: 6. Date Spudded:3 L, 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 February,', 2015 50-029-21179-02 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 403' FSL, 144' FEL, Sec. 30, T11N, R10E, UM February 7, 2015 KRU 1L -04B Top of Productive Horizon: 8. KB (ft above MSL): 116' RKB 15. Field/Pool(s): 1483' FNL, 1121' FEL, Sec. 30, T1IN, R10E, UM GL (ft above MSL): 81' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 2247' FSL, 920' FEL, Sec. 30, T1IN, RI OE, UM 9635' MD / 6097' TVD Kuparuk River Oil Pool ' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 539915 Y_ 5949371 Zone -4 9635' MD / 6097' TVD ADL 25659 TPI: x-538908 Y_ 5952760 Zone -4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 539123 Y_ 5951210 Zone -4 nipple @ 502' MD / 502' TVD 2585 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 (f -L' Pv1SL) 3014' MD / 2755' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22, Re-drill/Lateral Top Window MD/TVD GR/CCL 7208' MD / 5977' TVD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM SETTING DEPTH TVD HOLE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 31' 96' 31' 96' 24" 210 sx CS II 9.625" 36# J-55 31' 2343' 31' 2243' 12.25" 830 sx AS III, 250 sx Class G 7" 26# J-55 28' 7625' 28' 6334' 8.5" 600 sx Class G, 150 sx AS 1 2.375" 4.6# L-80 7124' 9635' 5906' 6097' 3" 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/TVD) 3.5" 7134' 6991' MD / 5795' TVD, slotted liner 7613'-9634' MD 6074'-6097' TVD 7106' MD / 5890' TVD, 7118' MD / 5901' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. COMPLETION Was hydraulic fracturing used during completion? Yeso No ❑✓ DATE DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED VERIFIED 2T 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 --> -low Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER-BBLOIL GRAVITY - API(corr) Tess. 24 -Hour Rate -> ?8. CORE DATA Conventional Core(s) Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes ❑ No ❑ f 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 Form 10-407 Revised pZ,12,� ��L /2,f/` ED ON REVERSE ®B®MS L_� APR 19 2017toriginalonly 29. GEOLOGIC MARKERS (List all formations and r, rs encountered): 30. FORMATION TESTS NAME MD TVD Well tested? [] Yes D No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top ground surface ground surface Permafrost - Bottom 3014' 2755' needed, and submit detailed test information per 20 AAC 25.071. Top Kuparuk B1 7276' 6025' Top Kuparuk A6 7520' 6052' Top Kuparuk A5 7605' 6072' Top Kuparuk A4 7660' 6084' Top Kuparuk A4 8705' 6090' Top Kuparuk A5 8939' 6078' Top Kuparuk A5 9008' 6082' Top Kuparuk A4 9560' 6096' N/A Formation at total depth: Kuparuk A4 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic, fianl directional survey 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. 2Il� Contact: Gary Eller @ 263-4172 Email: J.Gary.Eller( conocophillips.com t Printed Name DVerrhasu Title: CTD Engineering Supervisor Signature- Phone 263-4372 Date 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 I L -04B Final Ci® Schematic 16" 62# H-40 shoe @ 96' MD 10-3/4" by 9-5/8" 36# J-55 shoe @ 2343' MD Liner top packer @ 7,118' MD C -sand perfs (sqz'd) 7201'- 7214' M D Modified by RLP 2/11/15 3-1/2" DS Landing Nipple @ 502' MD (2.875" ID) '9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco MMG gas lift mandrel @ 2807, 4387, 5574, 6450, Baker 3-1/2" Locator @ 6961' MD Baker PBR at 6968' MD Baker FHL packer @ 6991' MD (2.96" ID) 1/2" Camco DS landing nipple @ 7043' MD (2.812" min ID) Baker 3-1/2" Locator @ 7090' MD Baker FHL packer @ 7106' MD 3-1/2" Camco D landing nipple @ 7128' MD (2.80" min ID) 1/2" tubing tail @ 7133' MD KOP @ 7208' MD for 'IJ southern laterals -------------------------- -------------------iL-0413, / IL-0413,TD = 9,635' MD 2'/." slotted liner 7,613'-9,635' MD Whipstock at 7230' MD 2-318" solid liner 7,130'-7,613' MD (slipped downhole) __ Seal bore deployment sleeve 7,124' MD KOP @ 7241' MD for northern laterals A -sand perfs (sqz'd) 7316'- 7377' MD1L-04ALIIII,TD = 8,025' MD _— - `- No liner, billet at 8,021' MD Fish: CT under -reamer at Unable to get kicked off 7260'-7283' MD. 7" 26# J-55 shoe @ - --_- ---- 1L-04AP131, TD =10,357' MD 7625' MD INo liner, billet at 8,650' MD V -1L-04AP82, TD = 8,846' MD No liner, billet at 8021' MD I L-04 WELL WORK SUMMARY DATE SUMMARY PRE -RIG WELL WORK 12/24/2014 PUMP 10 BLS. METHANOL THROUGH THE BACK PRESSURE VALVE TO FLUSH SAND OUT. JOB COMPLETE 12/26/2014 LOG 24 ARM CALIPER MAIN AND REPEAT PASS FROM 7266' TO 69501. LOG CORRELATED TO SLB CBL DATED OCT 5 1985. JOB COMPLETE. 1/3/2015 LATE START DUE TO HARDLINE CREW NOT RIGGED UP, RIH TO LOCATE NIPPLE AT 7041' RKB, FLAG PIPE (WHITE), POOH, CHANGE OUT BHA, RESTART IN AM FOR CEMENT SQUEEZE, JOB IN PROGRESS. 1/4/2015 RIH TO FLAG, CORRECT DEPTH TO 7064.70', PUMP 2 ANNULAR VOLUMES OF 120 DEGREE SEAWATER, PUMP 7 BBLS OF 16.5 PPG CLASS G CEMENT, ALLOW 1 HR FOR CEMENT TO SWAP WITH RATHOLE FLUIDS, DROP BALL AND CONTAMINATE TOC TO 7247.7' RKB, F/P TBG TO 4000' RKB, RETURN AFTER 24 HRS TO PUMP 2ND CEMENT BATCH, JOB IN PROGRESS. 1/6/2015 RIH TO LOCATE NIPPLE AT 7041' RKB, CORRECT DEPTH TO 7043.01' (NPL LOCATOR TO END OF BHA), RIH TO TAG TOC AT 7254' RKB, DISCUSS TAG WITH TOWN ENGINEER, DECISION TO TRY JETTING ON CEMENT, MADE IT DOWN TO 7254.7' RKB, PUH TO NIPPLE AT 7041' RKB AND FLAG PIPE (YELLOW), JOB IN PROGRESS. 1/7/2015 RIH TO FLAG @ 7042' CTMD, CORRECT DEPTH TO 7045.99' RKB, CONTINUE TO RIH TAG PBTD AT 7254.5' RKB, LAY IN 13 BBLS OF 16.5 PPG CLASS G CEMENT FROM 7250' RKB TO 6310' RKB, HOLD SQUEEZE PRESSURE OF 1500 PSI FOR 30 MINUTES, CONTAMINTAE CEMENT TO 71 10'RKB, CHASE CONTAMINATED CEMENT OOH AT 70% WHILE MAINTAINING 1:1 RETURNS, WELL LEFT F/P TO 7110' RKB, READY FOR S/L TAG IN 72 HRS, JOB COMPLETE. 1/11/2015 TAGGED TOP OF CEMENT @ 7113' RKB. LEAVE 1100 PSI ON TBG. READY FOR DHC 1/12/2015 (Pre -CTD) ALL TREE VALVED PASSED POSITIVE AND NEGATIVE TESTS Conoc Phillips Time Log & Summary Weliview Web Reporting Report epor` Well Name: 1 L-04 Rig Name: NABORS CDR2-AC .lob Type: DRILLING SIDETRACK Rig Accept: 12/14/2014 3:00:00 AM Rig Release: 12/18/2014 3:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/13/2014 24 hr Summary Complete RD from 1G-08. Move rig to 1L -Pad. MIRU CDR2. 08:00 10:00 2.00 0 0 MIRU MOVE NUND P Complete ND BOPE stack, load tree with methanol, secure wellhead, check tree flange bolts. 10:00 12:00 2.00 0 0 MIRU MOVE RURD P Finish RD. Prep for rig move to 1 L -Pad 12:00 18:00 6.00 0 0 MIRU MOVE MOB P Peak trucks on loaction, pull subs off 1 G-08, clean and inspect wellhead/jobsite. 18:00 20:30 2.50 0 0 MIRU MOVE MOB P Arrive on 1L pad, Remove jeeps, prep cellar area, Spot rig and sub 20:30 00:00 3.50 0 0 MIRU MOVE RURD P Start rig up check list 12/14/2014 Complete BOPE Test, PT PDL's & TT line, Swap out pack offs, Pull BPV 00:00 03:00 3.00 0 0 MIRU MOVE RURD P Continue rig up check list. NU BOP stack, MP line, all tree flange bolts checked, load stack, shell test. Rig Accept: 0:300 on 12/14/14 03:00 14.00 11.00 0 0 MIRU WHDBO BOPE P Perform initial BOP test, 250/4000 psi, 2500 psi annular, test waived by AOGCC (Chuck Scheve) on 12/13/14 at 07:00. 14:00 14:30 0.50 0 0 MIRU WHDBO CTOP P Cut coil and test E -Line, install boot. 14:30 17:00 2.50 0 0 MIRU WHDBO MPSP T PJSM. Pull BPV, Halliburton on location, PJSM. Install ends on Haliburton cable and test real time. NAD NPT 2.5 Hrs for frozen pipeing unable to PT BPV Lubricator 17:00 19:30 2.50 0 0 MIRU WHDBO MPSP P PJSM. Pull BPV, R/D BPV lubricator and load out 19:30 21:30 2.00 0 0 SLOT WELLPF PRTS P PJSM, PT DS PDL and TT Line. Blow down TT line and replace gasket on leaking connection test ODS PDL 21:30 22:30 1.00 0 0 SLOT WELLPF CTOP P PJSM, Replaces packoffs, 22:30 00:00 1.50 0 0 SLOT WELLPF CTOP P PJSM, air previously blown through coil, Start filling coil reversing 12/15/2014 RIH with BHA #1 go down to 7130' little evidence of cement. POOH for BHA #2. Run down to 7180 Midnight depth 00:00 02:00 2.00 0 0 SLOT WELLPF CTOP P Continue filling coil, Test inner reel iron and chart 02:00 02:42 0.70 0 0 SLOT WELLPF CTOP P Bleed off coil, Bleed off wellhead 830 PSI, Unstab Page 1 of 29 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 02:42 03:42 1.00 0 0 SLOT WELLPF CTOP P PJSM - Cut coil back for wire, test wire, Dress coil and install CTC Pull test to 35K 03:42 04:42 1.00 0 0 SLOT WELLPF CTOP P Head up E-Line UQC, PT to 4000 PSI 04:42 05:06 0.40 0 0 SLOT WELLPF SFTY P Hold pre spud with night crew (Corder) 05:06 06:12 1.10 0 52 SLOT WELLPF PULD P M/U BHA #1 with straight motor and 2.98 Bi Center, surface test. 06:12 10:06 3.90 52 6,875 SLOT WELLPF TRIP P RIH wl pilot hole assembly, pumping SW. Tie-in for +2' correction, continue in hole, weight check @ 6,690' 27K. Start seeing stringers @ 6,875'. 10:06 14:48 4.70 6,875 7,126 SLOT WELLPF MILL P Ream down at 1.42 BPM @ 2,725', not much WOB, get PU weight every 1 00'25-27K, drift through DSnipple@ 7,043', continue ream down hole, slowing going through packer @ 7,105', slower going to D nipple @ 7,126'. 14:48 16:18 1.50 7,126 7,120 SLOT WELLPF DLOG P PUH to log tie-in, sent logs town to confirm depth, tie-in to K1 for -6' correction, correct depth to 7,120'. 16:18 16:54 0.60 7,120 7,130 SLOT WELLPF MILL P Continue reaming down hole to 7,128' 16:54 18:18 1.40 7,130 52 SLOT WELLPFTRIP P POOH for BHA#2 18:18 19:18 1.00 52 0 SLOT WELLPF PULD P At surface, PJSM, perform 30 Min no flow test, All good lay down BHA #1 19:18 20:30 1.20 0 62 PROD1 RPEQPI PULD P M/U BHA #2 with .9° AKO motor and 2.79 D331 mill. M/U to coil and surface test. 20:30 22:00 1.50 62 7,040 PROD1 RPEQPITRIP P RIH with BHA#2, EDC closed. Take weight @ 7004 then 7035, Set down @ 7044. PUH bring pumps on to 1 BPM RBIH and see motor work @ 7040 with set down, PUH, PUW=26K bring pumps up to milling rate 1.5 BPM @ 3100 PSI FS 22:00 22:30 0.50 7,040 7,130 PROD1 RPEQPI MILL P Start milling down, Saw nothing after 7044 untill motor work @ 7115, Stall @ 7118', PUW=33K, Second stall @ 7118.6 . PUW=28K, Motor down to 7130. PUH to log K1 22:30 22:48 0.30 7,100 7,130 PROD1 RPEQPIDLOG P Log K1 marker for-5.5' 22:48 00:00 1.20 7,130 7,180 PROD1 RPEQPI MILL P Pumps up to 1.5 BPM @ 3100 PSI FS start working down hole, TF=10ROHS ROP=50 FPH @ 2.3K DHWOB. 7138 looks like cement getting better, 1.7K DHWOB @ 25FPH, 7141 back to 40+ FPH, 7180 Midnight depth 12/16/2014 Mill pilot hole 7,180' to 7,278', logged CCL for TT and "C" sand pert correlation, poor cement quality established, run under reamer BHA #3, ream 7" casing from 7,132' to 7,165' as of midnight. 00:00 00:12 0.20 7,190 PROD1 Continue to mill ahead, still over 40 1 17,180 1 IRPEQPIIMILL IT FPH Page 2 of 29 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:12 00:18 0.10 7,190 7,190 PROD1 RPEQPI WPRT T Pull wiper up to 7085, PUW=26K 00:18 01:48 1.50 7,190 7,256 PROD1 RPEQPI MILL T 7190 Mill Ahead, 1.5 BPM @ 3100 PS FS, BHP=3418, ROP=40 to 50 FPH, Closer to 50 FPH @ 7230'. Setting depth of upper whipstock 01:48 01:54 0.10 7,256 7,256 PROD1 RPEQPI WPRT T 7256 Mini wiper to roll tool off end stop, PUW=28K 01:54 02:36 0.70 7,256 7,278 PROD1 RPEQPI MILL T Mill, 1.5 BPM @ 3100 PSI FS, BHP=3455, ROP=40 FPH, stalled at 7273 twice, Fish in hole is underreamer blade, stalled hard @ 7278 02:36 02:48 0.20 7,278 7,098 PROD1 RPEQPI WPRT T PUH to confirm tie in, PUW=27K 02:48 03:00 0.20 7,098 7,126 PROD1 RPEQPI DLOG T Log K1 for 0 correction 03:00 03:12 0.20 7,126 6,950 PROD1 RPEQPI WPRT T PUH to run CCL log. 03:12 03:30 0.30 6,950 7,270 PROD1 RPEQPI DLOG T Run CCL 6950 to 7260 @ 18 FPM, Estimate 7125 Tail 03:30 03:54 0.40 7,270 6,880 PROD1 RPEQPI WPRT T PUH to dry drift transition area 03:54 04:00 0.10 6,880 7,267 PROD1 RPEQPI WPRT T Dry drift transition area looks good, RBIH to log "C" sand. 04:00 07:30 3.50 7,267 6,950 PROD1 RPEQPI DLOG T PUH log "C" sand, issue with logs, relog "C" sand. Minus -6' correction. 07:30 10:30 3.00 6,750 6,750 PROD1 RPEQPI DLOG T Log to bottom, reset depth +11.5' correction. PUH. 10:30 10:45 0.25 6,750 7,170 PROD1 RPEQPIDLOG T Log CCL 10:45 11:15 0.50 7,170 7,000 PROD1 RPEQPICIRC T Continue in hole to bottom, increase pump rate, clean-out below TT to bottom, PUH at max rate clean-out to TT. 11:15 12:45 1.50 7,000 66 PROD1 RPEQPI TRIP T Continue OOH @ 1.45 bpm, hole cleaning. 12:45 13:15 0.50 66 66 PROD1 RPEQPI OWFF T Flow check on surface, no flow. 13:15 16:00 2.75 66 73 PROD1 RPEQPI PULD T PJSM. LD BHA #2. PJSM. PU/MU BHA #3 under reamer assembly, Weatherford jars, motor and 2 3/8" Reeves under reamer (6") 16:00 17:33 1.55 73 7,115 PROD1 RPEQPITRIP T RIH w/ BHA #3 under reamer assembly, tie-in 17:33 17:48 0.25 7,115 7,144 PROD1 RPEQPI DLOG T Log K1, +3' correction. 17:48 18:18 0.50 7,144 7,134 PROD1 RPEQPITRIP T Pick up hole, PUW 28k, close EDC, RBIH. 18:18 00:00 5.70 7,134 7,165 PROD1 RPEQPI UREM T 7,134', set parameters 1.4 bpm at 3864 psi, 1058 diff, IA 359, OA 56, back ream to 7,132', RIH taking bites, ream out cement in 7" to 7,165', multiple stalls. 12/17/2014 Underream cement in 7" csg from 7,165' to 7,257'. Begin swapping hole over to seawater. 00:00 04:00 4.00 7,165 7,186 PROD1 RPEQPI UREM T 7,165', Continue reaming 7", 1.4 bpm at 3721, CTW 11.3k, WOB .4k to .6k, IA 545, OA 99, pump 5x5 sweep after multiple stalls. Page 3 of 29 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 04:00 08:15 4.25 7,186 7,203 PROD1 RPEQPI UREM T 7,186', Continue reaming 7", 1.4 bpm at 3749, CTW 11 k, WOB .4k to .5k, IA 642, OA 128, pump 5x5 sweep. Several stalls and restarts. 08:15 08:45 0.50 7,203 7,203 PROD1 RPEQPI UREM T Mini wiper 08:45 12:06 3.35 7,203 7,214 PROD1 RPEQPI UREM T 7,203', Continue reaming 7", 1.4 bpm at 3785, CTW 12k, WOB .4k, IA 850, OA 200, pump 5x5 sweep. 12:06 13:18 1.20 7,214 7,214 PROD1 RPEQPI UREM T Wiper/Tie-in, PUW=28K, wait on bottoms up, pumps off, drift through TT, tie-in to K1 +1' correction, log CCL from 7,100' to 7,210'. Pump on, continue in hole. 13:18 15:12 1.90 7,214 7,224 PROD1 RPEQPI UREM T 7,214', Continue reaming 7", 1.43 bpm at 3960, CTW 11.6k, WOB .5k, IA 855, OA 205, 15:12 15:27 0.25 7,224 7,224 PROD1 RPEQPI UREM T Wiper to TT, PUW=28.5, RBIH. 15:27 17:39 2.20 7,224 7,235 PROD1 RPEQPI UREM T 7,224', Continue reaming 7", 1.43 bpm at 3925, CTW 13k, WOB .4k, IA 885, OA 220. 17:39 17:54 0.25 7,235 7,235 PROD1 RPEQPI WPRT T Wiper to TT, PUW 28k, RBIH. 17:54 20:06 2.20 7,235 7,246 PROD1 RPEQPI UREM T 7,235', Continue reaming 7", 1.44 bpm at 3985 psi, CTW 12.9k, WOB .4k, IA 422, OA 213, pump 10x10 sweep. 20:06 20:42 0.60 7,246 7,246 PROD1 RPEQPI UREM T Wiper to TT chasing sweep out, PUW 28k, RBIH. 20:42 22:51 2.15 7,246 7,257 PROD1 RPEQPI UREM T 7,246', Continue reaming 7", 1.46 bpm at 4167 psi, CTW 13k, WOB .4k, IA 450, OA 210, pump 10x10 sweep. 22:51 23:33 0.70 7,257 7,115 PROD1 RPEQPI UREM T Wiper up hole with tie-in, PUW 26k, wait on bottoms up, sweeps out, pumps off, drift through TT. 23:33 23:45 0.20 7,115 7,143 PROD1 RPEQPI UREM T Tie-in to K1 with 0' correction 23:45 00:00 0.25 7,212 RPEQPI UREM IT Pump on, continue in hole pumping 17,143 1 JPROD1 seawater 12/18/2014 Swap hole over to seawater, pressure well up .25 bpm to 1000 psi with .6 bbl, looses of 15 psi every 5 minute for 30 minutes, freeze protect well from 2,500', LD BHA #3, Set BPV. RDMO CDR2. 00:00 01:30 1.50 7,212 7,257 PROD1 RPEQPI UREM T Continue in hole displaceing hole to seawater, Open EDC. 01:30 02:24 0.90 7,257 7,257 PROD1 RPEQPI UREM T Establish injectivity, pump .25 bpm to 1030 psi, bled down to 910 psi in 5 min. bump up to 1000 psi, bled down to 930 psi in 5 min, bump up to 1025 psi, 15 min 980 psi, 30 min 935, BHP 3650 psi, .6 bbl pumped. 02:24 03:45 1.35 7,257 2,500 PROD1 RPEQPI DISP T TOOH pumping seawater, PJSM with LRS, MIRU, PT lines, pump 30 bbl diesel, RDMO LRS. 03:45 04:33 0.80 2,500 73 PROD1 RPEQPI FRZP T 2,500', Freeze protect well to surface. 04:33 08:03 3.50 73 0 PROD1 RPEQPI PULD T PJSM- Un-deploy and LD BHA #3. LD BHA, organize rig floor. Page 4 of 29 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 08:03 11:03 3.00 0 0 DEMOB WHDBO NUND T Jet BOPE, set BPV, 530 psi well, LID FMC lubricator. Pump inhibitor, flush and purge coil/rig. Pre -Spud for 1 H-04 @ 10:30. 11:03 13:00 1.95 0 0 DEMOB WHDBO RURD T Offload pits. RD MP eqipment and misc. lines cellar/ TT lines. 13:00 15:00 2.00 0 0 DEMOB WHDBO NUND T Continue to prep for rig move to 1 H -Pad. ND BOPE stack, secure stack. Load tree with Methanol, check tree flange bolts with sweeny, secure wellhead. Rig Release: 12/18/14 @ 15:00 12/19/2014 Inactive 00:00 00:00 1 0.01 0 DEMOB MOVE RURD T Inactive 01/14/2015 Complete RD at IE -14 and prep for rig move to IL Pad. Pull subs off of 1E, clean & inspect wellhead and jobsite. 15:00 20:00 5.00 0 0 MIRU MOVE RURD T Finish RD. Prep for rig move to 1L Pad. 05:00 07:18 2.30 0 0 MIRU MOVE MOB T Peak trucks on location. PJSM. Move shop first to 1 L Pad. 07:18 07:45 0.45 0 0 MIRU MOVE SFTY T PJSM for using CATS in Pits. 07:45 09:00 1.25 0 0 MIRU MOVE MOB T Pull subs off location and move towards 1 L Pad. 01/15/2015 Complete RD from 1 E-14. Move rig over to 1 L Pad. MIRU CDR2. Perform initial BOPE test (waived by John Crisp, AOGCC) RU BPV equipment. 00:00 04:00 4.00 0 0 MIRU MOVE MOB T Move subs over to 1 L Pad from 1 E-14. 04:00 07:30 3.50 0 0 MIRU MOVE MOB T Arrive on 1L Pad. Remove jeeps, prep cellar area, spot rig and sub. Release Peak Trucks. 07:30 11:00 3.50 0 0 MIRU MOVE RURD T Start Rig Up Checklist. RU TT lines ***Rig Accept @ 11:00 am on 1-15-15- 11:00 14:00 3.00 0 0 MIRU WHDBO RURD T NU BOPE stack, MP line, all tree flange bolts checked (crooked tree, several bolts tightened to spec.,1 hr, rechecked after BOP NU, 30 min), grease tree, stack and manifold. Load surface lines and stack, shell test. 14:00 22:30 8.50 0 0 MIRU WHDBO ROPE T Perform initial BOPE test, 250/4000 psi, 2500 psi annular, test waived by AOGCC (John H Crisp) on 1/14/15 @ 9:04 am. 22:30 23:00 0.50 0 0 MIRU WHDBO PRTS T Pressure test tiger tank line to 1500psi. 23:00 00:00 1.00 0 0 MIRU WHDBO MPSP T PJSM, Load/RU BPV lubricator, PIT lubricator to 1500 psi. 1/16/2015 Pull BPV. Perform slack managment, cut 430 -ft coil, re -head and test. MU BHA #4, Mill pilot hole from 7,115 -ft to 7,258 -ft averageing 18 fph, casing contact is at 7,141.6 -ft. Milling in progress. Page 5 of 29 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 01:00 1.00 0 0 MIRU WHDBO MPSP T Pull BPV, WHP 550, RD and load out the FMC lubricator. 01:00 04:30 3.50 0 0 SLOT WELLPF CTOP T PJSM, remove CTC and BHI UQ, dress e-line, line up to break circulation, perform slack mangement, R/U hydraulic CT cutter, cut 30-ft of coil to find wire, cut 430-ft coil total. 04:30 05:30 1.00 0 0 SLOT WELLPF CTOP T PJSM- install CTC, Pull test to 35K 05:30 09:54 4.40 0 0 SLOT WELLPF CTOP T Test E-line, Head up E-line to Upper guick connect and retest wire, PT connector to 4000PS1. Pump slack forward. Pressure test PDL's. 09:54 10:24 0.50 0 0 SLOT WELLPF OVVFF T Perform No-Flow test. Good test. 10:24 10:36 0.20 0 0 PROD1 RPEQPI SFTY T PJSM for M/U Milling BHA. 10:36 11:36 1.00 61 61 PROD1 RPEQPI PULD T M/U BHA #4 and stab on well. 11:36 12:45 1.15 61 6,636 PROD1 RPEQPITRIP T Open swab and RIH pumping 1 bpm. WHP = 80 CP = 1,196 psi IA = 15 OA=O 12:45 13:09 0.40 6,636 6,695 PROD1 RPEQPI DLOG T Log for tie in to marker at 6,647'. Make correction of 4. 13:09 13:27 0.30 6,695 7,006 PROD1 RPEQPITRIP T Continue RIH. Pumping SW @ 1 bpm WHP = 65 psi IA = 220 psi OA = 0 psi 13:27 13:48 0.35 7,006 7,006 PROD1 RPEQPI CIRC T Stop at 7,006' and continue to pump milling fluid ( 6% KCL brine viscosified w/1.5 ppb PowerVis) till at the nozzle. 13:48 14:00 0.20 7,006 7,115 PROD1 RPEQPITRIP T Close EDC and continue RIH until motor work seen or tag cement. 14:00 15:00 1.00 7,115 7,130 PROD1 RPEQPIMILL T Tag cement@ 7,115.0. PUH and then RIH to start drilling pilot hole. 1.5 bpm WHP = 24 psi IA = 270 psi OA=O *1st hour average ROP = 15 fph WOB = 2.00 15:00 16:00 1.00 7,130 7,142 PROD1 RPEQPIMILL T Continue drilling pilot hole. 1.5 bpm WHP = 24 psi IA = 350 psi OA = 0 2nd hour average ROP = 11 fph WOB = 2.00 16:00 17:00 1.00 7,142 7,147 PROD1 RPEQPI MILL T Continue drilling pilot hole. 1.5 bpm WHP = 24 psi IA = 490 psi OA = 4 3rd hour average ROP = 6.7 fph WOB = 2.00 'Note: ROP decreased dramatically and WOB increased at 7,141.6. Page 6 of 29 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 17:00 18:00 1.00 7,147 7,166 PROD1 RPEQPI MILL T Continue drilling pilot hole. 1.5 bpm WHIP = 53 psi CP = 3,678 psi IA = 500 psi OA = 4 psi 4th hour average ROP = 18.5 fph WOB = 1.90 18:00 19:00 1.00 7,166 7,183 PROD1 RPEQPI MILL T 7,166 -ft, Continue drilling pilot hole 1.48 bpm at 3,651 psi, WHP 70 psi, IA 550 psi, OA 4 psi, ROP 17.3 fph, WOB 1.90k 19:00 20:00 1.00 7,183 7,199 PROD1 RPEQPI MILL P 7,183 -ft, Continue drilling pilot hole, 1.48 bpm at 3,656 psi, WHP 70 psi, IA 627 psi, OA 16 psi, ROP 16.1 fph, WOB 1.70k 20:00 21:00 1.00 7,199 7,211 PROD1 RPEQPI MILL P 7,199 -ft, Continue drilling pilot hole, 1.48 bpm at 3,650 psi, WHP 71 psi, IA 680 psi, OA 24 psi, PUH 60 -ft at 7,202 -ft, PUW 28k, average 12.4 fph, WOB 1.70k 21:00 22:00 1.00 7,211 7,230 PROD1 RPEQPI MILL P 7,211 -ft, Continue drilling pilot hole 1.48 bpm at 3,720 psi, WHP 71 psi, IA 720 psi, OA 34 psi, ROP 19 fph, WOB 1.9k. ** Bled IA down from 750 psi to 240 psi 22:00 23:00 1.00 7,230 7,249 PROD1 RPEQPI MILL P 7,230 -ft, Continue drilling pilot hole 1.48 bpm at 3,757 psi, WHP 90 psi, IA 241 psi, OA 34 psi, ROP 18 fph, WOB 1.9k 23:00 23:45 0.75 7,249 7,258 PROD1 RPEQPI MILL P 7,249 -ft, Continue drilling pilot hole 1.48 bpm at 3,749 psi, WHP 66 psi, IA 290 psi, OA 41 psi, WOB 1.9k. Stall at 7,251.46 -ft, PUW 29.5k, RBIH, continue to mill to stall at 7,258.14 -ft. 23:45 00:00 0.25 7,258 7,020 PROD1 RPEQPI WPRT P 7,258 -ft, Pull wiper to 7,020 -ft, PUW 28k 1/17/2015 Complete milling pilot hole from 7,258 -ft to 7,265 -ft at -6 fph, little to no motor work to TD at 7,280 -ft. Ream transition area. TOOH. Ran Halliburton real time caliper from 7,265 -ft to 6,700 -ft, good data. MU / RIH with Baker whipstock. 00:00 00:15 0.25 7,020 7,258 PROD1 IRPEQPIVVPRT P 7,020 -ft, RBIH with Pilot Hole BHA #4 00:15 01:42 1.45 7,258 7,280 PROD1 RPEQPI MILL P 7,258 -ft, BOBD pilot hole 1.48 bpm at 3,448 psi, no motor work to 7,261 -ft, drill 1.48 bpm at 3,733 psi, WHP 87 psi, IA 324 psi, OA 50 psi, ROP 6 fph, WOB 1.9k to stall at 7,265 -ft, PUW 32k, RBIH, little to no motor work to 7,280 -ft, ROP 65 to 75 fph. 0142 01:57 0.25 7,280 7,080 PROD1 RPEQPITRIP P 7,280 -ft, PUH to confirm tie in. 01:57 02:15 0.30 7,080 7,150 PROD1 RPEQPI DLOG P Log K1 marker, -1 correction 02:15 02:27 0.20 7,150 7,275 PROD1 RPEQPITRIP P Pumps down, dry drift to 7,275 -ft Page 7 of 29 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 02:27 04:27 2.00 7,275 7,020 PROD1 RPEQPI REAM P 7,275-ft, PUH (29k) and ream transition area at 170 TF, 5 passes up/dowm 1/5 fpm, drift area clean. 04:27 05:57 1.50 7,020 73 PROD1 RPEQPITRIP P TOOH with BHA #4. 05:57 06:36 0.65 73 73 PROD1 RPEQPI OWFF P At surface. Commence No-Flow test. No Flow Test fails. 06:36 06:51 0.25 73 73 FROM RPEQPI SFTY P PJSM for pressure undeploy procedures. 06:51 08:45 1.90 73 0 PROD1 RPEQPI PULD P Begin pressure undeploy and L/D BHA #4. ****Note: Bit still gauged at 2.80" after milling run. 08:45 09:30 0.75 0 0 PROD1 RPEQPI WASH P Put on JSN and jet BOP Stack and I choke at surface. 09:30 10:09 0.65 0 0 FROM RPEQPI PULD P Finish jetting BOP stack. Pop off well and remove nozzle. 10:09 10:21 0.20 0 0 PROM RPEQPI SFTY P PJSM with Halliburton for making up BHA #5. 10:21 11:45 1.40 22 22 PROM RPEQPI PULD P M/U BHA #5 (Caliper Run). Test Halliburton tools. Short in system .................... 11:45 13:03 1.30 22 22 PROD1 RPEQPI PULD T Trouble shoot electrical short in Halliburton's tool string. Short found in plug at J-Box. Repairs made. 13:03 13:45 0.70 22 22 FROM RPEQPI PRTS T Stab on well. Unable to pump through coil..................troubleshoot............. 13:45 15:36 1.85 22 7,050 PROM RPEQPI TRIP P Open swab and TIH @ 75 fpm (and slower through jewelry.....) 15:36 16:00 0.40 7,050 7,227 PROM RPEQPI DLOG P Log for correction at K1 marker. Make correction of 4 16:00 16:09 0.15 7,227 7,269 PROM RPEQPITRIP P Continue down to 7,269' before logging up. Pumping @.40 bpm WHP = 599 psi CP = 2,119 psi IA = 0 psi OA =0psi 16:09 16:42 0.55 7,269 6,700 PROM RPEQPI DLOG P @ 7,269' and begin logging up.................. 16:42 16:57 0.25 6,700 7,265 PROM RPEQPITRIP P @ 6,700'. TBIH to log again........... 16:57 17:24 0.45 7,265 6,700 FROM RPEQPI DLOG P @ 7,265' stop and begin logging up to 6,700' a second time......... Pumping @.40 bpm WHP = 574 psi IA = 5 psi OA = 0 psi CP = 2,536 psi 17:24 19:03 1.65 6,700 22 PROM RPEQPITRIP P @ 6,700'. Second logging run completed. TOOK data sent to town forvinterpretation. 19:03 20:03 1.00 22 0 PROD1 RPEQPI PULD P PJSM- Undeploy, LD Halliburton caliper, BHA #5. Page 8 of 29 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 20:03 21:03 1.00 0 0 PROD1 RPEQPI PULD P PJSM- Bring in and set up whipstock assembly, e-mail from town set top of whipstock at 7,240 -ft, 10° LOHS as planned 21:03 23:12 2.15 0 74 PROD1 RPEQPI PULD P PJSM- MU whipstock BHA #6, deploy BHA, make up to coil track tools, surface test, not working, clean up connection at collector, good. 23:12 00:00 0.80 74 2,825 PROD1 RPEQPITRIP P RIH with Baker 10.49-ftX 2.625" OD Mono Bore XL Whipstock w/ cement slips BHA #6, EDC open. 1/18/2015 Set whipstock w/ top at 7,240 -ft, TF 10° LOHS. Swap hole over to milling fluid. TOOK Undeploy BHA #6, Deploy BHA #7. Mill window exit 7,240 -ft to 7,246 -ft, rathole to 7,261 -ft. 00:00 01:03 1.05 2,825 7,085 PROD1 RPEQPITRIP P Continue RIH with BHA#6 whipstock assembly. 01:03 01:30 0.45 7,085 7,135 PROD1 RPEQPI DLOG P Log K1 marker, -5-ft correction, close EDC, PUW 33k 01:30 01:48 0.30 7,135 7,251 PROD1 RPEQPI WPST P RIH to set depth of 7,250.49 -ft, TOWS @ 7,240 -ft, oriented to 10° LOHS, PU to neutral, kick pumps on, see tool shift @ 4700 PSI, Set down 3K, open EDC. 01:48 02:48 1.00 7,251 7,200 PROD1 RPEQPI DISP P PUH to TT, PUW 33k, swap hole over to 9.6 ppg window milling fluid. 02:48 04:18 1.50 7,200 74 PROD1 RPEQPITRIP P POOH with BHA#6 04:18 06:00 1.70 74 0 PROD1 RPEQPI PULD P PJSM- Undeploy, LD BHA #6 06:00 07:00 1.00 0 69 PROD1 WHPST PULD P M/U BHA #7 (Window mill). Both string mill and window mill no-go @ 2.79" 07:00 08:12 1.20 69 69 PROD1 WHPST PULD P PJSM - Pressure Deploy. 08:12 09:57 1.75 69 7,023 PROD1 WHPST TRIP P Open swab and TIH. Pumping @ 2.47 bpm WHP = 603 psi CP = 1,703 psi IA = 0 psi OA = 0 psi 09:57 10:18 0.35 7,023 7,126 PROD1 WHPST DLOG P Stop @ 7,023' and shut in pump and close EDC. Begin logging for tie-in at K1 marker. Correction of -5'. 10:18 10:27 0.15 7,126 7,240 PROD1 WHPST WPST P Tag whipstock @ 7,240.6' PUH several feet and bring pump on @ 1.45 bpm. RBIH to whipstock and begin milling. VVOB = 1.96 Page 9 of 29 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 10:27 15:33 5.10 7,240 71245 PROD1 WHPST WPST P First stall. PUH and RBIH to continue milling. Progress being made milling ........................... 1.5 bpm WHP = 73 psi CP = 3,881 psi IA= 101 psi OA = 9 psi ROP = 1.0 fph WOB = 2.0 eventually increasing to 3.0 15:33 19:51 4.30 7,245 7,248 PROD1 WHPST WPST P Still milling................ROP as fallen off for quite sometime now.............very sl00000w drilling ......... 1.5 bpm WHP = 72 psi CP = 3,812 psi IA = 199 psi OA = 22 psi ROP =<0.6fph WOB = 3.42 19.51 21:45 1.90 7,248 7,251 PROD1 WHPST WPST P 7,247.6 -ft, Time milling 2 fph 1.46 bpm at 3753 psi, WOB .6k, WHP 69, IA 309, OA 51 ***Note: Bottom of window at 7,246 -ft 21:45 00:00 2.25 7,251 7,262 PROD1 WHPST MILL P 7,250.6 -ft, Drill rathole 1.45 bpm at 3843 psi, WOB 2.3k, WHP 66, IA 352, OA 66 01/19/2015 Back ream window ±30° from as drilled TF. Drifted clean. TOOK Undeploy BHA #7. Deploy BHA #8. Bit stuck at 7,299 -ft. Pulled free. Baker Coil Track EDC tool error. TOOK Undeploy BHA #8, Attempt to deploy BHA #9, stuck in PDL, freed up. Continue deploy BHA 49. 00:00 01:57 1.95 7,262 7,262 PROD1 WHPST REAM P 7,261.5 -ft, TD rathole, ream window exit ±30° TF from as milled TF. Drift window clean to 7,261.5 -ft. 01:57 03:15 1.30 7,262 75 PROD1 WHPST TRIP P POOH with BHA #8, PUW 24k 03:15 05:30 2.25 75 0 PROD1 WHPST PULD P PJSM- Undeploy and LD BHA #7, checks not holding, scope change safety meeting, power up tools, close EDC, power down tools, gauged mill 2.79" go. 05:30 06:00 0.50 0 0 PROD1 DRILL SVRG P Service injector, equipment. 06:00 08:42 2.70 0 74 PROD1 DRILL PULD P PIU BHA #8, build section BHA w/1.8 degree AKO motor and rebuilt bi-center bit. Surface test and pressure deploy. 08:42 10:06 1.40 74 7,035 PROD1 DRILL TRIP P TIH to start drilling build section. EDC is open. 10:06 10:24 0.30 7,035 7,123 PROD1 DRILL DLOG P Start logging for tie-in at K1. Correction of -6' made. Close EDC. 10:24 10:36 0.20 7,123 7,262 PROD1 DRILL TRIP P Continue TIH to rat hole TD. Window looks good - no issues. Page 10 of 29 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 10:36 12:06 1.50 7,262 7,299 PROM DRILL DRLG P At rat hole TD ............ start drilling build section. Pumping @ 1.42 bpm CP = 4,046 psi IA = 148 psi OA = 11 psi 12:06 13:39 1.55 7,299 7,299 PROM DRILL DRLG P Having difficulty getting back down to 7,299' after PUH a few feet. Hanging up around 7,295' probably bad shale. After numerous stalls finally able to get back to 7,299' and drill beyond to 7,303.7' before getting stuck. 13:39 15:45 2.10 7,299 7,089 PROD1 DRILL DRLG T Stuck -Stuck. Confer with town engineers for plan forward. Pumped down the backside, free pipe and pull up to inside the tubing above the cement. Open ECD. Pump sweeps bottoms up. 15:45 15:51 0.10 7,089 7,123 PROM DRILL DLOG P RBIH and log at the K1 marker. Make correction of+3'. 15:51 16:03 0.20 7,123 7,123 PROD1 DRILL TRIP P RBIH about 20' or so and pump a Hi/Lo Vis sweep and PUH just outside the window and wait on bottoms up. Close EDC @ 7,219' 1.35 bpm WHP = 166 psi IA = 249 psi OA = 37 psi 16:03 18.15 2.20 7,123 72 PROM DRILL TRIP T EDC got an error message; would not close. POOH to swap out EDC. 18:1520:45 2.50 72 0 PROM DRILL PULD T PJSM- Undeploy and LD BHA #8, change out float valves, inspect tools. 20:45 23:45 3.00 0 72 PROM DRILL PULD T PJSM- MU BHA #9, 1.88° AKO motor with reconditioned HYC Bi -center bit. Attempt to deploy BHA, stuck in tree, appeared to get to no --go, BHA stuck spaceing out, freed up surging well while working wire. 23:45 00:00 0.25 72 72 PROM DRILL SFTY T PJSM- Confirm valves and where were at on check list. Note: Daily losses, 23 bbls of 9.5 FloPro 1 /20/2015 Deploy BHA #9, stripped off, annular element appeared damaged, Undeploy, inspect and cycle bag, good. Re -deploy BHA #9. RIH. POOH. Test and Chart Annular bag, good. Deploy BHA #10. Drill build, TD at 7,515 -ft. TOOK Undeploy BHA #10. Deploy BHA #11. 00:00 00:30 0.50 72 0 PROM DRILL PULD T Deploy BHA #9, strip off PDL, check down BOPE, annular element appears to have chunk of rubber sticking into BOP, make calls, decision made to check out element. 00:30 03.00 2.50 0 0 PROD1 DRILL PULD T PJSM- Undeploy and LD BHA 49, inspect element, cycle bag around test joint, bag functioning properly, element in workable shape. Page 11 of 29 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 03:00 03:51 0.85 0 72 PROD1 DRILL PULD T PJSM- Re-deploy BHA #9, no problem to no-go or space out, strip off. 03:51 04:42 0.85 72 72 PROD1 DRILL PULD T Make up to coil track, surface test. 04:42 05:30 0.80 72 2,345 PROD1 DRILL TRIP T RIH with BHA #9, 1.88° AKO motor and reconditioned NYC Bi-center bit. 05:30 06:24 0.90 2,345 74 PROD1 DRILL TRIP T Confer with town engineers and decision made to POOH and test bag. 06:24 08:24 2.00 74 0 PROD1 DRILL PULD T At surface. PJSM for undeployment. Undeploy. 08:24 09:00 0.60 0 0 PROD1 DRILL BOPE T Prep for and Start Annular Preventer Test. 09:00 09:15 0.25 0 0 PROD1 DRILL BOPE T End Annular Preventer Test. Both low and high pressure test passed. Two skid marks about 180 degrees apart seen on bag, some thin rubber peices like coating seen on upper portion of element. Bags opened fully. Element looks like it has normal wear. 09:15 10:30 1.25 0 72 PROD1 DRILL PULD T M/U and Deploy build section BHA# 10 10:30 12:00 1.50 72 7,110 PROD1 DRILL TRIP T RIH, with 1.88 AKO motor and RR bi-center bit 1-1. 12:00 12:15 0.25 7,110 7,125 PROD1 DRILL DLOG T 711 Oft, Tie into the K1 marker correction of - 5. Oft. 12:15 12:30 0.25 7,125 7,305 PROD1 DRILL TRIP T Close EDC, Continue RIH through cement pilot, pumping 5x5 sweep 12:30 16:00 3.50 7,305 7,460 PROD1 DRILL DRLG P 7304ft, OBD 1.4bpm at 3500psi. BHP 3717, WHP 175, IA 158, OA 3 16:00 16:30 0.50 7,460 7,460 PROD1 DRILL WPRT P 7460ft, Wiper up hole to 7300ft, PUW24K, RIW 11k 16:30 17:18 0.80 7,460 7,515 PROD1 DRILL DRLG P 7460ft, BOBD 1.41 bpm at3700psi, BHP 3775, WHP 149, IA 294, OA 31 17:18 19:27 2.15 7,515 72 PROD1 DRILL TRIP P 7,515-ft, Build TD called. POOH with BHA #10, Jog well at surface, choke plugging off, Frac Sand across shaker. 19:27 21:15 1.80 72 0 PROD1 DRILL PULD P PJSM- Undeploy and LD BHA #10, Bit condition 1-1-PN-N-X-I-N0-BHA. 21:15 22:00 0.75 0 0 PROD1 DRILL BOPE P PJSM- PU Test joint, Function test BOP, LD test joint 22:00 00:00 2.00 0 69 PROD1 DRILL PULD P PJSM- MU Drilling BHA#11, RSM with New HYC Bi-center bit, deploy, replace checks, change out pack-offs, MU to coil track, surface test. 01/2112015 Drill ahead A lateral from 7,515-ft to 8,498-ft. 00:00 01:54 1.90 69 7,100 PROD1 DRILL TRIP P RIH with BHA #11, Close EDC, PUW 27k. 01:54 02:24 0.50 7,100 7,280 PROD1 DRILL DLOG P Tie into the K1 marker with correction of-4-ft. Continue RIH, clean thru cement pilot and window. Log RA marker at 7,248.5-ft Page 12 of 29 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 02:24 03:18 0.90 7,280 7,516 PROD1 DRILL TRIPP Continue RIH with RSM BHA to TD, PUH 28k, flush choke, RBIH. 03:18 06:00 2.70 7,516 7,715 PROD1 DRILL DRLG IP 17,516 -ft, OBD 1.42 bpm at 3690 psi. BHP 3717, WHP 123, IA 143, OA 2 06:00 07:00 1.00 7,715 7,715 PROD1 DRILL WPRT P 7715ft, Wiper up hole to 7350ft, PUW 25k, RIW 10k 07:00 09:15 2.25 7,715 7,915 PROD1 DRILL DRLG P 7715ft, BOBD 1.41bpm at3640psi, BHP 3810, WHP 168, IA 474, OA 68 09:15 10:15 1.00 7,915 7,915 PROD1 DRILL WPRT P 7915ft, Wiper up hole to 7260ft, PUW 26k RIW 10k 10:15 13:15 3.00 7,915 8,115 PROD1 DRILL DRLG P 7915ft, BOBD 1.5bpm at3800psi, BHP 3817, WHP 141, IA 531, OA 91 13:15 14:00 0.75 8,115 7,260 PROD1 DRILL WPRT P 8115ft, Wiper up hole for tie in, PUW 25k 14:00 14:15 0.25 7,262 7,278 PROD1 DRILL DLOG P 7260ft, Tie into the RA marker correction of minus 1.5ft. 14:15 14:45 0.50 7,278 8,115 PROD1 DRILL WPRT P 7278ft, continue wiper in hole.RlW 10k 14:45 16:45 2.00 8,115 8,315 PROD1 DRILL DRLG P 8115ft, BOBD 1.5 bpm at 3640 psi, BHP 3778, WHP 137, IA 709, OA 178 16:45 17:45 1.00 8,315 8,315 PROD1 DRILL WPRT P 8315ft, Wiper up hole to 7350ft, PUW 26k, RIW 17:45 00:00 6.25 8,315 8,498 PROD1 DRILL DRLG P 8315ft, BOBD 1.5 bpm at 3945 psi, BHP 3822, WHP 150, IA 750, OA 180, couple of BHA wipers, drilling ankerite stringers from 8,372 -ft. Note: Bled IA down to 250 psi. 01/22/2015 Drill ahead A lateral from 8,498 -ft to 9,120 -ft. 00:00 00:42 0.70 8,498 8,503 PROD1 DRILL DRLG P 8,498 -ft, OBD 1.5 bpm at 4045 psi, BHP 3840, WHP 139, IA 350, OA 208, ankerite and weight transfer issue, pull early wiper 00:42 01:15 0.55 8,503 7,400 PROD1 DRILL WPRT P 8,503 -ft, Wiper up hole to 7,400 -ft. PUW 24k, sample from 8,500 -ft 85% ankerite. 01:15 01:48 0.55 7,400 8,503 PROD1 DRILL WPRT P 7,400 -ft, Wiper in hole. RIW 10.5k 01:48 07:18 5.50 8,503 8,710 PROD1 DRILL DRLG P 8,503 -ft, OBD 1.5 bpm at 4066 psi, BHP 3838, WHP 131, IA 330, OA 212, lots of Ankerite. Note: Mud swap, 8,531 -ft new 9.6 ppg PWrPr0 at bit 0718 08:18 1.00 8,710 7,715 PROD1 DRILL WPRT P 871 Oft, Wiper up hole for tie in. PUW 24k 08:18 08:33 0.25 7,715 7,732 PROD1 DRILL DLOG P 7715ft, tie into the formation marker at 7700ft, correction of plus 1.Oft. 08:33 09.03 0.50 7,732 8,710 PROD1 DRILL WPRT P 7732ft, Continue wiper in hole. RIW 10k Page 13 of 29 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 09:03 11:03 2.00 8,710 8,730 PROD1 DRILL DRLG P 871 Oft, BOBD 1.5bpm at 3500psi, BHP 3834, W -IP 215, IA 76, OA 55 *" Note: Started taking losses from 8720ft 0.5bpm to 1.Obpm. PUW 31 k, Continue drilling ahead to heal up loss zone. 11:03 16:33 5.50 8,730 8,920 PROD1 DRILL DRLG P 8730ft, OBD 1.5 bpm at 3721 psi, BHP 3831, WHP 124, IA 154, OA 82 **** Note: Talked with town and decision was made to lower ECD's at the window from 11.8 to 11.7. 16:33 17:36 1.05 8,920 7,365 PROD1 DRILL WPRT P 8920ft, Wiper up hole to 7365ft, PUW 25k Note: Pressure survey from 7,375 to 7,365 -ft, 1.4 bpm at 3,356 psi, BHP 3717 psi, ECD 12.0 ppg 17:36 18:24 0.80 7,365 8,920 PROD1 DRILL WPRT P 7,365 -ft, Wiper in hole, RIW 9k 18:24 23:03 4.65 8,920 9,120 PROD1 DRILL DRLG P 8,920 -ft, OBD 1.5 bpm at 3708 psi, BHP 3837, WHP 167, IA 235, OA 124 23:03 23:39 0.60 9,120 7,920 PROD1 DRILL WPRT P 9,120 -ft, Wiper up hole to 7,920 -ft. PUW 28k 23:39 00:00 0.35 7,920 8,615 PROD1 DRILL WPRT P Wiper in hole, RIW 9k D1/23/2015 Drill ahead A lateral from 9,120 -ft to 9,235 -ft, Unable to pass fault. TOOK Bit in poor condition. MU RSM BHA #12, Deploy/RIH with BHA #12 00:00 00:18 0.30 8,615 9,120 PROD1 DRILL WPRT P Continue Wiper in hole, RIW 9k 00:18 04:06 3.80 9,120 9,149 PROD1 DRILL DRLG P 9,120 -ft, OBD 1.5 bpm at 3742 psi, BHP 3853, WHP 137, IA 320, 183, 04:06 06:06 2.00 9,149 9,230 PROD1 DRILL DRLG P 9149ft, Started losing 0.5bpm PUW 26k, Drill ahead 9232ft stall motor, PUW 34k, sticky, BOBD 1.5bpm at 3545psi, BHP 3913, WHP 109, IA 303, OA 176 06:06 07:06 1.00 9,230 9,230 PROD1 DRILL DRLG P 9232ft, Work coil trying to drill ahead, trouble getting back to bottom, stacking and stalling motor, 07:06 1106 4.00 9,230 9,230 PROD1 DRILL DRLG P 9232ft, discuss with town team on plan foward **** Note: Make up 39bbl high lube pill try and drill ahead, 9232ft, OBD 1.3bpm at 3150psi, BHP 3882, WHP 14, IA 282, OA 159 11:06 12:06 1.00 9,230 7,375 PROD1 DRILL WPRT P 9235ft, Wiper up hole, PUW 26k 12:06 12:36 0.50 7,375 9,230 PROD1 DRILL WPRT P 7375ft, Wiper back in hole RIW 9k 1236 14:36 2.00 9,235 9,230 PROD1 DRILL DRLG P 9235ft, BOB trying to drill with a beaded pill, pumping 1.3bpm at 3300psi, BHP 3841, WHP 129, IA 264, OA 158, try to drill ahead unsuccessfull, stacking at 9233.8', Page 14 of 29 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 14:36 16:36 2.00 9,230 69 PROM DRILL TRIP T POOH, to check bit and BHA, perform jog from 7330' down to 7500', continue POOH through window, open EDC, continued POOH pumping max rate to clean hole. 16:36 18:06 1.50 69 0 PROD1 DRILL PULD T PJSM - undeploy RibSteer BHA, 18:06 20:30 2.40 0 0 PROD1 DRILL PULD T PJSM- LD BHA #11, Bit condition 2-3-BT-A-X-1-CT-PR, 2 plugged nozzles and pilot begining to ring out, RSM motor appears in good shape, confer with town, MU RSM assembly (68 hrs, 2 stalls, new style seals installed) 20:30 21:51 1.35 0 0 PROM DRILL PULD T PJSM- Deploy BHA 412, RSM motor #2 with New HYC Bi-center bit (Stay Sharp cutters) MU to CoilTrak, surface test. 21:51 23:24 1.55 0 7,100 PROM DRILL TRIP T RIH with BHA #12. pumps off, close EDC, PUW 23k prior to entering cement pilot hole. 23:24 23:42 0.30 7,100 7,260 PROM DRILL DLOG T Log K1 marker, correction of minus 4-ft, continue in hole pumps off until] out window. 23:42 00:00 0.30 7,260 7,955 PROM DRILL TRIP T Continue in hole with BHA#12 Note : Lost 47 bbl Pwr Pro in last 24 hours. 01/24/2015 Drill ahead A lateral from 9,235-ft to 9,830-ft. Ankerite. 00:00 00:45 0.75 7,959 9,230 PROD1 DRILL TRIP T Continue in hole with BHA #12 00:45 06:33 5.80 9,230 9,270 PROM DRILL DRLG P 9,230-ft, BOBD 1.5 bpm at 3736 psi, BHP 3834, WHP 80, IA 0, OA 0, Stall at 9,230-ft, PU and drill 15 fph to stalll at 9,242-ft, PUW 31 k, stacking at multiple spots from 9,228 -ft to 9,239-ft, different place each time, RBIH 15 fph from 9,230-ft to 9270ft. 06:33 07:48 1.25 9,270 9,430 PROM DRILL DRLG P 9270ft, OBD 1.5 bpm at 3700 psi, BHP 3884, WHP 43, IA 202, OA 65, looks like we broke out of hard area, ROP 150fph, w/1.6k WOB. Continue drilling ahead from 9270ft to 07:48 09:18 1.50 9,430 9,430 PROM DRILL WPRT P 9430ft, Wiper up hole to 8200ft. PUW 25k, RIW 10k 09:18 11:18 2.00 9,430 9,630 PROD1 DRILL DRLG P 9430ft, BOBD 1.5 bpm at 3730psi, BHP 3880, WHP 48, IA 273, OA 122, 11:18 12:18 1.00 9,630 9,630 PROM DRILL WPRT P 9630ft, Wiper up hole to 8430ft, PUW 26k RIW 10k 12:18 22:54 10.60 9,630 9,830 PROD1 DRILL DRLG P 9630ft, BOBD 1.5 bpm at 3750psi, BHP 3880, WHP 42, IA 278, OA 130, lots of ankerite stringers, Pump 5x5 sweep. Page 15 of 29 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 22:54 00:00 1.10 9,830 8,130 PROD1 DRILL WPRT P 9,830 -ft, Wiper up hole for tie-in, PUW 31k Note: Lost 22 bbls in last 24 hrs. 01/25/2015 Drill ahead A lateral from 9,830 -ft to 10,357 -ft, Mud swap at 9,830 -ft. TOOH for plug back. Undeploy BHA #12, MU BHA #13 00.00 00:30 0.50 8,130 7,375 PROD1 DRILL WPRT P 8,130 -ft, Wiper up hole for tie-in, PUW 23k Note: Pressure survey from 7,380 to 7,375 -ft, 1.5 bpm at 3,561 psi, WHP 15, BHP 3,665 psi, ECD 11.84 ppg 00:30 00:42 0.20 7,375 7,715 PROD1 DRILL WPRT P 7,375 -ft, Wiper in hole, RIW 11k 00:42 00:51 0.15 7,715 7,740 PROD1 DRILL DLOG P Log formation marker at 7,700 -ft, Plus 4 -ft correction. 00:51 02:30 1.65 7,740 9,830 PROD1 DRILL WPRT P Continue wiper in hole, lowering pump rate to pass 8,730, 9,230, 9,380 and 9,660 -ft Note: Mud swap, new mud at bit at 9,830 -ft. 02:30 05:00 2.50 9,830 9,931 PROD1 DRILL DRLG P 9,830 -ft, BOBD 1.5 bpm at 3578 psi, BHP 3842, WHP 170, IA 100, OA 0, 05:00 05:30 0.50 9,931 9,931 PROD1 DRILL WPRT T 9931 ft, Geo wiper up hole to 9824ft, PUW 26k, RIW 9k **** Note: Geo wiper / Geo's called town for plan forward due to crossing fault into high gamma. Looks like we faulted into the upper A4 silt. 05:30 08:21 2.85 9,931 10,030 PROD1 DRILL DRLG P 9931ft, OBD 1.5 bpm at 3350psi, BHP 3898, WHP 176, IA 161, OA 18 08:21 08:51 0.50 10,030 9,000 PROD1 DRILL WPRT P 10030ft, Wiper up hole to 9000ft, PUW 25k 08:51 09:06 0.25 9,000 9,234 PROD1 DRILL WPRT P 9000ft, Wiper back in hole, RIW 9k, 09:06 10:06 1.00 9,234 9,234 PROD1 DRILL WPRT T 9234ft, try to work through trouble area, and were unsuccessful ****Note: Make call to DE, discussed drilling through trouble spot. Given ok to drill through. 10:06 11:06 1.00 9,234 10,030 PROD1 DRILL WPRT T 9234ft, Drill through hard spot successfully, PBUH , try to pass through trouble area, pumping min rate and were unsuccessful, bring pump up and drill through again, continue RIH to drill ahead. ****Note: Discussed with DE, plan forward for managing trouble spot. -' Page 16 of 29 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 11:06 14:36 3.50 10,030 10,230 PROM DRILL DRLG P 10030ft, BOBD 1.5 bpm at 3470psi, BHP 3883, WHP 188, IA 147, OA 4 **** Note: Decision was made to drill towards taget at 6001 TVD for data, Plug Back #1 due to hole stability. 14:36 15:33 0.95 10,230 10,230 PROD1 DRILL WPRT P 10230ft, Wiper up hole to 9315ft, PUW 25k, RIW 10k 15:33 17:33 2.00 10,230 10,357 PROD1 DRILL DRLG P 10230ft, BOBD 1.5 bpm at 3658 psi, BHP 3885, WHIP 170 17:33 20:45 3.20 10,357 69 FROM DRILL TRIP T 10,357-ft, TD A lateral per Geo, POOH for anchored billet. PUW 27k. 20:45 23:00 2.25 69 0 PROD1 DRILL PULD T PJSM- Undeploy BHA #12, Bit condition 3-1-BT-N-X-1-CT-HP, 1 plugged nozzle, LD RSM assembly. 23:00 23:30 0.50 0 0 PROD1 STK PULD T PJSM- MU BHA #13, anchored billet assembly. 23:30 00:00 0.50 0 0 PROM STK SVRG T Nabors CoilTrac computer down. Note: Lost 6 bbls in last 24 hours. 01/26/2015 Set OH anchored aluminum billet top at 8,650-ft. TOOH. Undeploy BHA #13. Deploy BHA #14. Kick off billet at 8,651-ft, drill A lateral to 8,805-ft with conventional motor, DLS average 7.56°. TOOH, LD BHA #14. MU BHA #15 00:00 01:33 1.55 0 73 PROM PULD T PJSM- Deploy BHA #13, make up to JSTK CoilTrac, surface test. 01:33 03:21 1.80 73 7,115 PROD1 STK TRIP T RIH with BHA #13, 2.625' x 11.76-ft Aluminum OH anchored billet assembly, Closed EDC at 7,000-ft, PUW 25k, RBI pumps off. 03:21 03:33 0.20 7,115 7,140 FROM STK DLOG T 7,115-ft, Log K1 marker with minus 4.5-ft correction. 03:33 04:18 0.75 7,140 8,662 FROM STK TRIP T Continue in hole with BHA #13. 04:18 04:27 0.15 8,662 8,650 PROM STK WPST T Position bottom of billet at 8,661.76-ft, billet set at 4,400 psi, set down 2k, top of OH billet at 8,650-ft 04:27 06:27 2.00 8,650 73 PROM STK TRIP T 8,650-ft, POOH for drilling assembly. 06:27 07:57 1.50 73 0 PROD1 STK PULD T At surface PJSM, Undeploy settting tools. 07:57 09:57 2.00 0 72 PROM STK PULD T PJSM - M/U and deploy kickoff BHA# 14 09:57 11:27 1:50 72 7,120 PROD1 STK TRIP T RIH with drilling / kickoff BHA w/conventional tools sting with a low 0.5 ako motor 11:27 11:54 0.45 7,120 7,134 PROM STK DLOG T 7120ft, Tie into the K1 correction of minus 4.0ft. 11:54 12:54 1.00 7,134 7,900 PROM STK TRIP T 7134ft, Continue RIH to bottom 12:54 13:24 0.50 7,900 7,900 PROM STK DLOG T 7900ft, perform MADD PASS 7900ft up to 7600ft to confirm readings from USR on previous run 12. 13:24 13:54 0.50 7,900 8,651 PROD1 STK TRIP T 7900ft, Continue RIH to bottom dry tag TOB at 8651 ft. PUW 25k Page 17 of 29 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 13:54 15:54 2.00 8,651 8,660 PROM STK KOST T 8651ft, KOST as per recommended practice and DD. Pumping 1.44 bpm at 3280psi , BHP 3798, WHP 162, IA 87, OA 13 15:54 19:06 3.20 8,660 8,805 PROD1 DRILL DRLG T 8,660 -ft, Drill ahead A lateral to 8,805 -ft 1.5 bpm, started loosing 8 to 10 bph at 8,790 -ft, slowly healing 19:06 22:00 2.90 8,805 72 PROD1 DRILL TRIP T 8,805 -ft, POOH for RSM assembly, PUW 27k,pump 5x5 to clean hole up of aluminum, close EDC at 7,010 -ft 22:00 23:30 1.50 72 0 PROM DRILL PULD T PJSM- Undeploy BHA #14, LD conventional drilling assembly. service injector. 23:30 00:00 0.50 0 0 PROM DRILL SFTY T PJSM- MU BHA #15, RibSteer motor assembly. Note: Lost 36 bbl in last 24 hours. )1/27/2015 Drill from 8,805 to 8,850', in progress. 00:00 01:54 1.90 0 73 PROD1 DRILL PULD T Continue to MU and Deploy BHA #15, RSM assembly. MU to CoilTrak, surface test. 01:54 03:18 1.40 73 7,110 PROM DRILL TRIP T RIH with BHA #15, New RSM (New style seals) and New HCC Bi -center bit. Close EDC at 7,030 -ft, PUW 27k 03:18 03:30 0.20 7,110 7,140 PROM DRILL DLOG T Log K1 marker, correction of minus 4 -ft, 03:30 04:24 0.90 7,140 8,805 PROM DRILL TRIP T RIH with BHA #15, bobble running thru 7,300 -ft, 04:24 13:54 9.50 8,805 8,845 PROD1 DRILL DRLG T 8,805 -ft, BOBD 1.5 bpm at 3668 psi, BHP 3809, WHP 215, IA 12, OA 0, Hard drilling, low progress, Trip for low bend motor 13:54 16:12 2.30 8,845 60 PROM DRILL TRIP T POOH for bent motor, PUW=26K 16:12 17:48 1.60 60 0 PROD1 DRILL PULD T Tag up and space out, PJSM, PUD BHA #15 RSM 17:48 19:24 1.60 0 0 PROM DRILL PULD T PJSM, Unload PDL, Reconfig BHA, Reload PDL, Short on res tool 19:24 20:30 1.10 0 72 PROM DRILL PULD T PJSM, PD BHA #16 with .4+° AKO motor and RR Hycalog Bi center, Stat on coil and surface test tool. 20:30 21:54 1.40 72 7,061 PROM DRILL TRIP T RIH, EDC Open, pump min rate 21:54 22:00 0.10 7,061 7,115 PROM DRILL TRIP T Stop and shut EDC, PUW=25K, RIH to tie into RA 22:00 22:12 0.20 7,115 7,134 PROD1 DRILL DLOG T Log GR tie into RA marker for -5' correction 22:12 22:54 0.70 7,134 8,845 PROM DRILL TRIP T Trip in to drill, clean pass through window 22:54 00:00 1.10 8,845 8,846 PROM DRILL DRLG T 8845 on bottom, very grabby on contact, lots of reactive, 1.47 BPM @ 3368, bhp=3775, Quick stalls with little WOB of Diff pressure DI/2812015 Pull RSM @ 8845 for low bend motor. RIH with .4° motor and Re run HYC bi center. Unable to make progress drilling, POOH, trim CT 2600' for fatigue mgmt Page 18 of 29 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 06:00 6.00 8,846 8,846 PROM DRILL DRLG T 8846' Hard to keep from stalling getting to bottom. PUH after stall and loose hole. RIH to bottom with pumps off try to push any debrie to bottom. 1.49 BPM @ 3505 PSI FS, BHP=3780 06:00 07:30 1.50 8,846 8,846 PROM DRILL DRLG T 8846ft, Shift change, continue trying to drill ahead, stalling motor, PUW 25k clean, try and work back to bottom, unsuccessful, confer with town team, decision to POOH 07:30 10:30 3.00 8,846 72 PROD1 DRILL TRIP T 8846ft, POOH, cleaning open hole in preparation for running Anchored Open Hole Billet 10:30 12:00 1.50 72 0 PROD1 DRILL PULD T At surface, PJSM, Undeploy and laydown drilling BHA# 16 12:00 13:00 1.00 0 0 PROM DRILL SFTY P Hold Safety Standup for crew on hand safety and perform PJSM for cutting coil 13:00 16:00 3.00 0 0 FROM DRILL PULD P Swap coil over to fresh water, unstab INJH, cut CTC and BHI upper quick off, protect eline, perform slackmanagement, 16:00 17:06 1.10 0 0 PROM DRILL PRTS P Test inner reel valve and stripper, and get a shell test on BOPE. 17:06 18:00 0.90 0 0 PROM DRILL CTOP P R/U floor and prep to trim coil 18:00 00:00 6.00 0 0 PROD1 DRILL CTOP P PJSM, Trim 2600' coil for fatigue mgmt D1/29/2015 Trim 2600' coil, Complete full BOPE Test, Witnes waived by Bob Noble, AOGCC, Run and set Anchored billit @ 8031.7, TOB @ 8020' 150° ROHS. Lost 11 BBIs 00:00 00:36 0.60 0 0 PROD1 DRILL CTOP P Continue trimming 2600' of CT, 00:36 02:00 1.40 0 0 PROM DRILL CTOP P RID floor from cutting ops, Prep for BOPE test 02:00 12:00 10.00 0 0 PROM WHDBO BOPE P Perform Biweekly full BOPE test. Test witness waived by Bob Noble, AOGCC **** Note: Replace Annular Element 12:00 14:00 2.00 0 0 PROD1 WHDBO BOPE T Replace Annular element, and test. Good test 14:00 15:30 1.50 0 0 PROM STK CTOP P Displace reel to drilling fluid, pump 1 coil volume forward. 15:30 16:42 1.20 0 0 PROD1 STK SFTY T I PJSM - M/U billet setting BHA 16:42 18:00 1.30 0 0 PROM STK PULD T M/U and deploy, BHI tools, and Open Hole Anchored Billet 18:00 19:00 1.00 0 74 PROM STK PULD T Crew change, valve checklist, Continue PD BHA #17 Anchored OH Billet. M/U to coil and surface test tool 19:00 21:00 2.00 74 7,116 PROM STK TRIP T RIH, EDC Open, Pump at min rate, Shut down pump and close EDC @ 7098. Above TOC. PUW=24K 21:00 21:06 0.10 7,116 7,135 PROD1 STK DLOG T Log K1 for -4' correction Page 19 of 29 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 21:06 21:42 0.60 7,135 8,032 PROD1 STK TRIP T Continue in well, take weight @ 7315 did not set down. Set OH anchor billet @ 8031.7. Top of billet @ 8020 oriented to 150° ROHS, set down 2.5K. 21:42 22:36 0.90 8,032 68 PROD1 STK TRIP T Trip out after setting billet 22:36 00:00 1.40 68 0 PROD1 STK PULD T At surface, Tag up and space out, PJSM, PUD BHA #17 after setting OH Anchored billet 01/30/2015 Time mill billet down to 8022, stall and P/U. Hole packed off. Unable to circulate. Able to recip pipe. Pump LVT start working pipe uphole 00:00 01:30 1.50 0 0 PROD1 STK PULD T PJSM - reconfigure BHA and load I PDL 01:30 02:45 1.25 0 72 PROD1 STK PULD T PJSM, PD BHA #18, Lateral drilling BHA with .4° AKO motor and new HC Bi center bit. Make up to coil and surface test 02:45 04:09 1.40 72 7,125 PROD1 STK TRIP T RIH, Pumping with EDC open 04:09 04:15 0.10 7,125 7,140 PROD1 STK DLOG T Log tie in for -4' correction 04:15 04:57 0.70 7,140 8,021 PROD1 STK TRIP T Continue in well, clean pass through window, tight area 7310 to 7320, Dry tag billit @ 8021 04:57 09:45 4.80 8,021 8,026 PROD1 STK KOST T Time mill off billet, 1.48 BPM @ 2990 PSI FS, BHP=3686, Having trouble getting weight to bit, pump 50 bbls, of new mud, getting good weight on bit, mill down to 8025.9ft, 09:45 11:33 1.80 8,026 7,500 PROD1 STK KOST T 8025.9ft, Pick up hole, Packing off above BHA, Work coil, free pulling up, stacking out RIH, set down 0 surface weight, PUH slowly to 7500ft, RIH freely 11:33 16:39 5.10 7,500 7,590 PROD1 STK KOST T Able to move between — 7900 and 7500. Well packed off with minimal returns. Line up and pump down backside. recip pipe with 800PSI on WH then try 900 PSI. Became stuck at 7728. Relax annular pressure to 3600PSI and work free downhole 16:39 18:33 1.90 7,590 7,490 PROD1 STK CIRC T Pump 7 BBI pill down coil..25BPM with—3900PSI on annular still minimal returns 18:33 21:45 3.20 7,490 7,370 PROD1 STK TRIP T LVT at bit, recip 7490 to 7520, Above end of build, Pull up past tight spot @ 7452. Pull up to 7370. Out of LVT keep trying to get up past 7370 @ 38-42K. Become stuck unable to move down hole. S/D pump and become free at 3600 PSI annular. RIH 21:45 00.00 2.25 7,370 7,370 PROD1 STK CIRC T Start 7 BBI LVT pill down coil 1/4BPM, annular 3990. Minimal returns to surface, Recip pipe 7380 to 7435 Page 20 of 29 Time Logs Date From To Dur S. De th E. Depth Phase Code Subcode T Comment 1/31/2015 24 hr Summary Surge down backside and free BHA #18, Trip out P/U BHA #19 clean out run. Stuck @ 7296 Surge down backside and pull free. Clean out above window for second whipstock. 00:00 00:48 0.80 7,370 7,370 PROM STK CIRC T 7370ft,CW 40k work pipe pressuring up on the casing to 700psi, then dumping pressure to Opsi, Continue circulating LVT down coil 00:48 01:48 1.00 7,370 7,370 PROM STK TRIP T LVT out, start working pipe up trying to get above 7370, Slowing start increasing tension with each cycle. Looks like movement up @ 46K. Keep pulling to 50K. Unable to RIH. Shut down pump to relax annulas. Still no returns at surface. 01:48 01:54 0.10 7,370 7,370 PROM STK TRIP T Not able to run back in hole. Line up and pump down coil and backside with coil in tension. 50K. Surge at 600 and 700 PSI WHP. Place coil in compression. Surge at 600 PSI. Pressure up for second surge coil became free going down. 01:54 03:00 1.10 7,370 7,370 PROM STK TRIP T Work pipe 7370 to 7440. Have to relax annulas to run in hole after over pull at 7370 03:00 04:00 1.00 7,370 7,370 PROM STK TRIP T Annulas has been between 3600 to 3850PSI. Try bringing up rate while reciping pipe to move bridge. Increase recip speed to 30 FPM. Annular up to 4060PSI still minimal returns 04:00 04:30 0.50 7,370 7,370 PROD1 STK TRIP T Confer with town for plan forward. Continue recip pipe 7380 - 7445 04:30 07:00 2.50 7,370 7,370 PROM STK CIRC T Plan is to pump down coil to break out bridge / establish circulation 1 BPM2660 PSI Pump Pressure, BHP=4216 PSI, 1.5 BPM @ 3688PS1, BHP=4345, 1.55 BPM @ 4222 PSI, BHP=4503 07:00 10:00 3.00 7,370 7,370 PROM STK TRIP T Work Pipe from 7400ft up to 7380ft, pressuring up the back side to 1000, in tention, Dropping back side pressure to 0 while RIH, down to 7400ft. 10:00 10:45 0.75 7,370 7,000 PROD1 STK TRIP T 7370ft, pulling free from 7400ft, continue PUH though window to TOC at 7000ft. 10:45 13:15 2.50 7,000 7,090 PROM STK TRIP T 7000ft, RBIH to TOC 7090ft, circulate 5x5 sweep, checking samples, 95% Shattered frac sand / 1 % shale/slit cuttings, Bottoms up sample 99% whole frac sand, 1 % shale/silt. 13:15 14:00 0.75 7,090 72 PROM STK TRIP T 7090ft, POOH pumping 1.6bpm with EDC closed. perform jog at surface 200ft - 400ft, continue POOH, tag up and space out for undeploy of drilling BHA# 18 14:00 1430 0.50 72 72 PROM STK SFTY T Conference call with town on plan forward Page 21 of 29 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 14:30 16:30 2.00 72 0 PROD1 STK PULL T I PJSM, Undeploy Drilling BHA# 18 16:30 17:00 0.50 0 0 PROD1 STK PULD T L/D drilling BHA, Bit gauged 1-1 17:00 17:36 0.60 0 62 PROD1 STK PULD T M/U, Cleanout BHA# 19 with .9° Motor and D331 Mill, M/U to coil and urface test 17:36 19:06 1.50 62 7,105 PROD1 STK TRIP T RIH, EDC open 19:06 19:18 0.20 7,105 7,123 PROD1 STK DLOG T Log K1 marker for -5' correction. 19:18 20.30 1.20 7,123 71221 PROD1 STK TRIP T R1 to 7145, Pump 5X 5 Sweeps circulate bottoms up, RIH to 7240', Pump 5 X 5 sweeps and circulate bottoms up. 1.6 BPM 20:30 20:42 0.20 7,221 7,300 PROD1 STK TRIP T Close EDC, run through window, clean pass down to 7300' 20:42 20:54 0.20 7,300 7,296 PROD1 STK TRIP T Clean down to 7300 Recip pipe uphole 20' @ 10 FPM, full returns with sweeps coming out, RIH to 7348 and recip up. Overpull @ 7296 with pack off, Unable to RIH. Motor stalled. Seeing DHWOB movement while working pipe. Unable to orient 20:54 21:06 0.20 7,296 7,296 PROD1 STK TRIP T 7296 Stuck and stalled, work pipe attempt to get free, Consult town 21:06 21:36 0.50 7,296 7,296 PROD1 STK TRIP T Relax pipe, discuss option, PJSM with plan for pumping and surgeing down backside 21:36 21:42 0.10 7,296 7,280 PROD1 STK TRIP T Pump down coil and backside, Pull coil into tension 35K, Pressure up to 800 PSI WHP then dump. Increase coil tension to 40K. Repeat pressure up / dump and pull free, full returns. Jog below window. Clean pass up through window. 21:42 23:54 2.20 7,280 5,600 PROD1 STK CIRC T Circulate bottoms up. Frac sand coming out, quite heavy at times. Still seeing sand at 2nd bottoms up, Pump 5 X 5 sweeps and head back in to clean whipstock setting area 7225 to 7236 23:54 00:00 0.10 7,105 7,121 PROD1 STK DLOG T Log K1 for+2' correction 32/01/2015 Complete Fill clean out in upper whipstock setting area, 7236 to 7225. Trip out. P/U Whipstock, Tie in for -5' correction. Set whipstock @ 7225. Able to push downhole. POOH 00:00 02:00 2.00 7,121 7,236 PROD1 STK TRIP T Continue in clean out upper whipstock area 7225 to 7236. With 5 x 5 sweeps, recip through area 02:00 04:18 2.30 7,236 58 PROD1 STK TRIP T Trip out of well, recip across gas lift mandrels 04:18 07:18 3.00 58 0 PROD1 STK PULD T At surface, space out, PJSM, PUD BHA #19, FCO with .9° motor 07:18 08:18 1.00 0 74 PROD1 STK PULD T L/D Cleanout tools, inspect checks in upper quick and float valve sub BHI Page 22 of 29 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 08:18 09:48 1.50 74 PROD4 RPEQPI PULD P M/U and PIU new Whipstock setting BHA# 20 **** Note: BHA# 20 Both set of check valves were blocked by beads. Changed out BHI tools due to over pull. 09:48 11:27 1.65 74 7,000 PROD4 RPEQPITRIP P RIH, 3-1/2", MB XL WS with cement slips, 2 ra tags 11:27 11:33 0.10 7,000 7,115 PROD4 RPEQPITRIP P 7000ft, PUW25k 11:33 11:51 0.30 7,115 7,141 PROD4 RPEQPI DLOG P 7115ft, Tie into the K1 marker correction minus 5.5ft. 11:51 12:21 0.50 7,141 7,236 PROD4 RPEQPITRIP P 7141ft, Continue RIH to setting depth 7235.48ft. 12:21 12:36 0.25 7,236 7,235 PROD4 RPEQPI WPST P 7235.48ft, PUW 25k, PU to 22k, set TOWS at 7225ft. pressure up to 3801 psi, shear setting tool, shift 1.6k on cement slips, move IH to set weight down not seeing any weight, set down 7k at 7241ft, Move up hole to 7240ft, 800lbs WOB. 12:36 14:12 1.60 7,235 74 PROD4 RPEQPITRIP T 7235ft, POOH to surface. 14:12 15:42 1.50 74 0 PROD4 RPEQPITRIP T 73.6ft, PJSM undeploy WS setting BHA# 20, UD BOT Tools 15:42 19:12 3.50 0 0 PROD4 RPEQPI WAIT T Formulate plan forward 19:12 22:54 3.70 0 0 PROD4 RPEQPI CTOP T PJSM, Remove UQC and CTC. Boot E-line. Pump slack mgmt. Cut 14' CT to find wire. Trim 230' Coil for fatigue management 22:54 00:00 1.10 0 0 PROD4 RPEQPI CTOP T Test wire, Good test, Prep coil for connector and install 2/02/2015 Perform slack mgmt. trim CT for fatigue mgmt. Run caliper with HES E-line. MU BHA # 21. 00:00 00:12 0.20 0 0 PROD4 RPEQPI CTOP T �Complet install of CTC and pull test to 36K 00:12 01:30 1.30 0 0 PROD4 RPEQPI PULD T M/U E-line to UQC, Test wire 73.5 Ohmes/>2K Meg, PT to 4K 01:30 01:54 0.40 0 0 PROD4 RPEQPI SFTY T PJSM with HES to rig up e-line on rig 01:54 06:54 5.00 0 0 PROD4 RPEQPI PULD T Rig up E-line on rig, PT lubricator to 4000psi. 06:54 07:54 1.00 0 0 PROD4 RPEQPITRIP T RIH, with full caliper assembly to check pilot hole integrity. From 7229ft to the HRZ. 07:54 08:24 0.50 0 0 PROD4 RPEQPI PULD T Eline At surface, shut tango valve, unstab lubricator, remove lower centralizer. 08:24 09:24 1.00 0 0 PROD4 RPEQPI PULD T Stab back on, P/T lubricator to 2000psi, RIH to log down across the WS tray. 09:24 10:24 1.00 0 0 PROD4 RPEQPITRIP T I Eline, RIH without lower centralizer, caliper down to 7225ft. 10:24 11:09 0.75 0 0 PROD4 RPEQPI PULD T Eline at surface, shut tango valve, unstab lubricator, UD eline tools, 11:09 13:39 2.50 0 0 PROD4 RPEQPI PULD T R/D eline unit Page 23 of29 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 13:39 18:33 4.90 0 0 PROD4 RPEQPI WAIT T WOO, performing rig maintenance. 18:33 21:51 3.30 0 74 PROD4 RPEQPI PULD T BOT on location with modified whipstock, PJSM to M/U BHA#21, whipstock with OH anchor. PD BHA #21. M/U to coil and surface test 21:51 23:27 1.60 74 6,800 PROD4 RPEQPITRIP T RIH, EDC Open pumping min rate 23:27 00:00 0.55 6,800 6,890 PROD4 RPEQPI DLOG T 6800 start Gamma log downhole, 3FPM, 6890' Midnight depth 2/03/2015 Set OH Anchored whipstock @ 7,208'. POOH for milling assembly. PUD BHA #21, PD BHA #22. TIH w/ milling assembly, tag WS @ 7,208'. Mill exit window to 7,214', drill rathole to 7,224'. Back ream window, dry drift clean. POOH for drilling assembly. PUD of BHA #22, LD motor assembly. 00:00 01:48 1.80 6,890 7,200 PROD4 RPEQPI DLOG T Continue logging run 6800 to 7200, Stop at 7200 and correct depth to 7194.5, -5.5' 01:48 02:06 0.30 7,200 6,900 PROD4 RPEQPI DLOG T PUH to 6900' to run CCL 02:06 02:24 0.30 6,900 7,200 PROD4 RPEQPI DLOG T 6900', log CCL, 15FPM 02:24 02:42 0.30 7,200 7,219 PROD4 RPEQPI DLOG T Confer with town, Ted Starns town geo confirmed Doug's correction. Confer with Ron Phillips. Good to set whipstock 02:42 02:48 0.10 7,219 7,218 PROD4 RPEQPI WPST T At set depth 7218.57 oriented to high side, Pumps on see tool shift @ 4500 PSI. Set down 4K. Looks good, TOWS=7208 02:48 04:48 2.00 7,218 69 PROD4 RPEQPI TRIP P Trip out of well, Stop at 7080 and open EDC 04A8 06:18 1.50 69 0 PROD4 RPEQPI PULD P At surface, PJSM, PUD BHA #21 Whipstock setting tools 06:18 07:48 1.50 0 74 PROD4 WHPST PULD P M/U and deploy Window milling BHA 07:48 09:24 1.60 74 7,120 PROD4 WHPST TRIP P RIH, Window milling BHA# 22 09:24 09:36 0.20 7,120 7,142 PROD4 WHPST DLOG P 7142ft, tie into the K1 marker correction of minus Eft. 09:36 09:42 0.10 7,142 7,208 PROD4 WHPST TRIP P Continue RIHTB, closing EDC, no pump through cement pilot hole. 09:42 17:00 7.30 7,208 7,214 PROD4 WHPST WPST P Dry tag Whipstock @ 7208, PUH pumps on @ 1.5 BPM @ 3260 PSI FS. Call pinch point 7207.4 start milling window per procedure 17:00 19:48 2.80 7,214 7,224 PROD4 WHPST WPST P Call bottom of window, Drop off on WOB 19:48 20:48 1.00 7,224 7,224 PROD4 WHPST WPST P Reached rathole TD, start reaming passes, made passes @ 30L, 30R and HS, Dry drift hole, Looks good 20:48 22:12 1.40 7,224 67 PROD4 WHPST TRIP P Trip out of hole, Open EDC @ 7085, P U W=26K 22:12 00:00 1.80 67 0 PROD4 WHPST PULD P PJSM, PUD BHA#22 Window milling BHA, Both mills out @ 2.79 No go 2/04/2015 PD BHA #23, TIH with drilling assembly. Drill ahead "B" lateral from 7,224' to EOB @ 7625, Trip out for Lateral drilling BHA Page 24 of 29 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 02:30 2.50 0 63 PROD4 DRILL PULD P PJSM, M/U and deploy BHA #23, Build section BHA with 2.3° ako motor and Rebuilt hughes with edge cutters. No res. M/U to coil and surface test tool. Inspect injector and reel 02:30 04:00 1.50 63 71100 PROD4 DRILL TRIP P Trip in hole, EDC open 04:00 04:12 0.20 7,100 7,136 PROD4 DRILL DLOG P Close EDC, log tie in for -5.5, PUW=24K 04:12 04:24 0.20 7,136 7,224 PROD4 DRILL TRIP P Trip into drill 04:24 07:54 3.50 7,224 7,320 PROD4 DRILL DRLG P Clean pass through window, Tag up at 7224 and drill, 144 BPM @ 3020 PSI FS, BHP=3850 07:54 08:33 0.65 7,320 7,320 PROD4 DRILL DLOG P Wiper for tie-in, PUW=26K, tie-in @ K1 for zero correction, log RA @ 7,215'. RBIH. 08:33 15:33 7.00 7,320 7,520 PROD4 DRILL DRLG P Drill ahead. 1.50 BPM @ 3,210 PSI, BHP=3,645 PSI, CTW=10K, WOB-1.5K, ROP=35. Started pumping new mud, mud at bit @ 7,450'. 15:33 16:21 0.80 7,520 7,520 PROD4 DRILL WPRT P Wiper trip, PUW=26.5K, RBIH @ 16:00. 16:21 22:39 6.30 7,520 7,625 PROD4 DRILL DRLG P Drill ahead: 1.50 BPM @ 3,280 PSI, BHP=3,690 PSI, CTW=9.5K, WOB-1.4K, ROP=20 22:39 00:00 1.35 7,625 200 PROD4 DRILL TRIP P Call EOB, Trip out of well, PUW=26K, Midnight depth 200' 2/05/2015 Deploy BHA #24, Lateral section w/.6° motor and RR hycalog bit, Drill 7625 to 8425 00:00 00:18 0.30 200 61 PROD4 DRILL TRIP P I Continue out of well after completing build section 00:18 01:54 1.60 61 0 PROD4 DRILL PULD P At surface, PJSM, PUD BHA # 23 Build section BHA 01:54 02:30 0.60 0 0 PROD4 DRILL BOPE P Perform BOPE Function test 02:30 04:06 1.60 0 72 PROD4 DRILL PULD P PJSM, PD BHA#24, Lateral section with .6° AKO motor and RR Hycalog bit. M/U to coil and surface test 04:06 06:06 2.00 72 7,625 PROD4 DRILL TRIP P Trip in hole with BHA #24. Tie-in to K1 for -5.5' correction, continue in hole. 06:06 09:36 3.50 7,625 7,825 PROD4 DRILL DRLG P Drill ahead: 1.48 BPM @ 3310 PSI, BHP=3705 PSI, CTW=9.3K, WOB=1.9K, ROP=60 09:36 09:48 0.20 7,825 7,635 - PROD4 DRILL WPRT P Wiper trip 09:48 10:48 1.00 7,235 7,825 PROD4 DRILL DLOG P MAD pass from 7,635' to 7,235'. RBIH @ 10:25. 10:48 13:57 3.15 7,825 8,025 PROD4 DRILL DRLG P Drill ahead: 1.47 BPM @ 3330 PSI, BHP=3735 PSI, CTW=8.51<, WOB=1.6K, ROP=65 13:57 15:00 1.05 8,025 8,025 PROD4 DRILL WPRT P Wiper to window, PUW=28K, RBIH @ 14:40. 15:00 17:54 2.90 8,025 8,225 PROD4 DRILL DRLG P Drill ahead: 1.48 BPM @ 3290 PSI, BHP=3745 PSI, CTW=7.5K, WOB=1.5K, ROP=70 Page 25 of 29 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 17:54 19:30 1.60 8,225 8,225 PROD4 DRILL WPRTP Wiper to window with tie in for +2.5' correction, PUW=26K, 19:30 21:54 2.40 8,225 8,370 PROD4 DRILL DRLG P 8225', Drill, 1.5BPM @ 3070 PSI FS, BHP=3769 21:54 23:24 1.50 8,370 8,377 PROD4 DRILL DRLG P Found Ankorite, ROP 5-10FPM, Pulled mini wipers, 23:24 23:42 0.30 8,377 8,425 PROD4 DRILL DRLG P Broke through ROP 60-60FPH, 1.5 BPM @ 3105PSI FS, BHP=3746 23:42 00:00 0.30 8,425 8,300 PROD4 DRILL WPRT P 8425 Wiper trip to 7630, PUW=26K 2/06/2015 Drill ahead from 8425 to 9215, Swap Mud 00:00 01:12 1.20 8,300 8,425 PROD4 DRILL WPRT P Continue wiper to 7630, Clean trip up and down 01:12 02:54 1.70 8,425 8,531 PROD4 DRILL DRLG P 8425', Drill, 1.5 BPM @ 3110PSI FS, BHP=3748 02:54 04:36 1.70 8,531 8,625 PROD4 DRILL DRLG P Hard spot, Pull mini wiper hard to get going, PUW=28K, go back to drilling 04:36 05:33 0.95 8,625 8,625 PROD4 DRILL WPRT P Wiper trip to 7630, PUW=26K, RBIH @ 05:15 05:33 11:03 5.50 8,625 8,825 PROD4 DRILL DRLG P Drill ahead: 1.48 BPM @ 3320 PSI, BHP=3775 PSI, CTW=3.5K, WOB=1.4K, ROP=35, some stacking @ 8,665' to 8,670', PUW=30K. 11:03 12:09 1.10 8,825 7,235 PROD4 DRILL WPRT P Wiper for tie-in, PUW=26K. 12:09 12:54 0.75 7,235 8,825 PROD4 DRILL DLOG P Tie-in to RA tag for +2' correction. RBIH. 12:54 19:24 6.50 8,825 9,025 PROD4 DRILL DRLG P Drill ahead: 1.48 BPM @ 3360 PSI, BHP=3820 PSI, CTW= 2K, WOB=1.5K, ROP=30. Start pumping new mud, new mud at bit @ 8,950'. Stacking and weight transfer @ 8,970' 19:24 20:24 1.00 9,025 9,025 PROD4 DRILL. WPRT P Wiper trip to 7630, PUW=29K, Trouble getting on bottom from 8990, motor work, reduce pump rate 20:24 00:00 3.60 9,025 9,215 PROD4 DRILL DRLG P 9025', Drill, 1.48 BPM @ 3147 PSI FS, BHP=3790, RIW=5.8K 2/07/2015 Drill 9215 to 9635' Call early TD @9635 00:00 00:12 0.20 9,215 9,217 PROD4 DRILL DRLG P Drill ahead, 00:12 01:18 1.10 9,217 9,217 PROD4 DRILL WPRT P 9217', pull wiper, PUW=30K, ROP down, Weight transfer down 01:18 07:30 6.20 9,217 9,424 PROD4 DRILL DRLG P Hard to get started drilling, Kept stacking out, finally got drilling, 1.48 BPM @ 3100 PSI FS, BHP=3820. Surface CTW decreasing, BHA wipers @ 9,353' and 9,355'. 07:30 09:00 1.50 9,424 9,424 PROD4 DRILL WPRT P Wiper for tie-in, PUW=32K, tie-in at RA for coreection of +4' correction. 09:00 11:30 2.50 9,424 9,424 PROD4 DRILL WPRT P RBIH, stacking 9,032',9,301', and 9,366' struggling below 9,300', no surface coil weight, add addition 1% lubricate. Page 26 of 29 Time Logs Date From To Dur S. DeiDth E. De th Phase Code Subcode T Comment 11:30 15:06 3.60 9,424 9,565 PROD4 DRILL DRLG P Hard time getting started drilling, stacking out, no surface weight, finally got drilling. 1.48 BPM @ 3285 PSI FS, BHP=3870, CTW=1 K, WOB=1.3K, ROP=35. Lost diffential, stacking @ 9565', BHA wiper. 15:06 15:24 0.30 9,565 9,565 PROD4 DRILL WPRT P Lost Diff., stacking, P/U, BHA Wiper 15:24 19:30 4.10 9,565 9,625 PROD4 DRILL DRLG P 9565', Drilling, 1.47 BPM @ 3070 PSI FS, BHP=3782 19:30 21:00 1.50 9,625 9,625 PROD4 DRILL WPRT P 9625', Wiper to 8400, PUW=28K, Had some drag @ 9018 to 8970. Stacked out @ 9006, 9120. Work down with reduced pump rate 21:00 21:42 0.70 9,625 9,635 PROD4 DRILL DRLG P 9625', Drill, 1.48 BPM @ 3190 PSI FS, BNP=3856 21:42 00:00 2.30 9,635 2,250 PROD4 DRILL WPRT P Call TD, pump 10 X 10 Sweeps and chase to swab, 2/08/2015 Condition hole, Lay in Beaded liner pill followed with 11.4PPG Completion fluid. M/U Lower liner segment, Trip in hole 00:00 00:54 0.90 2,250 65 PROD4 DRILL WPRT P Continue swab wiper, Increase in cutting @ 700', Jog inhole @ 500 feet to let well unload. 00:54 02:24 1.50 65 7,110 PROD4 DRILL WPRT P At surface, reset counters, trip in 02:24 02:36 0.20 7,110 7,144 PROD4 DRILL DLOG P Logging K1 for -5' correction, PUW=24K 02:36 04:36 2.00 7,144 9,500 PROD4 DRILL WPRT P Continue in to confirm TD, Had to work through 8980 to 9000. Able to get through @ .9 BPM third try @ 25FPM, 100R TF as drilled 90R, More problems from 9200 on down fairly continuous. Set downs with no WOB. Unable to work past 9500. No motor work or WOB 04:36 05:06 0.50 9,500 9,100 PROD4 DRILL WPRT P Wiper up hole to 9100 and try again 05:06 05:33 0.45 9,100 9,020 PROD4 DRILL WPRT P RBIH, Set down @ 9250 work to 9280. PUH to work 9100 to 8950, stall coming uphole @ 9,008', tried to pack -off, getting sticky. Call town, decide to make 2nd wiper to swab. 05:33 08:18 2.75 9,020 72 PROD4 DRILL WPRT P Wiper to swab, jog back down @ 200' to 1,000', clean-up returns, POOH. tag up, reset depth. 08:18 09:33 1.25 72 450 PROD4 DRILL WPRT P TIH for corrected TD and lay in liner pill/completion fluid,stack @ 400', negative surface weight, troubleshoot stacking, stripper lube not functioning, troubleshoot. 09:33 12:33 3.00 450 9,550 PROD4 DRILL WPRT P TIH to lay -in completion fluids, tie-in @ K1 for -4.5' correction, PUW=25K, continue in hole. PUH @ 8,955', PUW=29K, decrease pump rate .30 bpm, continue in hole, no issues to 9,550', start stacking at 9,550', decrease pump rate, still stacking. Page 27 of 29 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 12:33 15:33 3.00 9,550 72 PROD4 DRILL DISP P TOOH laying in liner pill/completion fluid, paint EOP flag @ 8,400'& 6,100', continue out of hole with BHA #24. 15:33 16:03 0.50 72 72 PROD4 DRILL OWFF P On surface, flow check. 16:03 17:09 1.10 72 0 PROD4 DRILL PULD P PJSM. LD BHA#24 17:09 18:39 1.50 0 0 COMPZ CASING PUTB P Prep floor for liner ops, Crew change, Valve checklist 18:39 20:21 1.70 0 1,023 COMPZ CASING PUTB P PJSM, MU BHA 25 Lower liner assembly with non ported bullnose, 31 Jts slotted liner, and shorty deployment sleeve 20:21 21:27 1.10 1,023 1,023 COMPZ CASING PULD P PJSMM, P/U Coiltrack, M/U to coil and surface test 21:27 23:09 1.70 1,023 7,123 COMPZ CASING RUNL P Trip in well, EDC closed 23:09 23:15 0.10 7,123 7,119 COMPZ CASING DLOG P Correct to 6100' EOP flag for -4.5, PUW=27K 23:15 23:39 0.40 7,119 8,060 COMPZ CASING RUNL P Continue trip in, Clean pass through window 23:39 23:51 0.20 8,060 8,096 COMPZ CASING DLOG P Log K1 for+3' correction 23:51 00:00 0.15 8,096 8,510 COMPZ CASING RUNL P Continue in well 2/09/2015 Set lower liner 9635 to8656. Set upper liner 8656 to 7124. Set KBPacker 7124 to 7118. Trip in to displace well 00:00 00:30 0.50 8,510 9,635 COMPZ CASING RUNL P Continue tripping in with lower liner segment, See bobble @ 9550, Clean trip to 9635, PUW=31 K, Set back down and pump off liner, PUW=25K, TOL lower segment=8656 00:30 01:24 0.90 9,635 8,637 COMPZ CASING TRIP P PUH and remove liner length left in hole, Line up to pump accross top, Trip out 01:24 01:36 0.20 7,080 7,044 COMPZ CASING DLOG P Log K1 for +2' 01:36 03:12 1.60 7,044 46 COMPZ CASING TRIP P Trip out, Paint EOP flags @ 7000'& 5500' 03:12 03:42 0.50 46 46 COMPZ CASING OWFF P At surface, Perform 30 Min no flow test, PJSM to lay down liner running BHA 03:42 04:30 0.80 46 0 COMPZ CASING PULD P Lay down BHA #24, liner running tools 04:30 07:03 2.55 0 1,525 COMPZ CASING PULD P PJSM, PIU BHA #26, 1 L-04B Upper liner segmet, Non Ported bull nose, 33 Jts slotted liner, 16 Blank liner and seal bore deployment sleeve 07:03 08:33 1.50 1,525 1,597 COMPZ CASING PULD P PJSM. MU BHA #26. Test MVD, tag stripper, reset depth. 08:33 11:06 2.55 1,597 8,659 COMPZ CASING RUNL P RIH w/ BHA #26 Upper liner assembly, stop @ flag, correction -6.5', PUW=28K, continue in hole, tag up on lower liner assembly, PUW=28K, set down, release from liner, PUW=24K, correct depth. 11:06 12:24 1.30 8,659 55 COMPZ CASING TRIP P POOH for liner top packer. Page 28 of 29 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 12:24 13:09 0.75 55 55 COMPZ CASING OWFF P At surface. Flow check, PJSM. 13:09 13:39 0.50 55 0 COMPZ CASING PULD P PJSM. LD BHA #26 13:39 14:24 0.75 0 56 COMPZ CASING PULD P PJSM. MU BHA #27 Liner top packer assembly 14:24 15:21 0.95 56 56 COMPZ CASING RGRP T PJSM. Service choke 15:21 18:27 3.10 56 7,095 COMPZ RPEQPI PACK P RIH w/ packer assembly, EDC Open 18:27 18:39 0.20 7,095 7,122 COMPZ RPEQPI DLOG P Tie into K1 for -6' correction 18:39 18:51 0.20 7,122 7,118 COMPZ RPEQPI PACK P Obtain PUW 27K then sting into seal bore sleeve, Set down @ 7132, PIU to break over +1' 7128. Set packer, set down 2K, PIU 2K. Pump up to release running tool. TOPacker is @ 7118 18:51 20:09 1.30 7,118 40 COMPZ RPEQPI PACK P POOH after setting liner top packer 20:09 20:39 0.50 40 40 COMPZ RPEQPI OWFF P Observe well for flow 30 Min no flo test. PJSM to lay down packer running tools 20:39 21:03 0.40 40 0 COMPZ RPEQPI PULD P Lay down BHA # 27, Packer running tools 21:03 21:27 0.40 0 15 DEMOB WHDBO FRZP P PJSM P/U BHA #28 Nozzle and 10' PUP 21:27 22:51 1.40 15 7,075 DEMOB WHDBO FRZP P RIH 22:51 00:00 1.15 7,075 7,075 DEMOB WHDBO FRZP P Displace well to seawater 02/10/2015 00:00 01:54 1.90 7,075 10 DEMOB WHDBO FRZP P Seawater out, POOH, Start loading CT with F/P diesel @ 5350', Pump 30BBIs diesel 01:54 02:48 0.90 10 0 DEMOB WHDBO FRZP P At surface, Shut master and lower swab, FSITP=870, PJSM. Pull BHA #28, Pull checks, Install jet nozzle 02:48 04:00 1.20 0 0 DEMOB WHDBO FRZP P Stab on well with nozzle, start corrosion inhibitor flush while jetting stack, Pump 30 BBIs Fresh water, 30 BBIs inhibited fresh water, 30 BBIs fresh water flush. 04:00 06:00 2.00 0 0 DEMOB WHDBO MPSP P PJSM, Unstab Injector, Lift BPV Lubricator, Install BPV 06:00 08:00 2.00 0 0 DEMOB WHDBO RURD P Blow down CT reel and riglines to tiger tank. Rig down MP (line and misc. cellar lines. Rig Release: 08:00 AM 08:00 12:00 4.00 0 0 DEMOB WHDBO NUND P Continue to prep rig for move to 30 -pad. ND BOPE, secure wellhead, check tree flange bolts. Lift and secure stack. Page 29 of 29 1 L-04 WELL WORK SUMMARY DATE SUMMARY POST RIG WELL WORK 2/13/2015 ASSIST VALVE CREW PULLING BPV (VALVE CREW UNIT BROKE DOWN). JOB SUSPENDED. 2/16/2015 MAKE MULTIPLE MAGNETS RUNS DOWN TO LINER TOP @ 7118' RKB (RECOVERING METAL SHAVINGS); MEASURE BHP @ 7118' RKB (3407 PSI); SET 2.81" CSV @ 7043' RKB; PULL DV & SET GLV @ 6450' RKB. IN PROGRESS. 2/17/2015 PULLED DVs, SET GI -Vs @ 5574', 4387', & 2807' RKB. ATTEMPTED SET OV @ 6892' SLM. IN PROGRESS. 2/18/2015 BRUSHED GLM. ATTEMPTED PULL DV @ 6904' RKB. IN PROGRESS. 2/19/2015 PULLED GLV @ 6450' RKB, REPLACED WITH 1/4" OV. BLED IA, CONFIRMED SET. PULLED CAT SV @ 7043' RKB. COMPLETE. ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 1 L Pad 1 L -04B 50-029-21179-02 Baker Hughes INTEQ Definitive Survey Report 10 February, 2015 ON Fag BAKER HUGHES Conoc6PNIIip5 +E/ -W Date 2/10/2015 SPAMI To Definitive Survey Report (usft) BAKER Survey (Wellbore) 200.00 7,200.00 HUGHES Company: ConocoPhillips (Alaska) inc. -Kup2 Local Co-ordinate Reference: Well 1 L-04 GCT -MS Project: Kuparuk River Unit TVD Reference: I L-04 @ 116. 00usft (I L-04) MWD - Standard Site: Kuparuk 1 L Pad MD Reference: I L-04 @ 11 6.00usft (I L-04) Well: 1L-04 North Reference: True Wellbore: I L-04 Survey Calculation Method: Minimum Curvature Design: 1L-04 Database: EDM Alaska Sandbox Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 .. ...... . . . .......... ----- - – ------- --- Using geodetic scale factor .... ..... .... ... Well I L-04 Well Position +N/ -S 0.00 usft Northing: 5,949,370.89 usft Latitude: 70' 16'21.420 N +E/ -W 0.00 usft Easting: 539,914.96 usft Longitude: 149'40'37.789 W Position ..' Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1L -04B hm-A-1 Vertical Section: Depth From (TVD) (usft) 116.00 -- — -------- --- Survey Program +E/ -W Date 2/10/2015 From To (1) (usft) (usft) Survey (Wellbore) 200.00 7,200.00 1 L-04 (I L-04) 7,208.00 9,595.28 1L -04B (I L-04 B) +N/ -S +E/ -W Direction (usft) (usft) (1) 0.00 0.00 180.00 Survey Survey Tool Name Description Start Date End Date GCT -MS Schlumberger GCT multishot 1/81200I MWD MWD - Standard 2/3/2015 2/8/2015 211012015 4:43:56PM Page 2 COMPASS 5000.1 Build 61 y ConoC®PhillIp5. Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 1 L-04 Project: Kuparuk River Unit TVD Reference: 1 L-04 @ 116.00usft (1 L-04) Site: Kuparuk 1 L Pad MD Reference: 1 L-04 @ 116.00usft (11--04) Well: 1L-04 North Reference: True Wellbore: 1L-04 Survey Calculation Method: Minimum Curvature Design: 1L-04 Database: EDM Alaska Sandbox Survey _.......-._.. - MD Inc Azi TVD TVDSS +N/ -S +E/ -W Map Map DLS Vertical (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (°1100') Section Survey Tool Name (ft) (ft) (ft) 7,200.00 31.23 341.62 5,970.23 5,854.23 3,394.93 -988.66 5,952,760.19 538,908.41 2.07 -3,394.93 MWD (2) 7,208.00 31.12 341.70 5,977.07 5,861.07 3,398.86 -989.96 5,952,764.12 538,907.08 1.47 -3,398.86 MWD (2) 7,240.46 42.56 342.00 6,003.01 5,887.01 3,417.32 -996.01 5,952,782.55 538,900.94 35.25 -3,417.32 MWD (2) 7,270.43 57.18 343.00 6,022.27 5,906.27 3,439.13 -1,002.86 5,952,804.31 538,893.97 46.85 -3,439.13 MWD (2) 7,300.47 71.63 344.45 6,035.21 5,919.21 3,465.07 -1,010.41 5,952,830.21 538,886.28 48.30 -3,465.07 MWD (2) 7,330.43 80.61 353.69 6,042.41 5,926.41 3,493.57 -1,015.87 5,952,856.68 538,880.68 42.34 -3,493.57 MWD (2) 7,360.43 84.78 8.07 6,046.24 5,930.24 3,523.24 -1,015.40 5,952,888,34 538,880.99 49.52 -3,523.24 MWD (2) 7,390.39 88.31 21.50 6,048.05 5,932.06 3,552.08 -1,007.78 5,952,917.22 538,888.46 46.26 -3,552.08 MWD (2) 7,420.36 89.57 33.60 6,048.61 5,932.61 3,578.60 -993.94 5,952,943.81 538,902.15 40.58 -3,578.60 MWD (2) 7,450.30 89.97 48.05 6,048.73 5,932.73 3,601.19 -974.42 5,952,966.51 536,921.55 48.28 -3,601.19 MWD (2) 7,480.27 88.00 62.65 6,049.27 5,933.27 3,618.18 -949.84 5,952,983.63 538,946.04 49.15 -3,618.18 MWD (2) 7,510.33 79.93 71.89 6,052.43 5,936.43 3,629.73 -922.33 5,952,995.32 538,973.48 40.66 -3,629.73 MWD (2) 7,540.15 78.02 83.60 6,058.15 5,942.15 3,635.94 -893.78 5,953,001.68 539,001.99 39.07 -3,635.94 MWD (2) 7,570.44 77.83 98.75 6,064.52 5,948.52 3,635.33 -864.26 5,953,001.23 539,031.51 48.91 -3,635.33 MWD (2) 7,595.51 78.18 111.60 6,069.76 5,953.76 3,628.93 -840.65 5,952,994.95 539,055,16 50.15 -3,628.93 MWD (2) 7,625.13 77.81 123.42 6,075.94 5,959.94 3,615.57 -815.00 5,952,981.73 539,080.87 39.05 -3,615.57 MWD (2) 7,655.16 76.77 126.24 6,082.55 5,966.55 3,598.84 -790.96 5,952,965.14 539,105.00 9.79 -3,598.84 MWD (2) 7,685.26 76.90 128.42 6,089.40 5,973.40 3,581.07 -767.66 5,952,947.49 539,128.40 7.07 -3,581.07 MWD (2) 7,715.37 76.48 131.53 6,096.34 5,980.34 3,562.25 -745.20 5,952,928.79 539,150.95 10.15 -3,562.25 MWD (2) 7,745.28 77.05, 134.17 6,103.18 5,987.18 3,542.45 -723.86 5,952,909.10 539,172.39 8.80 -3,542.45 MWD (2) 7,775.27 79.29 134.56 6,109.33 5,993.33 3,521.93 -702.88 5,952,888.69 539,193.48 7.58 -3,521.93 MWD (2) 7,805.21 81.96. 135.63 6,114.21 5,998.21 3,501.01 -682.03 5,952,867.89 539,214.44 9.59 -3,501.01 MWD (2) 7,835.40 84.68 136.36 6,117.72 6,001.72 3,479.44 -661.20 5,952,846.43 539,235.38 9.32 -3,479.44 MWD (2) 7,865.18 86.81 136.46 6,119.93 6,003.93 3,457.93 -640.72 5,952,825.04 539,255.97 7.16 -3,457.93 MWD (2) 7,895.30 89.79 137.46 6,120.82 6,004.82 3,435.93 -620.18 5,952,803.15 539,276.63 10.44 -3,435.93 MWD (2) 7,925.26 92.89 138.31 6,120.12 6,004.12 3,413.72 -600.09 5,952,781.04 539,296.83 10.73 -3,413.72 MWD (2) 7,955.28 93.65 140.03 6,118.41 6,002.41 3,391.04 -580.50 5,952,758.47 539,316.54 6.26 -3,391.04 MWD (2) 7,985.22 93.93 142.95 6,116.43 6,000.43 3,367.66 -561.90 5,952,735.20 539,335.26 9.78 -3,367.66 MWD (2) 8,015.24 93.47 145.42 6,114.49 5,998.49 3,343.37 -544.37 5,952,711.00 539,352.92 8.35 -3,343.37 MWD (2) 8,045.39 92.76. 148.24 6,112.65 5,996.85 3,318.18 -527.90 5,952,685.89 539,369.52 9.63 -3,318.16 MWD (2) Annotation TIP KOP MANS BAKER HUGHES 2/10/2015 4:43:56PM Page 3 COMPASS 5000.1 Build 61 ConocoPhillips Inc Azi F/%11 TVDSS Definitive Survey Report +El -W BAKER Map DLS Vertical HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 1 L-04 (usft ) Project: Kuparuk River Unit TVD Reference: 1L-04 @ 116.00usft (1L-04) Easting Site: Kuparuk 1 L Pad MD Reference: 1 L-04 @ 116.00usft (1 L-04) Well: 1L-04. North Reference: True Wellbore: 1 L-04 Survey Calculation Method: Minimum Curvature Design: 1 L-04 Database: EDM Alaska Sandbox 151.07 Survey 5,995.48 _. -512.71 MD Inc Azi TVD TVDSS +Nl-S +El -W Map Map DLS Vertical (usft) (°) (°) (usft (usft ) usft ( ) (usft ) Northing Easting Section Survey Tool Name Annotation (ft) (ft) (ft) 8,075.49 92.49 151.07 6,111.48 5,995.48 3,292.23 -512.71 5,952,660.03 539,384.84 9.43 -3,292.23 MWD (2) 8,105.35 93.07 153.91 6,110.03 5,994.03 3,265.78 -498.94 5,952,633.66 539,398.76 9.70 -3,265,78 MWD (2) 8,135.28 91.87 156.06 6,108.74 5,992.74 3,238.68 486.29 5,952,606.63 539,411.54 8.22 -3,238.68 MWD (2) 8,165.28 91.90 159.02 6,107.75 5,991.75 3,210.98 -474.84 5,952,578.99 539,423.14 9.66 -3,210.98 MWD (2) 8,195.13 92.30 161.64 6,106.66 5,990.66 3,182.89 -464.80 5,952,550,96 539,433.33 8.87 -3,182.89 MWD (2) 8,225,25 91.94 164.22 6,105.54 5,989.54 3,154.12 455.97 5,952,522.24 539,442.32 8.64 -3,154.12 MWD (2) 8,255.18 90.49 165.87 6,104.91 5,988.91 3,125.21 -448.25 5,952,493.37 539,450.19 7.34 -3,125.21 MWD (2) 8,285.26 90.40 168.07 6,104.67 5,968.67 3,095.91 -441.46 5,952,464.11 539,457.13 7,32 -3,095.91 MWD (2) 8,315.36 91.32 170.29 6,104.22 5,988.22 3,066,35 -435.81 5,952,434.58 539,462.93 7.98 -3,066.35 MWD (2) - 8,345.54 91.97 172.75 6,103.35 5,987.36 3,036.52 -431.37 5,952,404.78 539,467.54 8.43 -3,036.52 MWD (2) 8,375.47 89.79 174.23 6,102.90 5,986.90 3,006.78 -427.97 5,952,375.07 539,471,09 8.80 -3,006.78 MWD (2) 8,405.47 90.40 176.64 6,102.85 5;986.85 2,976.88 -425.59 5,952,345.18 539,473.63 8.29 -2,976.88 MWD (2) 8,435.34 90.15 176.15 6,102.70 5,986.70 2,947.07 -423.71 5,952,315.38 539,475.67 1.84 -2,947.07 MWD (2) 8,465,16 89.45 174.65 6,102.81 5,986.81 2,917,35 -421.32 5,952,285.68 539,478.22 5.55 -2,917.35 MWD (2) 8,493.81 90.12 173.70 6,102.91 5,986.91 2,888.85 -418.41 5,952,257.19 539,481.28 4.06 -2,888.85 MWD (2) 8,525.50 89.75 175.60 6,102.95 5,986.95 2,857.30 -415.45 5,952,225.66 539,484.40 6.11 -2,857.30 MWD (2) 8,555.56 90.43' 177.52 6,102.90 5,986.90 2,827.29 -413.65 5,952,195.67 539,486.36 6.78 -2,827.29 MWD (2) 8,585.58 91.54 179.06 6,102.39 5,986.39 2,797.29 -412.75 5,952,165.68 539,487.42 6.32 -2,797.29 MWD (2) 8,615.46 93.81 180.76 6,100.99 5,984.99 2,767.45 -412.71 5,952,135.84 539,487.62 9.49 -2,767.45 MWD (2) 8,645.06 96.24 18D.92 6,098.40 5,982.40 2,737.97 -413.14 5,952,106.36 539,487.35 B.23 -2,737.97 MWD (2) 8,675.19 98.20 182.20 6,094.61 5,978.61 2,708.09 -413.95 5,952,076.48 539,486.69 7.75 -2,708.09 MWD (2) 8,705.42 98.48 184.44 6,090.23 5,974.23 2,678.23 -415.68 5,952,046.62 539,485.12 7.39 -2,678.23 MWD (2) 8,740.44 95.69 184.55 6,085.91 5,969.91 2,643.59 -418.41 5,952,011.96 539,482.58 7.97 -2,643.59 MWD (2) 8,770.46 94.67 186.16 6,083.20 5,967.20 2,613.82 -421.20 5,951,982.19 539,479.95 6.33 -2,613.82 MWD (2) 8,800.25 93.01 186.50 6,081.20 5,965.20 2,584.28 424.48 5,951,952.63 539,476.83 5.69 -2,584.28 MWD (2) 8,830.52 91.38 187.30 6,080.04 5,964.04 2,554.25 -428.11 5,951,922.59 539,473.35 6.00 -2,554.25 MWD (2) 8,860.45 91.51 190.12 6,079.29 5,963.29 2,524.68 -432.64 5,951,892.99 539,468.98 9.43 -2,524.66 MWD (2) 8,890.56 91.17 192.89 6,078.58 5,962.58 2,495.19 -438.64 5,951,863.47 539,463.13 9.27 -2,495.19 MWD (2) 8,920.06 90.71 194.43 6,078.10 5,962.10 2,466.53 -445.61 5,951,834.78 539,456.32 5.45 -2,466.53 MWD (2) 8,950.24 88.46 194.48 6,076.32 5,962.32 2,437.31 -453.14 5,951,805.52 539,448.94 7.46 -2,437.31 MWD (2) 8,980.18 86.10 194.74 6,079.74 5,963.74 2,408.37 -460.68 5,951,776.54 539,441.55 7.93 -2,408.37 MWD (2) 2/10/2015 4.43.56PM Page 4 COMPASS 5000.1 Build 61 Conoc®PhillipS Inc Azi TVD Definitive Survey Report +N! -S Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 1L -04 -- L-04Project: Project: Kuparuk River Unit TVD Reference: IL -04 @ 116.00usft (IL -04) Site: Kuparuk 1 L Pad MD Reference: IL -04 @ 116.00usft (IL -04) Well: 1L-04 North Reference: True Wellbore: 1L-04 Survey Calculation Method: Minimum Curvature Design: 1L-04 Database: EDM Alaska Sandbox Survey 6,D81.82 _ MD Inc Azi TVD TVDSS +N! -S +El -W Map Map Vertical (usft) (1) M (usft) (usft) (usft) (usft) Northing East, ng (.1100,) Section y Annotation Survey Tool Name 9,010.42 86.00 196.96 6,D81.82 5,965.82 2,379.35 -468.92 (ft) 5,951,747.48 (ft) 539,433.47 7.33 (ft) -2,379.35 MWD (2) 9,040.44 85.14 198.78 6,084.14 5,958.14 2,350.86 -478.11 5,951,718.95 539,424.44 6.69 -2,350.86 MWD (2) 9,070.40 87.70 200.87 6,086.01 5,970.01 2,322.74 1186.25 5,951,69D.78 539,414.45 11.02 -2,322.74 MWD (2) 9,100.33 67.51 203.64 6,087.26 5,971.26 2,295.D7 -499.57 5,951,663.05 539,403.27 9.27 -2,295.07 MWD (2) 9,130.35 87.91 204.69 6,086.46 5,972.46 2,267.70 -511.85 5,951,635.62 539,391.14 3.74 -2,267.70 MWD (2) 9,160.39 89.08 206.52 6,089.25 5,973.25 2,240.62 -524.83 5,951,608.47 539,378.31 7.23 -2,240.62 MWD (2) 9,191.14 90.40 21D.45 6,089.39 5,973.39 2,213.60 -539.49 5,951,581.38 539,363.79 13.48 -2,213.60 MWD (2) 9,220.40 89.97 210.61 6,069.30 5,973.30 2,186.39 -554.35 5,951,556.10 539,349.06 1.57 -2,186.39 MWD (2) 9,250.30 89.17 213.41 6,089.52 5,973.52 2,163.04 -570.20 5,951,530.67 539,333.35 9.74 -2,163.D4 MWD (2) 9,280.29 88.86 215.30 6,090.04 5,974.04 2,138.29 -587.12 5,951,505.83 539,316.56 6.39 -2,138.29 MWD (2) 9,310.20 90.06 216.48 6,090.32 5,974.32 2,114.06 -604.65 5,951,481.51 539,299.16 5.63 -2,114.06 MWD (2) 9,340.50 90.98 218.91 6,090.04 5,974.04 2,090.09 -623.18 5,951,457.44 539,280.77 8.57 -2,090.09 MWD (2) 9,375.47 89.17 220.08 6,090.00 5,974.00 2,063.10 -645.42 5,951,430.34 539,258.67 6.16 -2,063.10 MWD (2) 9,405.42 88.40 218.38 6,090.63 5,974.63 2,039.91 -664.36 5,951,407.05 539,239.86 6.23 -2,039.91 MWD (2) 9,435.37 88.34 215.74 6,091.49 5,975.49 2,016.02 -682.40 5,951,383.07 539,221.95 8.81 -2,016.02 MWD (2) 9,470.16 88.53 212.96 6,092.44 5,976.44 1,987.31 -702.02 5,951,354.26 539,202.48 8.01 -1,987.31 MWD (2) 9,503.03 88.22. 211.84 6,093.37 5,977.37 1,959.57 -719.62 5,951,326.43 539,185.03 3.53 -1,959.57 MWD (2) 9,530.10 87.11 209.95 6,094.47 5,978.47 1,936.36 -733.51 5,951,303.15 539,171.26 8.09 -1,936.36 MWD (2) 9,561.06 86.74 207.60 6,096.13 5,980.13 1,909.27 -748.39 5,951,275.97 539,156.53 7.67 -1,909.27 MWD (2) 9,595.28 89.82 2D7.60 6,097.16 5,981.16 1,878.96 -764.23 5,951,245.59 539,140.85 9.00 -1,878.96 MWD (2) 9,635.00 89.82 2D7.60 6,097.28 5,981.28 1,843.76 -782.64 5,951,21D.29 539,122.63 0.00 -1,843.76 PROJECTEDtoTD HIM BAKER HUGHES 2/10/2015 4:43:56PM Page 5 COMPASS 5000.1 Build 61 --04 p7b Z1Vic;' Zug Regg, James B (DOA) From: NSK Prod Engr Specialist <nll39@conocophillips.com> Sent: Thursday, May 12, 2016 4:30 PM To: Bixby, Brian D (DOA); Regg, James B (DOA) Cc: NSK Fieldwide Operations Supt Subject: Requested Wellhouse Sign Photos 1L -04B, 2G -11A Attachments: Wellhouse Signs to AOGCC.pdf Enclosed are the requested photos showing new wellhouse signs for wells that were identified during State witnessed SVS testing in April. This should close out the Deficiency Reports for 1L -04B, 2G -11A wellhouses. ✓ Please let us know if you need anything further. Regards, Darrell Humphrey / Bob Christensen Production Engineering Specialist Conocophillips Alaska Inc. nll39@conocophillips.com Office (907) 659-7535 Pager (907) 659-7000 #924 QW ConocoPhillips Alaska Well Name: KRU 11-04B I API Number: 50-029-2117902-00 PTD: 215-020-0 Sur. Location: 4877' FNLo 144' FEL, Sec. 30, TIM RIOEo UM in iQ Iq 0 10 CC A AO pe to . Arm c own use; any other use or by any other party pr ithout written consent of hillips Alaska, Inc. FKA a 2 BAKER HUGHES To: RECEIVED FEB 13 2015 Letter of Transmittal Date:'' w DATA LOGGED February13 2015 Zi'3mi8 ' M. K. BENDER Makana Bender AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 From: Yosha Ragbirsingh / Michael Soper Baker Hughes INTEQ 795 East 94th Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 1L-04APB1 1L-04APB2 1L-04AL4PB1 1L -04B 214-158 25396 214-158 25397 215-019 25398 215-020 25399 DISC IN 1L -04B (4) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael. Soper@BakerHughes.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Raizbirsin2ha,BakerHuiahes. com ConocoPs Philli ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 1 L Pad 1 L -04B 50-029-21179-02 Baker Hughes I NTEQ Definitive Survey Report 10 February, 2015 21 5020 25399 lEv FEB 13 2015 AOGCC WMA FA I BAKER HUGHES Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) (usft) 116.00 Survey Program Date 2/10/2015 From To Tie On Depth: 7,200.00 +N/ -S +E/ -W (usft) (usft) 0.00 0.00 (usft) (usft) Survey (Wellbore) Tool Name ConocoPhillips Definitive Survey Report 1 L-04 (1 L-04) HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 1 L-04 MWD Project: Kuparuk River Unit TVD Reference: 1 L-04 @ 116.00usft (1 L-04) Site: Kuparuk 1 L Pad MD Reference: 1 L-04 @ 116.00usft (1 L-04) Well: 1 L-04 North Reference: True Wellbore: 1 L-04 Survey Calculation Method: Minimum Curvature Design: 1 L-04 Database: EDM Alaska Sandbox Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1 L-04 Well Position +N/ -S 0.00 usft Northing: 5,949,370.89 usft Latitude: 70° 16'21.420 N +E/ -W 0.00 usft Easting: 539,914.96usft Longitude: 149° 40'37.789 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1L -04B Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I (°) (nT) BG G M 2014 12/1/2014 19.12 80.89 57,571 Design 1L -04B Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) (usft) 116.00 Survey Program Date 2/10/2015 From To Tie On Depth: 7,200.00 +N/ -S +E/ -W (usft) (usft) 0.00 0.00 (usft) (usft) Survey (Wellbore) Tool Name 200.00 7,200.00 1 L-04 (1 L-04) GCT -MS 7,208.00 9,595.28 1L -04B (1L-0413) MWD Description Schlumberger GCT multishot MWD - Standard Direction (1) 180.00 Survey Survey Start Date End Date 1/8/2001 2/3/2015 2/8/2015 2/10/2015 4:43:56PM Page 2 COMPASS 5000.1 Build 61 ConocoPhillips Company: Project: Site: Well: Wellbore: Design: Survey l MD (usft) 7,200.00 7,208.00 7,240.46 7,270.43 7,300.47 7,330.43 7,360.43 7,390.39 7,420.36 7,450.30 7,480.27 7,510.33 7,540.15 7,570.44 7,595.51 7,625.13 7,655.16 7,685.26 i 7,715.37 7,745.28 7,775.27 7,805.21 7,835.40 7,865.18 7,895.30 7,925.26 7,955.28 z 7,985.22 8,015.24 8,045.39 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 1 L Pad 1 L-04 1 L-04 1 L-04 Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 1 L-04 1 L-04 @ 116.00usft (1 L-04) 1 L-04 @ 116.00usft (1 L-04) True Minimum Curvature EDM Alaska Sandbox ri.I BAKER HUGHES t Inc Azi TVD TVDSS +N/ -S +E/ -W Map Map DLS Vertical (°) (°) (usft) (usft) (usft) (usft) Northing Easting (°/100') Section Survey Tool Name Annotation Y (ft) (ft) (ft) 31.23 341.62 5,970.23 5,854.23 3,394.93 -988.66 5,952,760.19 538,908.41 2.07 -3,394.93 MWD (2) TIP 31.12 341.70 5,977.07 5,861.07 3,398.86 -989.96 5,952,764.12 538,907.08 1.47 -3,398.86 MWD (2) KOP 42.56 342.00 6,003.01 5,887.01 3,417.32 -996.01 5,952,782.55 538,900.94 35.25 -3,417.32 MWD (2) 57.18 343.00 6,022.27 5,906.27 3,439.13 -1,002.86 5,952,804.31 538,893.97 48.85 -3,439.13 MWD (2) 71.63 344.45 6,035.21 5,919.21 3,465.07 -1,010.41 5,952,830.21 538,886.28 48.30 -3,465.07 MWD (2) 80.61 353.69 6,042.41 5,926.41 3,493.57 -1,015.87 5,952,858.68 538,880.68 42.34 -3,493.57 MWD (2) 84.78 8.07 6,046.24 5,930.24 3,523.24 -1,015.40 5,952,888.34 538,880.99 49.52 -3,523.24 MWD (2) 88.31 21.50 6,048.05 5,932.06 3,552.08 -1,007.78 5,952,917.22 538,888.46 46.26 -3,552.08 MWD (2) 89.57 33.60 6,048.61 5,932.61 3,578.60 -993.94 5,952,943.81 538,902.15 40.58 -3,578.60 MWD (2) 89.97 48.05 6,048.73 5,932.73 3,601.19 -974.42 5,952,966.51 538,921.55 48.28 -3,601.19 MWD (2) 88.00 62.65 6,049.27 5,933.27 3,618.18 -949.84 5,952,983.63 538,946.04 49.15 -3,618.18 MWD (2) 79.93 71.89 6,052.43 5,936.43 3,629.73 -922.33 5,952,995.32 538,973.48 40.66 -3,629.73 MWD (2) 78.02 83.60 6,058.15 5,942.15 3,635.94 -893.78 5,953,001.68 539,001.99 39.07 -3,635.94 MWD (2) 77.83 98.75 6,064.52 5,948.52 3,635.33 -864.26 5,953,001.23 539,031.51 48.91 -3,635.33 MWD (2) 78.18 111.60 6,069.76 5,953.76 3,628.93 -840.65 5,952,994.95 539,055.16 50.15 -3,628.93 MWD (2) 77.81 123.42 6,075.94 5,959.94 3,615.57 -815.00 5,952,981.73 539,080.87 39.05 -3,615.57 MWD (2) 76.77 126.24 6,082.55 5,966.55 3,598.84 -790.96 5,952,965.14 539,105.00 9.79 -3,598.84 MWD (2) 76.90 128.42 6,089.40 5,973.40 3,581.07 -767.66 5,952,947.49 539,128.40 7.07 -3,581.07 MWD (2) 76.48 131.53 6,096.34 5,980.34 3,562.25 -745.20 5,952,928.79 539,150.95 10.15 -3,562.25 MWD (2) 77.05 134.17 6,103.18 5,987.18 3,542.45 -723.86 5,952,909.10 539,172.39 8.80 -3,542.45 MWD (2) 79.29 134.56 6,109.33 5,993.33 3,521.93 -702.88 5,952,888.69 539,193.48 7.58 -3,521.93 MWD (2) 81.96 135.63 6,114.21 5,998.21 3,501.01 -682.03 5,952,867.89 539,214.44 9.59 -3,501.01 MWD (2) 84.68 136.36 6,117.72 6,001.72 3,479.44 -661.20 5,952,846.43 539,235.38 9.32 -3,479.44 MWD (2) 86.81 136.46 6,119.93 6,003.93 3,457.93 -640.72 5,952,825.04 539,255.97 7.16 -3,457.93 MWD (2) 89.79 137.46 6,120.82 6,004.82 3,435.93 -620.18 5,952,803.15 539,276.63 10.44 -3,435.93 MWD (2) 92.89 138.31 6,120.12 6,004.12 3,413.72 -600.09 5,952,781.04 539,296.83 10.73 -3,413.72 MWD (2) 93.65 140.03 6,118.41 6,002.41 3,391.04 -580.50 5,952,758.47 539,316.54 6.26 -3,391.04 MWD (2) 93.93 142.95 6,116.43 6,000.43 3,367.66 -561.90 5,952,735.20 539,335.26 9.78 -3,367.66 MWD (2) 93.47 145.42 6,114.49 5,998.49 3,343.37 -544.37 5,952,711.00 539,352.92 8.35 -3,343.37 MWD (2) 92.76 14824 6,112.85 5,996.85 3,318.18 -527.90 5,952,685.89 539,369.52 9.63 -3,318.18 MWD (2) 2/10/2015 4:43.56PM Page 3 COMPASS 5000.1 Build 61 J� ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 1 L Pad Well: 1 L-04 Wellbore: 1 L-04 Design: 1 L-04 Survey Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 1 L-04 1 L-04 @ 116.00usft (IL -04) 1 L-04 @ 116.00usft (1L-04) True Minimum Curvature EDM Alaska Sandbox MD Inc Azi TVD TVDSS +Ni -S +E/ -W Map Map Vertical (usft) V) V) (usft) (usft) (usft) (usft) Northing Easting (0 00) Section Survey Tool Name Annotation (ft) (ft ) (ft) 8,075.49 92.49 151.07 6,111.48 5,995.48 3,292.23 -512.71 5,952,660.03 539,384.84 9.43 -3,292.23 MWD (2) 8,105.35 93.07 153.91 6,110.03 5,994.03 3,265.78 -498.94 5,952,633.66 539,398.76 9.70 -3,265.78 MWD (2) 8,135.28 91.87 156.06 6,108.74 5,992.74 3,238.68 -486.29 5,952,606.63 539,411.54 8.22 -3,238.68 MWD (2) 8,165.28 91.90 159.02 6,107.75 5,991.75 3,210.98 -474.84 5,952,578.99 539,423.14 9.86 -3,210.98 MWD (2) 8,195.13 92.30 161.64 6,106.66 5,990.66 3,182.89 -464.80 5,952,550.96 539,433.33 8.87 -3,182.89 MWD (2) 8,225.25 91.94 164.22 6,105.54 5,989.54 3,154.12 -455.97 5,952,522.24 539,442.32 8.64 -3,154.12 MWD (2) 8,255.18 90.49 165.87 6,104.91 5,988.91 3,125.21 -448.25 5,952,493.37 539,450.19 7.34 -3,125.21 MWD (2) 8,285.26 90.40 168.07 6,104.67 5,988.67 3,095.91 -441.46 5,952,464.11 539,457.13 7.32 -3,095.91 MWD (2) 8,315.36 91.32 170.29 6,104.22 5,988.22 3,066.35 -435.81 5,952,434.58 539,462.93 7.98 -3,066.35 MWD (2) 8,345.54 91.97 172.75 6,103.35 5,987.36 3,036.52 -431.37 5,952,404.78 539,467.54 8.43 -3,036.52 MWD (2) 8,375.47 89.79 174.23 6,102.90 5,986.90 3,006.78 -427.97 5,952,375.07 539,471.09 8.80 -3,006.78 MWD (2) 8,405.47 90.40 176.64 6,102.85 5,986.85 2,976.88 -425.59 5,952,345.18 539,473.63 8.29 -2,976.88 MWD (2) 8,435.34 90.15 176.15 6,102.70 5,986.70 2,947.07 -423.71 5,952,315.38 539,475.67 1.84 2,947.07 MWD (2) 8,465.16 89.45 174.65 6,102.81 5,986.81 2,917.35 -421.32 5,952,285.68 539,478.22 5.55 -2,917.35 MWD (2) 8,493.81 90.12 173.70 6,102.91 5,986.91 2,888.85 418.41 5,952,257.19 539,481.28 4.06 -2,888.85 MWD (2) 8,525.50 a 89.75 175.60 6,102.95 5,986.95 2,857.30 415.45 5,952,225.66 539,484.40 6.11 -2,857.30 MWD (2) 1 8,555.56 90.43 177.52 6,102.90 5,986.90 2,827.29 413.65 5,952,195.67 539,486.36 6.78 -2,827.29 MWD (2) 8,585.58 91.54 179.06 6,102.39 5,986.39 2,797.29 -412.75 5,952,165.68 539,487.42 6.32 -2,797.29 MWD (2) 8,615.46 93.81 180.76 6,100.99 5,984.99 2,767.45 -412.71 5,952,135.84 539,487.62 9.49 -2,767.45 MWD (2) d 8,645.06 96.24 180.92 6,098.40 5,982.40 2,737.97 -413.14 5,952,106.36 539,487.35 8.23 -2,737.97 MWD (2) 8,675.19 98.20 182.20 6,094.61 5,978.61 2,708.09 -413.95 5,952,076.48 539,486.69 7.75 -2,708.09 MWD (2) 8,705.42 98.48 184.44 6,090.23 5,974.23 2,678.23 -415.68 5,952,046.62 539,485.12 7.39 -2,678.23 MWD (2) 8,740.44 t 95.69 184.55 6,085.91 5,969.91 2,643.59 -418.41 5,952,011.96 539,482.58 7.97 -2,643.59 MWD (2) 8,770.46 94.67 186.16 6,083.20 5,967.20 2,613.82 -421.20 5,951,982.19 539,479.95 6.33 -2,613.82 MWD (2) 8,800.25 93.01 186.50 6,081.20 5,965.20 2,584.28 -424.48 5,951,952.63 539,476.83 5.69 -2,584.28 MWD (2) 8,830.52 91.38 187.30 6,080.04 5,964.04 2,554.25 -428.11 5,951,922.59 539,473.35 6.00 -2,554.25 MWD (2) % 8,860.45 91.51 190.12 6,079.29 5,963.29 2,524.68 -432.64 5,951,892.99 539,468.98 9.43 -2,524.68 MWD (2) 8,890.56 91.17 192.89 6,078.58 5,962.58 2,495.19 -438.64 5,951,863.47 539,463.13 9.27 -2,495.19 MWD (2) 8,920.06 90.71 194.43 6,078.10 5,962.10 2,466.53 -445.61 5,951,834.78 539,456.32 5.45 -2,466.53 MWD (2) 8,950.24 88.46 194.48 6,078.32 5,962.32 2,437.31 -453.14 5,951,805.52 539,448.94 7.46 -2,437.31 MWD (2) 8,980.18 86.10 194.74 6,079.74 5,963.74 2,408.37 -460.68 5,951,776.54 539,441.55 7.93 -2,408.37 MWD (2) rial BAKER HUGHES 2110/2015 4:43:56PM Page 4 COMPASS 5000.1 Build 61 NAM ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 1 L-04 Project: Kuparuk River Unit TVD Reference: 1 L-04 @ 116.00usft (1 L-04) Site: Kuparuk 1 L Pad MD Reference: 1 L-04 @ 116.00usft (1 L-04) Well: 1L-04 North Reference: True Wellbore: 1 L-04 Survey Calculation Method: Minimum Curvature Design: 1L-04 Database: EDM Alaska Sandbox Survey MD Inc Azi TVD TVDSS +N/ -S +E/ -W Map Map DLS Vertical (usft) (°) (°) (usft (usft) (usft) (usft Northing Easting (°/100') Section Survey Tool Name Y (ft) (ft) (ft) 9,010.42 86.00 196.96 6,081.82 5,965.82 2,379.35 -468.92 5,951,747.48 539,433.47 7.33 -2,379.35 MWD (2) 9,040.44 85.14 198.78 6,084.14 5,968.14 2,350.86 -478.11 5,951,718.95 539,424.44 6.69 -2,350.86 MWD (2) 9,070.40 87.70 200.87 6,086.01 5,970.01 2,322.74 -488.25 5,951,690.78 539,414.45 11.02 -2,322.74 MWD (2) 9,100.33 87.51 203.64 6,087.26 5,971.26 2,295.07 -499.57 5,951,663.05 539,403.27 9.27 -2,295.07 MWD (2) 9,130.35 87.91 204.69 6,088.46 5,972.46 2,267.70 -511.85 5,951,635.62 539,391.14 3.74 -2,267.70 MWD (2) 9,160.39 89.08 206.52 6,089.25 5,973.25 2,240.62 -524.83 5,951,608.47 539,378.31 7.23 -2,240.62 MWD (2) 9,191.14 90.40 210.45 6,089.39 5,973.39 2,213.60 -539.49 5,951,581.38 539,363.79 13.48 -2,213.60 MWD (2) 9,220.40 89.97 210.61 6,089.30 5,973.30 2,188.39 -554.35 5,951,556.10 539,349.06 1.57 -2,188.39 MWD (2) 9,250.30 89.17 213.41 6,089.52 5,973.52 2,163.04 -570.20 5,951,530.67 539,333.35 9.74 -2,163.04 MWD (2) 9,280.29 88.86 215.30 6,090.04 5,974.04 2,138.29 -587.12 5,951,505.83 539,316.56 6.39 -2,138.29 MWD (2) 9,310.20 90.06 216.48 6,090.32 5,974.32 2,114.06 -604.65 5,951,481.51 539,299.16 5.63 -2,114.06 MWD (2) 9,340.50 90.98 218.91 6,090.04 5,974.04 2,090.09 -623.18 5,951,457.44 539,280.77 8.57 -2,090.09 MWD (2) 9,375.47 89.17 220.08 6,090.00 5,974.00 2,063.10 -645.42 5,951,430.34 539,258.67 6.16 -2,063.10 MWD (2) 9,405.42 88.40 218.38 6,090.63 5,974.63 2,039.91 -664.36 5,951,407.05 539,239.86 6.23 -2,039.91 MWD (2) 9,435.37 88.34 215.74 6,091.49 5,975.49 2,016.02 -682.40 5,951,383.07 539,221.95 8.81 -2,016.02 MWD (2) 9,470.16 88.53 212.96 6,092.44 5,976.44 1,987.31 -702.02 5,951,354.26 539,202.48 8.01 -1,987.31 MWD (2) 9,503.03 88.22 211.84 6,093.37 5,977.37 1,959.57 -719.62 5,951,326.43 539,185.03 3.53 -1,959.57 MWD (2) 9,530.10 87.11 209.95 6,094.47 5,978.47 1,936.36 -733.51 5,951,303.15 539,171.26 8.09 -1,936.36 MWD (2) 9,561.06 86.74 207.60 6,096.13 5,980.13 1,909.27 -748.39 5,951,275.97 539,156.53 7.67 -1,909.27 MWD (2) 9,595.28 89.82 207.60 6,097.16 5,981.16 1,878.96 -764.23 5,951,245.59 539,140.85 9.00 -1,878.96 MWD (2) 9,635.00 89.82 207.60 6,097.28 5,981.28 1,843.76 -782.64 5,951,210.29 539,122.63 0.00 -1,843.76 PROJECTED to TO Annotation 2/10/2015 4:43:56PM Page 5 COMPASS 5000.1 Build 61 THE STATE °fALASKA GOVERNOR BILL WALKER D. Venhaus CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1 L -04B ConocoPhillips Alaska, Inc. Permit No: 215-020 Surface Location: 403' FSL, 144' FEL, SEC. 30, TI 1N, RI OE, UM Bottomhole Location: 1441' FSL, 1167' FEL, SEC. 30, T1 IN, R10E, UM Dear Mr. Venhaus: 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 AOGCC 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 AOGCC 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 an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Commissioner V J DATED this 3 day of February, 2015. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 FFR 0 2 ?.015 1 a. Type of Work: 1 b Proposed Well Class: Development - Oil ❑ Service - Winj ❑ Single Zone ❑ Drill r�, J* Lateral Stratigraphic Test ❑ Development -Gas ❑ Service - Supply ❑ Multiple Zone ❑ Redrill Reentry Exploratory ❑ Service - WAG ❑ Service - Disp ❑ -b/ 1c. Specify if well is proposed for: Coalbed Gas ❑ Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: KRU 1L -04B 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 10550' TVD: 6095' 12. Field/Pool(s): Kuparuk River Field Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): Surface: 403' FSL, 144' FEL, Sec. 30, T11 N, R10E, UM Top of Productive Horizon: 1578' FNL, 580' FEL, Sec. 30, T11 N, R10E, UM Total Depth: 1441' FSL, 1167' FEL, Sec. 30, T11 N, R10E, UM 7. Property Designation (Lease Number): ADL 25659 8. Land Use Permit: 2585 13. Approximate Spud Date: 2/2/2015 9. Acres in Property: 2490 14. Distance to Nearest Property: 18630 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 539915 y- 5949371 Zone- 4 10. KB Elevation above MSL: 116 feet GL Elevation above MSL: 86 feet 15. Distance to Nearest Well Open to Same Pool: 1 L-02, 345' 16. Deviated wells: Kickoff depth: Maximum Hole Angle: 7230 ft. 95° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4135 psig Surface: 3531 psig 18. Casing Program: Specifications Hole Casing Weight Grade Coupling Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L-80 ST -L 2450' 8100' 6134' 10550' 6095' 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) 7668 6371 none Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) 1 7538 6259 7134 Casing Length Size Cement Volume MD TVD Conductor/Structural 65' 16 210 sx Cold Set II 96' 96' Surface 2312' 9.625 830 sx AS III, 250 sx CI G 2343' 2243' Intermediate Production 7597' 7 600 sx Class G, 150 sx AS 1 7625' 6334' Liner Perforation Depth MD (ft): 7201'-7214', 7316'-7331', 7347'-7377' Perfora tion Depth TVD (ft): 5971'-5982', 6070'-6082', 6096'-6122' 20. Attachments: Property Plat ❑ BOP Sketch ❑ Diverter Sket& ❑ Drilling Prograrr ❑✓ Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements ❑ 21. Verbal Approval: Commission Representative: 22. 1 hereby certify that the foregoing is true and correct. Printed Name D. Ven us Signature' Date: Contact Gary Eller @ 263-4172 Email J.Garv.Eller(d)cop.com Title CTD Engineering Supervisor Phone: 263-4372 Date 2., 2_5 Commission Use Only Permit to Drill Number: 021��-Q,�(, API Number: '\ 50-0 9-�a��7-02,E-0V Permit Approval Date: See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed m thane, gas hydrates, or gas contained in shales: Other: 3D P fa 4 b e OF>5 i Samples req'd: Yes No [ Mud log req'd: Yes ❑ No � y yY1 „ VC ✓G "1 fZ 0- f--S� 1-12S measures: Yes [�] No Directional svy req'd: Yes [Z No fa v 51 Spacing exception req'd: Yes ❑ No Inclination -only svy req'd: Yes ❑ No P V D Y T E J Approved by: COMMISSIO E ISI N Date: ( f Fnrm in -Ani (R—used 10/2012 This ermit is valid f 4 s t 120 AAC 25 ;-,-L- 2-1,311-5- p e e rova ( .005(g)) I, Conocophillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 2, 2015 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: FEB 0 2 2015 A®GCC ConocoPhillips Alaska, Inc. has experienced complications while drilling the KRU 1 L -04A sidetrack (214-158) that have forced us to abandon drilling efforts of all coiled tubing drilling laterals to the north of 1 L-04. We are progressing with drilling of the previously p southern laterals, but the loss of the planned `A' sidetrack requires that the names of these southern laterals be changed so at production can ultimately be properly booked to this well. Accordingly, ConocoPhillips requests the AOGCC to do the following: • Please cancel the drilling permits for KRU 1 L-04AL3 (214-161) and 1 L-04AL3-01 (214-162) • Please approve replacement permit -to -drill applica itit ons 1 L -04B and 1 L-04BEl respectively. Please note that these replacement permit -to -drill applications are identical to the previously approved applications for 1 L-04AL3 and 1 L-04AL3-01 except for the naming convention. Window milling of the 1 L -04B sidetrack is expected to commence on February 3, 2015 (i.e. tomorrow) so your prompt attention to this matter is greatly appreciated. Attached to this application are the following documents: — 10-401 Applications for 1 L -04B and 1 L-04131-1 — Detailed Summary of Operations (revisions shown in red) — Directional Plans for 1 L -04B and 1 L-04BL1 — Proposed CTD Schematic If you have any questions or require additional information please contact me at 907-263-4172. Gary Eller ConocoPhillipsziska Coiled Tubing Drilling Engineer Kuparuk CTD Laterals NABORSAALASKA 1 L -04A, AL4, AL1, AL21 B & 131-1CD Application for Permit to Drill Document 2RC 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(0 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............................................................................................................. 5 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................ 5 Summaryof Operations...................................................................................................................................................5 PressureDeployment of BHA..........................................................................................................................................6 LinerRunning...................................................................................................................................................................7 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 7 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 7 15. Directional Plans for Intentionally Deviated Wells....................................................................... 7 (Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 7 16. Attachments....................................................................................................................................7 Attachment 1: Directional Plan for 1 L -04B & BL1............................................................................................................7 Attachment 2: Current Well Schematic...........................................................................................................................7 Attachment 3: Proposed Well Schematic for 1 L -04B CTD Laterals................................................................................7 Page 1 of 7 ORIGINAL February 02, 2015 PTD Application: 1 L -04A, 1 L-04AL4, 1 L-04AL1, 1 L-04NL2, 1 L -04B & 1 L-04BL1 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 1 L -04A, 1 L-04AL4. 1 L-04AL1, 1 L-04AL2, 1 L -04B & 1 L- 04131-1. All laterals will be classified as "Development— Oil" wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See the attached 10-401 form for surface and subsurface coordinates of the 1 L -04A, 'i L-04AL4, 1 L-04AL1, 1 L-04AL2, 1 L -04B & 1 L-0461-1. 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 the maximum formation pressure in the area of 4135 psi in well 1 L-05, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3531 psi. 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 AAC 25.005 (c)(4)(a)) A static bottom hole pressure of 1 L-04 in June 2014 indicated a reservoir pressure of 2796 psi or 8.9 ppg equivalent mud weight. The maximum down hole pressure in the 1 L-04 pattern is at 1 L-04. The highest pressure in an offset well is at the 1 L-05 injector to the east with 4135 psi, or 13.1 ppg EMW. Using the 1 L-05 pressure as the maximum possible, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3531 psi. We do not expect to encounter this magnitude of formation pressure while drilling the 1 L-04 laterals since they are oriented drilled north -south along a line of producers. In fact, it's likely that we will drill into areas of reduced formation pressure. Well 1 F-09 to the north recently measured A -sand formation pressure of 7.3 ppg EMW. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled but both the 1 L and 1 F pads are active gas injection sites. There is a distinct potential that free gas could be associated with any formation influx. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) An expected risk of 1 L-04 is the hole stability through the A5 & A4 basal shales. We will use MPD techniques to target a constant 11.4 ppg formation pressure while drilling and completing all laterals. There is a risk of differential sticking since we're drilling into areas of reduced formation pressure. There are limited backup window exit locations in 1 L-04. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) N/A for this thru-tubing drilling operation. According to 20 AAC 25.030(1), thru-tubing drilling operations need not perform additional formation integrity tests. Page 2 of 7 ORIGINAL February 02, 2015 PTD Application: 1 L -04A, 1 L-04AL4, 1 L-04AL1, 1 L-04AL2, 1 L -04B & 1 L -0413L1 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Top MD Name MD MD TVDSS TVDSS Liner Details 1L -04A 8020' 8850' 5983' 5984' No liner just anchored aluminum billet 1L-04AL4 10300' 11700' 5983' 6000' 2%", 4.7#, L-80, ST -L slotted liner; with 36.0 J-55 BTC 0' 2343' aluminum billet 1L-04AL1 8100' 11700' 6094' 6078' 23/", 4.7#, L-80, ST -L slotted liner; with J-55 BTC 0' 7625' 0' aluminum billet 1L-04AL2 7240' 10200' 6004' 6064' 23/8', 4.7#, L-80, ST -L slotted liner with EUE-MOD 0' 1 7092' 0' 5879' 1 de to ment sleeve 1L -04B 8100' 10550' 6134' 6095' 23/8', 4.7#, L-80, ST -L slotted liner; with aluminum billet 1 L-04BL1 7120' 10575' 5902' 6054' 23/8', 4.7#, L-80, ST -L slotted liner with deployment sleeve Existing Casing/Liner Information Category OD Weight (ppf) Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.50 H-40 Welded 0' 96' 0' 96' 1640 630 Surface 9-5/8" 36.0 J-55 BTC 0' 2343' 0' 2243' 3520 2020 Casing 7" 26 J-55 BTC 0' 7625' 0' 6334' 4980 4320 Tubing 3'/2" 9.3 L-80 EUE-MOD 0' 1 7092' 0' 5879' 1 10160 10530 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not 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 - Window milling operations: Chloride -based Flo -Pro mud (9.6 ppg) - Drilling operations: Chloride -based Flo -Pro mud (9.6 ppg). This mud weight should hydrostatically overbalance reservoir pressure. However, if increased formation pressure is encountered then overbalanced conditions will be maintained using MPD practices described below. - Completion operations: 1L-04 does not contain a subsurface safety valve (SSSV). The well will be loaded with 11.6 ppg NaBr completion fluid in order to provide formation over -balance while running completions. - Emergency Kill Weight fluid: Two well bore volumes (-285 bbl) of 13.1 ppg emergency kill weight fluid will be within a short drive to the rig during drilling operations. Page 3 of 7 ORIGINAL February 02, 2015 PTD Application: 1 L -04A, 1 L-04AL4, 1 L-04AL1, 1 L-04AL2, 1 L -04B & 1 L-0461-1 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 providing an overbalance on the reservoir. Through experience with drilling CTD laterals in the Kuparuk sands, 11.4 ppg has been identified as the minimum EMW to ensure stability of shale sections. The constant BHP target will be adjusted to maintain overbalanced conditions if increased reservoir pressure is encountered during drilling. The constant BHP target will be maintained utilizing the surface choke. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 1L -04A Window (7250' MD, 6013' TVD) Usinq MPD 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. Page 4 of 7 0. D I GINAL February 02, 2015 Pumps On 1.5 bpm) Pumps Off A -sand Formation Pressure (8.9 ) 2783 psi 2783 psi Mud Hydrostatic 9.6 p) 3002 psi 3002 psi Annular friction i.e. ECD, 0.060psi/ft) 435 psi 0 psi Mud + ECD Combined 3437 psi 3386 psi (no choke pressure) (overbalanced (overbalanced —650psi) —220 psi) Target BHP at Window (11.4 p) 3564 psi 3564 psi Choke Pressure Required to Maintain 130 psi 560 psi Target BHP 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. Page 4 of 7 0. D I GINAL February 02, 2015 PTD Application: 1 L -04A, 1 l_-04AL4, 1 L-04AL1, 1 L-04AL2, 1 L -04B & 1 L-04131_1 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well 1L-04 is a Kuparuk A -sand producer (development) well equipped with 3'/2" tubing and 7" production casing. Six laterals from well 1L-04 will be drilled, four to the north (1L -04A, AL4, AL1, & AL2) and two to the south (1 L -04B & BL I ) to augment A sand production from 1 F-09 to the north and 1 L-02 to the south. Operations will target the A4 and A5 sand intervals. Well 1L-04 was completed into the Kuparuk A and C -sand intervals in 1984 as a commingled single completion. In 1998 the C -sand perfs were cement squeezed to make an A -only producer. A RWO was performed earlier this year to replace the existing tubing with a stacked packer completion above the failed packer and change the IC packoffs. Prior to CTD operations, the existing A -sand perfs in will be squeezed with cement to provide a means to kick out of the 7" casing. ConocoPhillips has submitted at 10-403 sundry application for a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A -sand perfs in this manner. Immediately prior to cementing the A -sand perfs, the D -nipple at 7128' MD will be milled out to a 2.80" fD and the tubing tail will be perforated. Both of these operations are needed to prepare the well for CTD operations. After plugging off the existing A -sand perfs with cement pre -rig, the Nabors CDR2-AC drilling rig will drill a pilot hole to 7280' and set a whipstock in the 2.80" pilot hole at the planned kickoff point. All northern laterals will exit through the 7" casing at 7240' MD and will target the A4 & A5 sands. All southern laterals will exit through a second exit in the 7" casing at 7225' MD and will also target the A4 & A5 sands. The laterals will be completed with 23/8" slotted liner from TD with the final liner top located inside the 3'/2" tubing. Pre -CTD Work 1. Slickline: Dummy all GLVs. 2. E -line: Shoot 2' of holes in the 3'/2" tubing tail at 7120' MD. 3. Coil: Mill out Cameo D -nipple at 7128' MD to 2.80" 4. Coil: Cement squeeze the A -sand perfs bringing cement up into the tubing tail. 5. Slickline: Drift tubing, tag top of cement and pressure test. 6. Prep site for Nabors CDR2-AC, including setting BPV Rid Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1L -04A Sidetrack (A4 sand - north) a. Drill 2.80" high -side pilot hole through cement to 7280' MD b. Caliper pilot hole c. Set whipstock at 7250' MD (actually set 7240' due to hole problems) d. Mill 2.80" window at 7250' MD (TOWS at 7240') e. Drill 31/4' bi-center lateral to TD of 11,700' MD (could not drill past fault at 8850') f. Run 23/8" slotted liner with an aluminum billet from TD up to 10,300' MD (Plan to set an anchored billet at 8020' MD but, did not run liner since we plan to drill in the same sand just to the east. IL -04A expected to remain open to production without any liner installed) Page 5 of 7 ORIGINAL February 02, 2015 PTD Application: 1 L -04A, 1 L-04AL4, 1 L-04AL1, 1 L-04AL2, 1 L -04B & 1 L-0461_1 3. 1L-04AL4 Lateral (A4 sand - north) a. Kick off of the aluminum billet at 8,020' MD b. Drill 31/4" bi-center lateral to TD of 1 1,700' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 10,300' MD 1L-04AL1 Lateral (A5 sand - north) a. Kick off of the aluminum billet at 10,300' MD b. Drill 3'/4" bi-center lateral to TD of 11,700' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 8100' MD 5. 1L-04AL2 Lateral (A5 sand - north) a. Kick off of the aluminum billet at 8100' MD b. Drill 3/4" bi-center lateral to TD of 10,200' MD c. Run 23/8" slotted liner from TD up to 7240' MD 6. 1 L -04B Lateral (A4 sand - south) a. Set whipstock at 7230' MD b. Mill 2.80" window at 7230' MD c. Drill 3" bi-center lateral to TD of 10,550' MD d. Run 23/8" slotted liner with an aluminum billet from TD up to 8100' MD 7. 11-0413 L I Lateral (A5 sand -south) a. Kickoff of the aluminum billet at 8100' MD b. Drill 3" bi-center lateral to TD of 10,575' MD c. Run 23/8" slotted liner from TD up to 7120' MD, inside the 3'/2" tubing tail 8. Freeze protect. Set BPV, ND BOPE. RDMO Nabors CRD2-AC. Post-RiLy Work 1. Pull BPV 2. Obtain static BHP. Install GLV's. 3. Return to 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 listed 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 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. Page 6 of 7 ORIGINAL February 02, 2015 PTD Application: 1 L -04A, 1 L-04AL4, 1 L-04AL1, 1 L-04AL2, 1 L -04B & 1 L-0461_1 — 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 observed, only in reverse. Liner Running — The 1 L-04 CTD laterals will be displaced to an overbalancing fluid (11.6 ppg NaBr) prior to running liner. See the "Drilling Fluids" section for more details. — 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%" rams will provide secondary well control while running 23/" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plan — 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. Sidetrack Name Directional Plan Distance to Unit Boundary Distance to Nearest Well Nearest Well 1 L -04A 06 23,745' 340' 1 F-09 1 L-04AL4 01 23,745' 605' 1 F-09 1 L-04AL1 06 23,745' 350' 1 F-09 1 L-04AL2 06 23,745' 380' 1 F-09 1 L -04B 10 18,630' 345' 1 L-02 1 L-04BL1 10 18,630' 370' 1 L-02 16. Attachments Attachment 1: Directional Plan for IL -04B & BL 1 Attachment 2: Current Well Schematic Attachment 3: Proposed Well Schematic for IL -04B CTD Laterals Page 7 of 7 ORIGINAL February 02, 2015 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 1 L Pad 1 L-04 Plan: ei _04A' .., u \�-- �3Apc�' W�G)k Standard Planning Report 02 October, 2014 ORIGINAL FeA pp" BAKER HUGHES His ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1 L-04 Company: ConocoPhillips (Alaska) Inc. -Kup2 ND Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 L-04 @ 116.00usft (1 L-04) Site: Kuparuk 1L Pad North Reference: True Well: 1 L-04 \� �A tJyr Survey Calculation Method: Minimum Curvature Wellbore: 3— 0.00 0.00 315.33 Design: +41.948—wfl40 ��• �� nl�� Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1 L Pad Site Position: Northing: 5,949,190.90 usft Latitude: 70° 16' 19.650 N From: Map Easting: 539,916.78 usft Longitude: 149° 40'37.763 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.30 ° Well 1 L-04 Well Position +N/ -S 0.00 usft Northing: 5,949,370.89 usft Latitude: 70° 16'21.420 N +E/ -W 0.00 usft Easting: 539,914.96 usft Longitude: 149° 40'37.789 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore \� - © Magnetics Model Name Sample Date Declination Dip Angle Field Strength V) V) (nT) BGGM2014 12/1/2014 19.12 80.89 57,571 Design 4!841'c6g7iwp49 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,200.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (I 0.00 0.00 0.00 315.33 10/2/2014 12:53:51 PM Page 2 ORIGINAL COMPASS 5000.1 Build 61 ConocoPhilli s �� p Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1 L-04 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 L-04 @ 116.00usft (1 L-04) Site: Kuparuk 1 L Pad North Reference: True Well: 1 L-04 Survey Calculation Method: Minimum Curvature Wellbore: =:AL3 - Design: Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +Nl-S +E/ -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100ft) (°1100ft) (°/100ft) (°) 7,200.00 31.23 341.62 5,854.23 3,394.93 -988.66 0.00 0.00 0.00 0.00 7,230.00 31.18 341.90 5,879.89 3,409.69 -993.53 0.51 -0.17 0.93 109.14 7,251.00 35.32 343.16 5,897.44 3,420.67 -996.97 20.00 19.73 6.00 10.00 7,321.00 66.54 348.84 5,941.04 3,472.86 -1,009.37 45.00 44.59 8.11 10.00 7,441.00 63.19 48.93 5,996.13 3,569.29 -977.24 45.00 -2.79 50.08 107.00 7,528.60 93.00 75.65 6,014.31 3,607.32 -902.41 45.00 34.03 30.50 45.00 7,608.60 93.60 111.71 6,009.55 3,602.29 -824.03 45.00 0.75 45.07 88.00 7,908.60 93.72 132.75 5,990.17 3,443.54 -572.20 7.00 0.04 7.01 89.00 8,208.60 90.09 153.45 5,980.09 3,205.08 -393.22 7.00 -1.21 6.90 99.50 8,408.60 89.84 167.45 5,980.21 3,017.08 -326.45 7.00 -0.12 7.00 91.00 8,608.60 90.09 181.44 5,980.32 2,818.52 -307.14 7.00 0.12 7.00 89.00 8,783.60 94.65 192.83 5,973.06 2,645.35 -328.79 7.00 2.60 6.50 68.00 8,958.60 90.06 204.20 5,965.85 2,479.87 -384.23 7.00 -2.62 6.50 111.70 9,138.60 87.67 216.57 5,969.44 2,324.93 -475.07 7.00 -1.33 6.88 101.00 9,438.60 89.97 195.69 5,975.68 2,057.15 -606.41 7.00 0.77 -6.96 276.00 9,738.60 91.76 216.62 5,971.09 1,789.40 -737.89 7.00 0.60 6.98 85.00 10,038.60 90.21 195.67 5,965.86 1,521.64 -869.32 7.00 -0.52 -6.98 266.00 10,213.60 88.58 207.81 5,967.71 1,359.41 -934.02 7.00 -0.93 6.94 97.70 10,388.60 88.61 195.56 5,972.02 1,197.16 -998.55 7.00 0.02 -7.00 270.00 10,550.00 86.11 184.53 5,979.47 1,038.66 -1,026.64 7.00 -1.55 -6.83 257.00 Target 10/212014 12.53:51 PM Page 3 COMPASS 5000.1 Build 61 ORIGINAL ConocoPhilli s ,�� P Planning Report BAKER HUGHES Database: Company: Project: Site: Well: Wellbore: Design: EDM Alaska Sandbox Local Co-ordinate Reference: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Kuparuk River Unit MD Reference: Kuparuk 1 L Pad North Reference: 1L-04 Survey Calculation Method �4a�-"ted `�� , �r.►� ®` Planned Survey Map Vertical Dogleg Measured +E/ -W Section TVD Below Depth Inclination Azimuth System (usft) (°) (°) (usft) 7,200.00 31.23 341.62 5,854.23 TIP -996.97 3,133.67 20.00 7,230.00 31.18 341.90 5,879.89 KOP -1,009.37 3,179.50 45.00 7,251.00 35.32 343.16 5,897.44 End 20 dls, Start 45 dls 45.00 7,300.00 57.15 347.61 5,931.14 7,321.00 66.54 348.84 5,941.04 4 539,154.80 3,511.60 -656.43 7,400.00 61.32 28.16 5,976.88 7,441.00 63.19 48.93 5,996.13 5 89.86 5,952,816.76 539,318.20 7,500.00 83.03 67.50 6,013.32 7,528.60 93.00 75.65 6,014.31 6 91.00 5,952,394.27 7,600.00 93.60 107.83 6,010.09 7,608.60 93.60 111.71 6,009.55 End 45 dls, Start 7 dls 90.99 7,700.00 93.69 118.12 6,003.73 7,800.00 93.74 125.13 5,997.25 7,900.00 93.72 132.15 5,990.73 7,908.60 93.72 132.75 5,990.17 8 2,827.11 -306.97 8,000.00 92.64 139.07 5,985.09 8,100.00 91.43 145.96 5,981.54 8,200.00 90.20 152.86 5,980.11 8,208.60 90.09 153.45 5,980.09 9 88.99 5,952,187.46 8,300.00 89.98 159.85 5,980.04 8,400.00 89.86 166.84 5,980.19 8,408.60 89.84 167.45 5,980.21 10 8,500.00 89.96 173.84 5,980.37 8,600.00 90.08 180.84 5,980.33 8,608.60 90.09 181.44 5,980.32 11 8,700.00 92.48 187.38 5,978.26 8,783.60 94.65 192.83 5,973.06 12 8,800.00 94.22 193.90 5,971.79 8,900.00 91.60 200.40 5,966.70 8,958.60 90.06 204.20 5,965.85 13 9,000.00 89.50 207.04 5,966.01 9,100.00 88.18 213.92 5,968.04 9,138.60 87.67 216.57 5,969.44 14 9,200.00 88.13 212.30 5,971.69 9,300.00 88.89 205.33 5,974.30 9,400.00 89.67 198.38 5,975.56 9,438.60 89.97 195.69 5,975.68 15 Well 1 L-04 Mean Sea Level 1 L-04 @ 116.00usft (1 L-04) True Minimum Curvature Toolface Map Vertical Dogleg +N/ -S +E/ -W Section Rate (usft) (usft) (usft) (°/100ft) 3,394.93 -988.66 3,109.51 0.00 3,409.69 -993.53 3,123.43 0.51 3,420.67 -996.97 3,133.67 20.00 3,454.76 -1,005.60 3,163.97 45.00 3,472.86 -1,009.37 3,179.50 45.00 Toolface Map Map Azimuth Northing Easting (°) (usft) (usft) 0.00 5,952,760.19 538,908.41 109.14 5,952,774.93 538,903.46 10.00 5,952,785.89 538,899.96 10.00 5,952,819.92 538,891.15 6.86 5,952,838.01 538,887.29 3,541.17 -999.71 3,221.29 45.00 107.00 5,952,906.36 538,896.58 3,569.29 -977.24 3,225.49 45.00 89.13 5,952,934.59 538,918.90 3,598.31 -929.48 3,212.56 45.00 45.00 5,952,963.87 538,966.51 3,607.32 -902.41 3,199.94 45.00 39.48 5,952,973.02 538,993.52 3,605.19 -832.10 3,149.00 45.00 88.00 5,952,971.27 539,063.83 3,602.29 -824.03 3,141.26 45.00 89.90 5,952,968.41 539,071.92 3,563.89 -741.34 3,055.82 7.00 89.00 5,952,930.45 539,154.80 3,511.60 -656.43 2,958.94 7.00 89.41 5,952,878.61 539,239.99 3,449.33 -578.53 2,859.89 7.00 89.86 5,952,816.76 539,318.20 3,443.54 -572.20 2,851.32 7.00 90.32 5,952,811.01 539,324.56 3,378.03 -314.16 -508.73 7.00 2,760.11 5,952,096.37 7.00 99.50 -328.79 5,952,745.84 7.00 539,388.37 5,952,014.20 3,298.77 2,629.44 -447.96 2,103.87 2,661.02 111.70 7.00 99.85 2,534.07 5,952,666.92 2,056.73 539,449.56 111.78 3,212.75 539,539.56 -397.11 -384.23 2,564.10 7.00 7.00 100.10 539,517.62 5,952,581.17 -595.11 539,500.86 7.00 3,205.08 5,951,461.55 -393.22 2,057.15 2,555.91 1,889.36 7.00 100.19 5,951,424.60 5,952,573.52 539,504.78 3,121.21 -357.01 2,470.81 7.00 91.00 5,952,489.86 539,541.44 3,025.46 -328.37 2,382.57 7.00 91.00 5,952,394.27 539,570.59 3,017.08 -326.45 2,375.27 7.00 90.99 5,952,385.90 539,572.54 2,926.94 -311.60 2,300.72 7.00 89.00 5,952,295.85 539,587.87 2,827.11 -306.97 2,226.46 7.00 88.99 5,952,196.06 539,593.03 2,818.52 -307.14 2,220.47 7.00 88.99 5,952,187.46 539,592.91 2,727.46 -314.16 2,160.64 7.00 68.00 5,952,096.37 539,586.37 2,645.35 -328.79 2,112.53 7.00 68.13 5,952,014.20 539,572.18 2,629.44 -332.57 2,103.87 7.00 111.70 5,951,998.27 539,568.48 2,534.07 -362.00 2,056.73 7.00 111.78 5,951,902.75 539,539.56 2,479.87 -384.23 2,033.81 7.00 112.11 5,951,848.44 539,517.62 2,442.54 -402.13 2,019.85 7.00 101.00 5,951,811.03 539,499.92 2,356.43 -452.81 1,994.23 7.00 100.99 5,951,724.66 539,449.71 2,324.93 -475.07 1,987.48 7.00 100.85 5,951,693.04 539,427.62 2,274.34 -509.75 1,975.88 7.00 -84.00 5,951,642.27 539,393.20 2,186.80 -557.90 1,947.47 7.00 -83.84 5,951,554.49 539,345.52 2,094.05 -595.11 1,907.66 7.00 -83.66 5,951,461.55 539,308.82 2,057.15 -606.41 1,889.36 7.00 -83.57 5,951,424.60 539,297.71 10/212014 12:53:51 PM Page 4 COMPASS 5000.1 Build 61 k-11 N L MAP .I ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1L Pad North Reference: Well: 1 L-04 \�-- 4, Survey Calculation Method: Wellbore: v 90.95 Design: 146 Planned Survey Measured Map Vertical TVD Below Depth Inclination Azimuth System (usft) (o) (o) (usft) 9,500.00 90.34 199.97 5,975.51 9,600.00 90.95 206.95 5,974.38 9,700.00 91.54 213.93 5,972.21 9,738.60 91.76 216.62 5,971.09 16 -772.63 1,779.81 7.00 9,800.00 91.46 212.33 5,969.37 9,900.00 90.95 205.35 5,967.27 10,000.00 90.42 198.37 5,966.08 10,038.60 90.21 195.67 5,965.86 17 10,100.00 89.64 199.93 5,965.94 10,200.00 88.71 206.87 5,967.39 10,213.60 88.58 207.81 5,967.71 18 10,300.00 88.59 201.76 5,969.85 10,388.60 88.61 195.56 5,972.02 19 10,400.00 88.43 194.78 5,972.31 10,500.00 86.87 187.95 5,976.41 10,550.00 86.11 184.53 5,979.47 Planned TD at 10550.00 Well 1 L-04 Mean Sea Level 1 L-04 @ 116.00usft (1 L-04) True Minimum Curvature 1,463.20 -888.09 1,371.49 -927.78 1,359.41 -934.02 1,281.03 Map Vertical Dogleg +N/ -S +E/ -W Section Rate (usft) (usft) (usft) (°/100ft) 1,998.72 -625.21 1,861.02 7.00 1,907.05 -665.00 1,823.79 7.00 1,820.90 -715.61 1,798.11 7.00 1,789.40 -737.89 1,791.37 7.00 1,738.82 -772.63 1,779.81 7.00 1,651.30 -820.82 1,751.44 7.00 1,558.55 -858.03 1,711.63 7.00 1,521.64 -869.32 1,693.32 7.00 1,463.20 -888.09 1,371.49 -927.78 1,359.41 -934.02 1,281.03 Map -970.22 1,197.16 V) -998.55 1,186.16 5,951,366.07 -1,001.53 1,088.27 85.09 -1,021.22 1,038.66 5,951,156.18 -1,026.64 1,664.95 1,627.63 1,623.43 1,593.13 1,553.39 1,547.67 1,491.88 1,460.42 7.00 7.00 7.00 7.00 7.00 7.00 7.00 7.00 Toolface Map Azimuth Northing V) (usft) 85.00 5,951,366.07 85.01 5, 951, 274.20 85.09 5,951,187.79 85.24 5,951,156.18 -94.00 5,951,105.42 -94.12 5,951,017.65 -94.27 5,950,924.71 -94.35 5,950,887.75 97.70 5,950,829.21 97.69 5,950,737.30 97.59 5,950,725.20 -90.00 5,950,646.63 -89.85 5,950,562.62 -103.00 5,950,551.60 -102.98 5,950,453.62 -102.70 5,950,403.99 Map Easting (usft) 539,279.22 539,239.92 539,189.77 539,167.66 539,133.20 539, 085.47 539,048.77 539,037.67 539,019.21 538,980.01 538,973.83 538,938.05 538,910.17 538,907.25 538,888.08 538,882.92 10/212014 12:53:51PM Page 5 COMPASS 5000.1 Build 61 ORIGINAL NAaI ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1L-04 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 L-04 @ 116.00usft (11--04) Site: Kuparuk 1L Pad North Reference: True Well: 1 L-04 Survey Calculation Method: Minimum Curvature Wellbore: `4&8-tAb@- (usft) Latitude Longitude Design: *,14� �` V `� 1 W Q) -297.691,139,410.37 5,955,116.00 Targets Target Name hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting Shape (°) (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 1 L-04A_Fault2 0.00 0.00 0.00 -297.691,139,410.37 5,955,116.00 1,679,199.00 70° 2' 16.173 N 140° 32' 13.562 W plan misses target center by 1139737.31 usft at 8600.00usft MD (5980.33 TVD, 2827.11 N, -306.97 E) Rectangle (sides W310.00 1-11.00 D0.00) 1 L-04AL3_T04 0.00 0.00 5,966.00 -3,809.871,139,745.78 5,951,606.00 1,679,553.00 70° V41.580 N 140° 32' 19.122 W plan misses target center by 1140072.06usft at 8600.00usft MD (5980.33 TVD, 2827.11 N, -306.97 E) Point 1 L-04AL3_T01 0.00 0.00 6,014.00 -2,692.901,139,210.64 5,952,720.00 1,679,012.00 70° V53.210 N 140° 32'29.527 W plan misses target center by 1139530.98usft at 8600.00usft MD (5980.33 TVD, 2827.11 N, -306.97 E) Point 1L-04AL3_T05 0.00 0.00 5,976.00 -4,228.741,139,523.53 5,951,186.00 1,679,333.00 70° 1' 37.839 N 140° 32'27.233 W plan misses target center by 1139852.34usft at 8600.00usft MD (5980.33 TVD, 2827.11 N, -306.97 E) Point 1L-04AL3_T06 0.00 0.00 5,966.00 -4,774.391,139,257.61 5,950,639.00 1,679,070.00 70° V32.931 N 140° 32'37.128 W plan misses target center by 1139589.93usft at 8600.00usft MD (5980.33 TVD, 2827.11 N, -306.97 E) Point 1 L-04 CTD Polygon_Soi 0.00 0.00 0.00 -2,926.751,138,988.38 5,952,485.00 1,678,791.00 70° V51.266 N 140° 32'36.845 W plan misses target center by 1139325.57usft at 8600.00usft MD (5980.33 TVD, 2827.11 N, -306.97 E) Polygon Point 1 0.00 0.00 0.00 5,952,485.00 1,678,791.00 Point 0.00 156.14 -23.18 5,952,641.00 1,678,766.99 Point 0.00 280.90 25.48 5,952,766.00 1,678,814.99 Point 0.00 374.25 150.98 5,952,860.01 1,678,939.98 Points 0.00 390.39 315.09 5,952,877.02 1,679,103.98 Point 0.00 309.42 498.68 5,952,797.03 1,679,287.98 Point 0.00 50.86 788.36 5,952,540.04 1,679,579.00 Point 0.00 -140.83 916.36 5,952,349.05 1,679,708.00 Point 0.00 -505.35 1,007.46 5,951,985.05 1,679,801.03 Point 10 0.00 -696.24 982.45 5,951,794.05 1,679,777.03 Point 11 0.00 -900.87 908.37 5,951,589.05 1,679,704.05 Point 12 0.00 -1,295.89 712.27 5,951,193.03 1,679,510.06 Point 13 0.00 -1,618.11 557.56 5,950,870.03 1,679,357.08 Point 14 0.00 -2,168.81 297.64 5,950,318.01 1,679,100.11 Point 15 0.00 -2,446.57 247.18 5,950,040.02 1,679,051.13 Point 16 0.00 -2,402.84 -81.63 5,950,082.00 1,678,722.12 Point 17 0.00 -2,118.02 -42.13 5,950,366.99 1,678,760.11 Point 18 0.00 -1,501.26 207.14 5,950,985.01 1,679,006.08 Point 19 0.00 -1,148.30 414.01 5,951,339.02 1,679,211.05 Point 20 0.00 -771.19 590.02 5,951,717.03 1,679,385.04 Point 21 0.00 -642.50 652.70 5,951,846.03 1,679,447.03 Point 22 0.00 -521.62 678.34 5,951,967.04 1,679,472.03 Point 23 0.00 -246.25 613.78 5,952,242.03 1,679,406.02 Point 24 0.00 -134.91 551.35 5,952,353.03 1,679,343.00 Point 25 0.00 88.51 285.50 5,952,575.01 1,679,076.00 Point 26 0.00 0.00 0.00 5,952,485.00 1,678,791.00 1L-04AL3_Faultl 0.00 0.00 0.00 -3,454.221,139,819.67 5,951,962.00 1,679,625.00 700 1'44.924 N 1400 32' 15.496 W plan misses target center by 1140159.63usft at 8600.00usft MD (5980.33 TVD, 2827.11 N, -306.97 E) Rectangle (sides W330.00 1-11.00 D0.00) 1L-04AL3_T03 0.00 0.00 5,980.00 -3,413.211,139,817.89 5,952,003.00 1,679,623.00 70° 1'45.325 N 140° 32' 15.370 W plan misses target center by 1140141.93usft at 8600.00usft MD (5980.33 TVD, 2827.11 N, -306.97 E) Point 1L-04 CTD Polygon_Noi 0.00 0.00 0.00 -2,926.751,138,988.38 5,952,485.00 1,678,791.00 700 1'51.266 N 1400 32'36.845 W plan misses target center by 1139325.57usft at 8600.00usft MD (5980.33 TVD, 2827.11 N, -306.97 E) Polygon Point 1 0.00 0.00 0.00 5,952,485.00 1,678,791.00 10/2/2014 12:53:51PM Page 6 COMPASS 5000.1 Build 61 ILIAL Design: wp10 \ \-- Q� A, -, r \,.4 ( `` ` Point 0.00 201.25 FSA .I ConocoPhillips Planning Report Point 3 BAKER 398.08 -6.91 5,952,883.00 HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1 L-04 98.43 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level 0.00 Project: Kuparuk River Unit MD Reference: 1L-04 @ 116.00usft (11--04) 1,679,074.95 Site: Kuparuk 1 L Pad North Reference: True 484.88 Well: 1L-04 \� -} Survey Calculation Method: Minimum Curvature 0.00 Wellbore: I -94AIZ 542.19 5,954,226.03 1,679,323.91 Design: wp10 \ \-- Q� A, -, r \,.4 ( `` ` Point 0.00 201.25 -43.95 5,952,685.99 1,678,745.99 Point 3 0.00 398.08 -6.91 5,952,883.00 1,678,781.98 Point 0.00 650.56 98.43 5,953,136.01 1,678,885.97 Point 5 0.00 929.59 288.91 5,953,416.02 1,679,074.95 Point 0.00 1,299.60 484.88 5,953,787.03 1,679,268.93 Point 0.00 1,738.35 542.19 5,954,226.03 1,679,323.91 Point 8 0.00 2,182.67 489.52 5,954,670.02 1,679,268.89 Point 0.00 2,463.33 369.98 5,954,950.02 1,679,147.87 Point 10 0.00 2,671.25 200.05 5,955,157.01 1,678,976.86 Point 11 0.00 2,864.40 -15.96 5,955,348.99 1,678,759.85 Point 12 0.00 3,269.73 -258.85 5,955,752.99 1,678,514.84 Point 13 0.00 4,029.55 -589.90 5,956,510.97 1,678,179.80 Point 14 0.00 4,169.12 -315.14 5,956,651.98 1,678,453.78 Point 15 0.00 3,448.24 28.11 5,955,933.00 1,678,800.82 Point 16 0.00 3,127.22 214.45 5,955,613.01 1,678,988.84 Point 17 0.00 2,870.98 445.13 5,955,358.02 1,679,220.85 Point 18 0.00 2,632.01 625.89 5,955,120.03 1,679,402.86 Point 19 0.00 2,217.85 836.74 5,954,707.04 1,679,615.88 Point 20 0.00 1,736.59 877.22 5,954,226.05 1,679,658.91 Point 21 0.00 1,182.96 795.30 5,953,672.05 1,679,579.94 Point 22 0.00 805.98 592.30 5,953,294.03 1,679,378.96 Point 23 0.00 485.10 371.59 5,952,972.02 1,679,159.98 Point 24 0.00 189.60 270.03 5,952,676.01 1,679,059.99 Point 25 0.00 91.49 288.51 5,952,578.01 1,679,078.99 Point 26 0.00 0.00 0.00 5,952,485.00 1,678,791.00 1 L-04AL3_T02 0.00 0.00 5,988.00 -2,883.911,139,585.67 5,952,531.00 1,679,388.00 70° V50.805 N 140° 32' 19.693 W plan misses target center by 1139906.94usft at 8600.00usft MD (5980.33 TVD, 2827.11 N, -306.97 E) Point 1L-04A_Faultl 0.00 0.00 0.00 -2,534.581,139,153.47 5,952,878.00 1,678,954.00 70° V54.831 N 140° 32'30.471 W plan misses target center by 1139488.75usft at 8600.00usft MD (5980.33 TVD, 2827.11 N, -306.97 E) Rectangle (sides W330.00 1-11.00 D0.00) 1 L-04AL3_T07 0.00 0.00 5,979.00 -5,257.611,139,100.03 5,950,155.00 1,678,915.00 70° 1'28.471 N 140° 32'43.677 W plan misses target center by 1139435.68usft at 8600.00usft MD (5980.33 TVD, 2827.11 N, -306.97 E) Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 10,550.00 5,979.47 2-3/8" 2.375 3.000 10/212014 12:53: 51 PM Page 7 7RIGINAL COMPASS 5000.1 Build 61 Fel .I ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1 L-04 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 L-04 @ 116.00usft (1 L-04) Site: Kuparuk 1 L Pad North Reference: True Well: 1 L-04 \� Survey Calculation Method: Minimum Curvature Wellbore: '1tBdfet9— -988.66 TIP Design: rr��, lr -0 ,t.: v�C�� W�C3\ 3,409.69 -993.53 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 7,200.00 5,854.23 3,394.93 -988.66 TIP 7,230.00 5,879.89 3,409.69 -993.53 KOP 7,251.00 5,897.44 3,420.67 -996.97 End 20 dls, Start 45 dls 7,321.00 5,941.04 3,472.86 -1,009.37 4 7,441.00 5,996.13 3,569.29 -977.24 5 7,528.60 6,014.31 3,607.32 -902.41 6 7,608.60 6,009.55 3,602.29 -824.03 End 45 dls, Start 7 dls 7,908.60 5,990.17 3,443.54 -572.20 8 8,208.60 5,980.09 3,205.08 -393.22 9 8,408.60 5,980.21 3,017.08 -326.45 10 8,608.60 5,980.32 2,818.52 -307.14 11 8,783.60 5,973.06 2,645.35 -328.79 12 8,958.60 5,965.85 2,479.87 -384.23 13 9,138.60 5,969.44 2,324.93 -475.07 14 9,438.60 5,975.68 2,057.15 -606.41 15 9,738.60 5,971.09 1,789.40 -737.89 16 10,038.60 5,965.86 1,521.64 -869.32 17 10,213.60 5,967.71 1,359.41 -934.02 18 10,388.60 5,972.02 1,197.16 -998.55 19 10,550.00 5,979.47 1,038.66 -1,026.64 Planned TD at 10550.00 10/2/2014 12:53:51 PM OR'RGNAL COMPASS 5000.1 Build 61 ConocoPh i I I i ps ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 1 L Pad 1 L-04 1L -04A �, R v ` L' 6 4 1 - L3_wp10 Travelling Cylinder Report 02 October, 2014 RIGINAL WE P k 9 BAKER HUGHES ri.I ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 1 L Pad Site Error: 0.00usft Reference Well: 1 L-04 Well Error: 0.00usft Reference Wellbore 1L-04AL3 Reference Design: 1L-04A1_3_wp10 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1 L-04 1 L-04 @ 116.00usft (1 L-04) 1 L-04 @ 116.00usft (1 L-04) True Minimum Curvature 1.00 sigma EDM Alaska Prod Offset Datum Reference 1L-04AL3_wp10 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.O0usft Error Model: ISCWSA Depth Range: 7,200.00 to 10,550.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,243.40usft Error Surface: Elliptical Conic Survey Tool Program Date 10/2/2014 From To (usft) (usft) Survey (Wellbore) Tool Name Description 200.00 7,200.00 1 L-04 (1 L-04) GCT -MS Schlumberger GCT multishot 7,200.00 10, 550.00 1 L -04A L3_wp 10 (1 L-04AL3) MWD MWD - Standard Casing Points Measured Vertical Casing Hole Measured Depth Depth Diameter Diameter Depth (usft) (usft) Name O (11) (usft) 10,550.00 6,095.47 2-3/8" 2-3/8 3 Summary Site Name Offset Well - Wellbore - Design Kuparuk 1 F Pad 1 F-20 - 1 F-20 - 1 F-20 1 F-20 - 1 F-20 P B I- 1 F -20P B 1 Kuparuk 1 L Pad 1 L-03 - 1 L-03 - 1 L-03 1 L-03 - 1 L -03A - 1 L -03A 1 L-04 - 1 L-04 - 1 L-04 1 L-04 - 1 L -04A - 1 L-04A_wp06 1 L-04 - 1 L-04AL1 - 1 L-04AL1_wp03 1 L-04 - 1 L-04AL2 - 1 L-04AL2_wp04 1 L-04 - 1 L-04AL3-01 - 1 L-04AL3-01_wp02 Reference Offset Centre to Measured Measured Centre Depth Depth Distance (usft) (usft) (usft) 9,968.20 10,300.00 976.80 No -Go Allowable Distance Deviation Warninc (usft) from Plan 1,240.93 233.57 (usft) Pass - Major Risk 305.59 672.55 Pass - Major Risk 2.00 -1.28 Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 10/212014 10:14:02AM Page 2 of 15 COMPASS 5000.1 Build 61 R N A L Out of range 7,321.00 7,950.00 1,240.93 233.57 1,010.87 Pass - Major Risk 7,249.97 7,250.00 0.70 2.00 -1.28 FAIL - Major Risk 7,225.00 7,225.00 0.00 0.85 -0.81 FAIL - Major Risk 7,225.00 7,225.00 0.00 0.85 -0.81 FAIL - Major Risk 7,225.00 7,225.00 0.00 0.85 -0.81 FAIL - Major Risk 8,124.98 8,125.00 0.72 0.62 0.26 Pass - Minor 1/10 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 10/212014 10:14:02AM Page 2 of 15 COMPASS 5000.1 Build 61 R N A L TRANSMITTAL LETTER CHECKLIST WELL NAME: &R(A, I o PTD: '� 1 S - U ZO /Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: t V POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. 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 Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 4/2014 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL- 490100 Well Name: KUPARUK RIV_UNIT 1_L -04B Program Well bore seg ❑ PTD#:2150200 Company CONOCOPHILLIPS ALASKA INC _ _ Initial Class/Type _ / PEND GeoArea 890 Unit 111.60 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) NA 1 Permit fee attached NA 9 2 Lease number appropriate_ Yes ADL0025659, entire wellbore_ I3 Unique well name and number Yes KRU 1L -04B 12 i4 Well located in a defined pool Yes KUPARUK RIVER, KUPARUK RIV OIL - 490100, governed by Conservation Order No. 432C 5 Well located proper distance from drilling unit boundary Yes CO 432C contains no spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance from other wells Yes CO 432C has no intenvell spacing restrictions. 7 Sufficient acreage available in drilling unit Yes Conductor string provided 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes Appr Date 11 Permit can be issued without conservation order Yes 12 Permit can be issued without administrative approval Yes PKB 2/2/2015 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) NA 18 Conductor string provided NA Engineering 19 Surface casing protects all known USDWs NA_ 20 CMT vol adequate to circulate on conductor & surf csg NA 21 CMT vol adequate to tie-in long string to surf csg NA Wellbore will be more than 500' from an external property line where_ ownership or landownership changes. Conductor set in KRU 1 L-04 Surface casing set in KRU 1 L-04_ Surface casing set and fully cemented I22 CMT will cover all known productive horizons No - Productive interval will be completed with slotted liner Rig has steel tanks; all waste to approved disposal wells Proximity analysis complete; no major risk failures Max formation pressure is 4135 psi(13.1 ppg EMW); will drill w/ 9.8 ppg EMW and maintain overbalance with MPD MPSP si 3531 psi; will test BOPs to 4000 psi I33 Is presence of 1-12S gas probable Yes 1-12S measures required. 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No Geology 36 Data presented on potential overpressure zones Yes Appr Date 37 Seismic analysis of shallow gas zones NA PKB 2/2/2015 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] - NA Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date ,TK v��P F �J31►6 Wells on 1L -Pad are H2S-bearing. 1-12S measures required. Max expected reservoir pressure is 13.1 ppg EMW; will be drilled using 9.6 ppg mud and MPD technique. Two wellbore volumes of 13.1 ppg KWF will be available. Onshore development well to be drilled. I23 Casing designs adequate for C, T, B & permafrost- Yes 24 Adequate tankage or reserve pit Yes 25 If a_re-drill, has a 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes 27 If diverter required, does it meet regulations NA Appr Date 28 Drilling fluid program schematic & equip list adequate Yes VTL 2/3/2015 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes 31 Choke manifold complies w/API RP -53 (May 84)_ Yes 32 Work will occur without operation shutdown Yes Rig has steel tanks; all waste to approved disposal wells Proximity analysis complete; no major risk failures Max formation pressure is 4135 psi(13.1 ppg EMW); will drill w/ 9.8 ppg EMW and maintain overbalance with MPD MPSP si 3531 psi; will test BOPs to 4000 psi I33 Is presence of 1-12S gas probable Yes 1-12S measures required. 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No Geology 36 Data presented on potential overpressure zones Yes Appr Date 37 Seismic analysis of shallow gas zones NA PKB 2/2/2015 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] - NA Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date ,TK v��P F �J31►6 Wells on 1L -Pad are H2S-bearing. 1-12S measures required. Max expected reservoir pressure is 13.1 ppg EMW; will be drilled using 9.6 ppg mud and MPD technique. Two wellbore volumes of 13.1 ppg KWF will be available. Onshore development well to be drilled.