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ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Date: May 29, 2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W. 7th Ave Suite 100 Anchorage, AK 99501 COP reviewed cement evaluation activities for wells in response to AOGCC Industry Guidance Bulletin 25-001. There was no indication of cement evaluation logs being run for the following wells based on a review of all drilling files associated with well construction. Kuparuk River Unit/Field Well API #PTD #Comments 3G-13A 50103201370100 222-106 No cement bond logs run 2N-303A 50103203520100 214-088 No cement bond log run 2E-04 50029235050000 213-168 No cement bond log run TARN 2N-323A 50103202580100 213-159 No cement bond log run 1C-19 50029231490000 203-054 No cement bond log run By Gavin Gluyas at 9:48 am, Jun 02, 2025 2E-04 50029235050000 213-168 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Colville River Unit/Field Well API # PTD # Comments CD3-303 50103205680000 208-013 No cement bond log run ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Greater Mooses Tooth Unit/Field Well API # PTD # Comments MT6-06 50103207730000 218-093 Production well, CBL was not run across 7” liner CO CO ...4. o F- ' © N. 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N W r W r N W r r N r C z H Y O d 3• Q I. co .E GJ R) H a a Q ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 22, 2015 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7�' Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement (one with carbolite) and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) Kuparuk Field Date 6/22/2015 1E,1Y,2E,2F,2M,2N,2V,3N & 3S Pads Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal 1E-32 50029227880000 1971320 15" na 15" na 1.8 6/18/2015 1Y-10 50029209340000 1830510 36' 3.70 13" 5/10/2015 4.6 6/20/2015 2E-02 50029235170000 2140780 9' 0.60 24" 6/14/2015 5.1 6/16/2015 2E-03 50029235090000 2132030 4' 0.62 7" 6/13/2015 3.9 6/16/2015 2E-04 50029235050000 2131680 10' 1.29 19" 6/15/2015 7.7 6/16/2015 2F-20 50029227390000 1970160 6' 0.80 13" 4/20/2015 3 6/20/2015 2F-21 50029223525000 2141360 22" 0.10 22" 4/25/2015 15.3 6/19/2015 2F-22 5002923530000 2141500 64" 1.10 17" 4/25/2015 11.5 6/19/2015 2M-36 50103206910000 2141020 87" 0.70 10" 5/23/2015 2.1 6/20/2015 2N-322 50103206780000 2131790 13" na 13" na 2.5 6/19/2015 2V-02 50029210370000 1831610 11" 1.00 14" 5/20/2015 2 6/16/2015 3N -11A 50029215800100 2120950 34' 27 cu.ft carbolite 10" 5/26/2015 2 6/18/2015 3S-620 50103206950000 2141670 6'3" 0.60 12" 4/26/2015 2.6 6/18/2015 0 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Z k 3- L 6 S Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: Q Color Items: ❑ Maps: O-Grayscale Items: ❑ Logs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: Stacey dosepl� Date: Project Proofling BY: StaceyJoseph Date: Scanning Preparation x 30 = + = TOTAL PAGES (Count does not include cover sheet) BY: StaceyJose Date: k Zt/o ce l/ Y /s/'"��s Production Scanning Stage 1 Page Count from Scanned File: (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: --YES BY: Stacey Jose Date: C 2-1111 q' Stage 1 If NO in stage 1, page(s) discrepancies were found: _ BY: Stacey Joseph Date: Stage 2 Additional Well Reports Digital version appended by: Meredith YES NO /s/ YES NO TOTAL PAGES: Michal Date: /s/ NO Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. n Phill1 s DATA LOGGED � 9 h\ rro1q p A T .i. K. BENDER TRANSMITTAL RANSMIT i AL CONFIDENTIAL DATA RECEIVED FROM: Sandra D. Lemke, AT03-0340 TO: Makana Bender SEP 1 1 2014 ConocoPhillips Alaska, Inc. AOCCC nn P.O. Box 100360 333 W. �' Ave., Suite 100 AOG C V Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 2E-04PB1 DATE: 09/09/2014 Kuparuk Riser Unit, Alaska 5-1194 D VD •- DVD ofdigital data _ Cored Intervals Summary.xlsx- lists all cores taken in this well, includes Sidewall Core and Conventional SWC.xIsx - P&P, Saturation data for Sidewall cores _ Conv.xlsx - P&P, Tracer Saturation data for Conventional Core (2 files) _ Conv_Core_Photos folder - TIFF files of core photos of Conventional Core, plain light and UV) DNR POD 2E-04 Core cover letter promptly sign, scan and return electronically to 5andra.D.Lemkg0C0Acom CC: 2E-04PB1 transmittal folder, production well files, eSearch Receipt: ate: GIS -Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 0 Donald Ince Geoscience Manager Greater Kuparuk Area 700 G Street - ATO 1268 Anchorage, AK 99510-0360 ConocoPhillip.-.2 907.265.1665 September 9, 2014 Ms. Kathleen King Division of Oil and Gas Department of Natural Resources 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501 2` 3- tQ-6 L JA%%'� SEP 1 1 2014 RE: Kuparuk River Unit 2014 Plan of Development Request for Well 2E-04pb1 Core Data Dear Ms. King: On June 16, 2014 the Department of Natural Resources, Division of Oil and Gas approved the proposed 2014 Kuparuk River Unit Plans of Development. The approval contained a request from the Division for ConocoPhillips Alaska, Inc. to submit core data and analyses for KRU well 2E-04pb1 when it became available. In response to the Division's request, the enclosed CD contains well 2E-04pb1 core data and analyses as follows: 1. Cored Intervals Summary.xlsx- lists all cores taken in this well, includes Sidewall Core and Conventional 2. SWC.xlsx — P&P, Saturation data for Sidewall cores 3. Conv.xlsx — P&P, Tracer Saturation data for Conventional Core 4. Conv_Core—Photos folder — TIFF files of core photos of Conventional Core, plain light and UV) ConocoPhillips requests the information contained on this CD be kept confidential under AS 38.05.035(x)(8), AS 31.05.035(d), and other applicable law. If you have questions, please feel free to contact me. Sincerely, w Donald Ince GKA Geoscience Manager DATA SUBMITTAL COMPLIANCE REPORT 8/13/2014 Permit to Drill 2131680 Well Name/No. KUPARUK RIV UNIT 2E-04 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23505-00-00 1�1 I%, 24091 Digital Data \. MD 14823 TVD 6259 Completion Date ` 2/17/2014 Completion Status 1-0I1- Current Status 1-0IL UIC No REQUIRED INFORMATION GAS DATA.Ias ti C Mud Log No Digital Data Samples No Directional Survey Q DATA INFORMATION \ Types Electric or Other Logs Run: GR / Res, Sonic 04_Da i IyReport_1-10-14. pdf (data taken from Logs Portion of Master Well Data Maint) Well Log Information: 24091 Digital Data 4/2/2014 Log/ Electr Data Digital Dataset Log Log Run Interval OHI Tvoe Med/Frmt Number Name 24091 Scale Media No Start Stop CH Received Comments ED C 24091 Digital Data 1950 8000 4/2/2014 Electronic Data Set, Filename: CPAI 2E04 P131 GAS DATA.Ias ED C 24091 Digital Data 4/2/2014 Electronic File: ConocoPhillips_2E- 04_Da i IyReport_1-10-14. pdf ED C 24091 Digital Data 4/2/2014 Electronic File: ConocoPhillips_2E- 04_DailyReport_1-11-14.pdf ED C 24091 Digital Data 4/2/2014 Electronic File: ConocoPhillips_2E- 04_DailyReport_1-12-14. pdf ED C 24091 Digital Data 4/2/2014 Electronic File: ConocoPhillips_2E- 04_DailyReport_1-13-14. pdf ED C 24091 Digital Data 4/2/2014 Electronic File: ConocoPhillips_2E- 04_DailyReport_1-14-14. pdf ED C 24091 Digital Data 4/2/2014 Electronic File: ConocoPhillips_2E- 04_DailyReport_1-15-14. pdf ED C 24091 Digital Data 4/2/2014 Electronic File: ConocoPhillips_2E- 04_DailyReport_1-16-14.pdf ED C 24091 Digital Data 4/2/2014 Electronic File: ConocoPhillips_2E- 04_DailyReport_1-17-14. pdf ED C 24091 Digital Data 4/2/2014 Electronic File: ConocoPhillips_2E- 04_DailyReport_1-18-14. pdf ED C 24091 Digital Data 4/2/2014 Electronic File: ConocoPhillips_2E- 04_DailyReport_1-19-14. pdf ED C 24091 Digital Data 4/2/2014 Electronic File: ConocoPhillips_2E- 04_DailyReport_1-20-14.pdf ED C 24091 Digital Data 4/2/2014 Electronic File: ConocoPhillips_2E- 04_DailyReport_1-21-14. pdf AOGCC Page 1 of 6 Wednesday, August 13, 2014 • r1 DATA SUBMITTAL COMPLIANCE REPORT 8/13/2014 Permit to Drill 2131680 Well Name/No. KUPARUK RIV UNIT 2E-04 MD 14823 TVD 6259 Completion Date 2/17/2014 Operator CONOCOPHILLIPS ALASKA INC Completion Status 1 -OIL Current Status 1 -OIL API No. 50-029-23505-00-00 UIC No �D C 24091 Digital Data 4/2/2014 Electronic File: ConocoPhillips_2E- 04_DailyReport_1-6-14.pdf ED C 24091 Digital Data 4/2/2014 Electronic File: ConocoPhillips_2E- 04_Dai lyRe port_1-7-14. pdf ED C 24091 Digital Data 4/2/2014 Electronic File: ConocoPhillips_2E- 04_DailyReport_1-8-14.pdf ED C 24091 Digital Data 4/2/2014 Electronic File: ConocoPhillips_2E- 04_DailyReport_1-9-14.pdf ED C 24091 Digital Data 4/2/2014 Electronic File: 2E-04PB1.dbf ED C 24091 Digital Data 4/2/2014 Electronic File: 2E-04PB1.mdx ED C 24091 Digital Data 4/2/2014 Electronic File: 2E-04PB1_SCL.DBF ED C 24091 Digital Data 4/2/2014 Electronic File: 2E-04PB1_SCL.MDX ED C 24091 Digital Data 4/2/2014 Electronic File: 2E-04PB1_TVD.DBF ED C 24091 Digital Data 4/2/2014 Electronic File: 2E-04PB1_TVD.mdx ED C 24091 Digital Data 4/2/2014 Electronic File: 2e-04PB1r.dbf ED C 24091 Digital Data 4/2/2014 Electronic File: 2e-04PB1r.mdx ED C 24091 Digital Data 4/2/2014 Electronic File: 2e-04pb1.hdr ED C 24091 Digital Data 4/2/2014 Electronic File: English.scl ED C 24091 Digital Data 4/2/2014 Electronic File: CPAI 2E-04 PB1 Final Well Report.doc ED C 24091 Digital Data 4/2/2014 Electronic File: CPAI 2E-04 PB1 Final Well Report.pdf ED C 24091 Digital Data 4/2/2014 Electronic File: CPAI 2E-04PB1 COMBO LOG MD.pdf j ED C 24091 Digital Data 4/2/2014 Electronic File: CPAI 2E-04PB1 COMBO LOG TVD.pdf ED C 24091 Digital Data 4/2/2014 Electronic File: CPAI 2E-04PB1 DRILLING DYNAMICS MD.pdf ED C 24091 Digital Data 4/2/2014 Electronic File: CPAI 2E-04PB1 DRILLING DYNAMICS TVD.pdf ED C 24091 Digital Data 4/2/2014 Electronic File: CPAI 2E-04PB1 FORMATION LOG MD.pdf ED C 24091 Digital Data 4/2/2014 Electronic File: CPAI 2E-04PB1 FORMATION LOG TVD.pdf AOGCC Page 2 of 6 Wednesday, August 13, 2014 • is DATA SUBMITTAL COMPLIANCE REPORT 8/13/2014 Permit to Drill 2131680 Well Name/No. KUPARUK RIV UNIT 2E-04 MD 14823 ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C Log C Log ED C TVD 6259 Completion Date 2/17/2014 24091 Digital Data 24091 Digital Data 24091 Digital Data 24091 Digital Data 24091 Digital Data 24091 Digital Data 24091 Digital Data 24091 Digital Data 24091 Digital Data 24091 Digital Data 24091 Digital Data 24091 Digital Data 24091 Digital Data 24091 Digital Data 24091 Digital Data 24091 Digital Data 24091 Report: Final Well Re 24091 Mud Log 24118 Digital Data 2 Col Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23505-00-00 Completion Status 1 -OIL Current Status 1 -OIL UIC No 4/2/2014 Electronic File: CPA] 2E-04PB1 GAS RATIO LOG MD.pdf 4/2/2014 Electronic File: CPA] 2E-04PB1 GAS RATIO LOG TVD.pdf 4/2/2014 Electronic File: CPAI 2E-04 PB1 Engineering Remarks.txt 4/2/2014 Electronic File: CPA[ 2E-04 PB1 Lithologic Descriptions.txt 4/2/2014 Electronic File: CPAI 2E-04 P131 Hydrocarbon Show Report #1.pdf 4/2/2014 Electronic File: CPAI_ 2E- 04 1 COMB LG OMD.tif 26 4/2/2014 Electronic File: CPAI _2E- 04 PB1 COMB LOG TVD.tif 4/2/2014 Electronic File: CPAI _2E- 04 PB1 DRILLING DYNAMICS MD.tif 4/2/2014 Electronic File: CPAI _2E- 04_PB1_DRILLI NG_DYNAMICS_TVD.tif 4/2/2014 Electronic File: CPAI _2E- 04 PB1 FORMATION LOG MD.tif 4/2/2014 Electronic File: CPAI _2E- 04 PB1 FORMATION LOG TVD.tif 4/2/2014 Electronic File: CPAI _2E- 04 PB1 GAS RATIO LOG MD.tif 4/2/2014 Electronic File: CPAI _2E- 04 PB1 GAS RATIO LOG TVD.tif 4/2/2014 Electronic File: PP11Thumbs.ptn 4/2/2014 Electronic File: PP11Thumbs.ptn2 4/2/2014 Electronic File: maxdesk.ini2 0 0 2131680 KUPARUK RIV UNIT 2E-04 P131 LOG HEADERS 43 7900 4/2/2014 PB1 - Final Well Report - Formation Log MD & TVD, Gas Ratio Log MD & TVD, Combo Log MD & TVD, Drilling Dynamics Log MD & TVD 70 14792 4/2/2014 Electronic Data Set, Filename: 2E-04 EcoScope Memory Drilling Data.las AOGCC Page 3 of 6 Wednesday, August 13, 2014 • • DATA SUBMITTAL COMPLIANCE REPORT 8/13/2014 Permit to Drill 2131680 Well Name/No. KUPARUK RIV UNIT 2E-04 MD 14823 TVD 6259 Completion Date 2/17/2014 Operator CONOCOPHILLIPS ALASKA INC Completion Status 1 -OIL Current Status 1 -OIL ED C 24118 Digital Data ED C 24118 Digital Data ED C 24118 Digital Data ED C 24118 Digital Data ED C 24118 Digital Data ED C 24118 Digital Data ED C 24118 Digital Data ED C 24118 Digital Data ED C 24118 Digital Data ED C 24118 Digital Data ED C 24118 Digital Data Log C 24118 Log Header Scans 0 0 ED C 24118 Digital Data Log C 24119 Log Header Scans 0 0 ED C 24119 Digital Data 70 7900 ED C 24119 Digital Data ED C 24119 Digital Data ED C 24119 Digital Data ED C 24119 Digital Data ED C 24119 Digital Data ED C 24119 Digital Data API No. 50-029-23505-00-00 UIC No 4/2/2014 Electronic File: 2E-04 EcoScope Memory Drilling Data.dlis 4/2/2014 Electronic File: 2E-04 EcoScope Memory Drilling Data.html 4/2/2014 Electronic File: 2E-04 Final Standard Report -3- 27-2014 15-34-35.xlsx 4/2/2014 Electronic File: 2E-04 [canvas].txt 4/2/2014 Electronic File: 2E-04 [macro].txt 4/2/2014 Electronic File: 2E-04 [petrel].txt 4/2/2014 Electronic File: 2E-04 [surveys].txt 4/2/2014 Electronic File: 2E-04 EcoScope 2 inch MD Recorded Mode Log.PDF 4/2/2014 Electronic File: 2E-04 EcoScope 2 inch TVD Recorded Mode Log.PDF 4/2/2014 Electronic File: 2E-04 EcoScope 5 inch MD Recorded Mode Log.PDF 4/2/2014 Electronic File: 2E-04 EcoScope 5 inch TVD Recorded Mode Log.PDF 2131680 KUPARUK RIV UNIT 2E-04 LOG HEADERS 8/6/2014 Electronic File: 2E-04 Final Field Surveys_2-10- 2014.pdf 2131680 KUPARUK RIV UNIT 2E-04 P61 LOG HEADERS 4/2/2014 Electronic Data Set, Filename: 2E-04PB1 EcoScope Memory Drilling Data.las 4/2/2014 Electronic File: 2E-04PB1 EcoScope Memory Drilling Data.dlis 4/2/2014 Electronic File: 2E-04PB1 EcoScope Memory Drilling Data.html 4/2/2014 Electronic File: 2E-04PB1 Final Stand a rd Repo rt_3-27-2014_15-31-54.xlsx 4/2/2014 Electronic File: 2E-04PB1 [canvas].txt 4/2/2014 Electronic File: 2E-04PB1 [macro].txt 4/2/2014 Electronic File: 2E-04PB1 [petrel].txt AOGCC Page 4 of 6 Wednesday, August 13, 2014 • DATA SUBMITTAL COMPLIANCE REPORT 8/13/2014 Permit to Drill MD 14823 2131680 Well Name/No. KUPARUK RIV UNIT 2E-04 TVD 6259 Completion Date 2/17/2014 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23505-00-00 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 24119 Digital Data 4/2/2014 Electronic File: 2E-04PB1 [surveys].txt ED C 24119 Digital Data 4/2/2014 Electronic File: 2E-04 PB1 EcoScope 2 inch MD Name Start Stop Recorded Mode Log.PDF ED C 24119 Digital Data 4/2/2014 Electronic File: 2E-04 P131 EcoScope 2 inch INFORMATION RECEIVED TVD Recorded Mode Log.PDF ED C 24119 Digital Data 4/2/2014 Electronic File: 2E-04 PB1 EcoScope 5 inch MD Core Chips Y� Production Test Information Y /9 Mechanical Integrity Test Information Y /lam Recorded Mode Log.PDF ED C 24119 Digital Data 4/2/2014 Electronic File: 2E-04 P61 EcoScope 5 inch Laboratory Analyses Y NA TVD Recorded Mode Log.PDF ED C 24119 Digital Data 8/6/2014 Electronic File: 2E-04PB1 Final Surveys.pdf ED C 24673 Digital Data 7882 6148 8/13/201419Electronic Data Set, Filename: COP _2E_04PB 1 _BestDT_sonicVl S I ON_6160 TO 7770 V1.las ED C 24673 Digital Data 8/13/2014 Electronic File: 1 COP _2E_04PB1_BestDT_sonicVISION_6160 TO 7770.pdf ED C 24673 Digital Data 8/13/2014 $Electronic File: COP _2E_04PB 1 _BestDT_sonicVI S I ON_6160 TO 7770 V1.dlis Log C 24673 Log Header Scans 0 0 2131680 KUPARUK RIV UNIT 2E-04 PB1 LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments Core Chips 7425 7512 1/23/2014 1440 INFORMATION RECEIVED Completion Report Directional / Inclination DataV' Mud Logs, Image Files, Digital Dat Y NA Core Chips Y� Production Test Information Y /9 Mechanical Integrity Test Information Y /lam Composite Logs, Image, Data Files G) Core Photographs YN Geologic Markers/Tops Y® Daily Operations Summary 0 Cuttings Samples Y NA Laboratory Analyses Y NA COMPLIANCE HISTORY Completion Date: 2/17/2014 AOGCC Page 5 of 6 Wednesday, August 13, 2014 Is DATA SUBMITTAL COMPLIANCE REPORT 8/13/2014 Permit to Drill 2131680 Well Name/No. KUPARUK RIV UNIT 2E-04 Operator CONOCOPHILLIPS ALASKA INC MD 14823 TVD 6259 Completion Date 2/17/2014 Completion Status 1-0IL Current Status 1-0IL Release Date: 11/13/2013 Description Date Comments Comments: API No. 50-029-23505-00-00 UIC No - - RB �eemsQ` --- A q --- Compliance Reviewed __ DatQvir��+ -_ AU6 3 L��� ft AOGCC Page 6 of 6 Wednesday, August 13, 2014 Originated: Schlumberger PTS - PRINT CENTER 2525 GAMBELL STREET, STE. 400 ANCHORAGE, AK 99503 (907) 273-1700 main RECEIVED Delivered to. AUG 13 2014 MakanaK Bender 1(907) Natural Resources Technician II AOGCCAlaska Oil & Gas Conservation Commission 333 W. Th Ave, Suite 100 Anchorage, AK 99501 793-1225 njA-Ai ..:w-�:izd �alasl .0Y 2-k 3- Vi l -Z\-5-X(0-6 7R NSMITTALDATE • ` TRANSMITTAL # DATA LOGGED '� /'t31201A M. K. BENDER SERVICE COLOR WELL NAME ORDER # FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED PRINTS CDs Transmittal Receipt A Transmittal Receipt signature confirms that a package (box, Venvelope, etc.) has been received and the contents of the X / package have been verified to match the media noted above. The Print Name Signature Date %1%3%)-ispecific content of the CDs and/or hardcopy prints may or may 1 j not have been verified for correctness or quality level at this Please return via courier or sign/scan and email a copy to Schlumberger. point. 561-8317 fax R 10 Transmittal Receipt A Transmittal Receipt signature confirms that a package (box, Venvelope, etc.) has been received and the contents of the X / package have been verified to match the media noted above. The Print Name Signature Date %1%3%)-ispecific content of the CDs and/or hardcopy prints may or may 1 j not have been verified for correctness or quality level at this Please return via courier or sign/scan and email a copy to Schlumberger. point. 561-8317 fax R 10 0 Guhl, Meredith D (DOA) • From: Little, Laird D. [Laird.D.Little@conocophillips.com] Sent: Monday, July 14, 2014 2:54 PM To: Guhl, Meredith D (DOA) Cc: Lemke, Sandra D; Bettis, Patricia K (DOA); Guo, Haibin Subject: RE: KRU 2E-04, PTD 213-168, Additional Geologic markers required Attachments: 2E-04_tops_compl_rept.xlsx Hi Meredith - Please see attached for formation tops in the recently drilled 2E-04 and 2E-04PB1. Let me know if you need anything else. Thanks, Laird From: Guo, Haibin Sent: Wednesday, July 09, 2014 5:26 PM To: Guhl, Meredith D (DOA); Little, Laird D. Cc: Lemke, Sandra D; Bettis, Patricia K (DOA) Subject: RE: KRU 2E-04, PTD 213-168, Additional Geologic markers required Laird, can you please help to fill the formation tops and geologic markers for Meredith as mentioned below? Thanks. 29. GEOLOGIC MARKERS (List all formations MD Permafrost - Top Permafrost - Base Formation at total depth: encountered): 1 30. ❑ FORMATION TESTS TVD Well tested? Yes No If yes, list intervals and formations briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. • 0 From: Guhl, Meredith D (DOA)[mailto:meredith.guhl@alaska.gov] Sent: Wednesday, July 09, 2014 4:48 PM To: Guo, Haibin Cc: Lemke, Sandra D; Bettis, Patricia K (DOA) Subject: [EXTERNAL]KRU 2E-04, PTD 213-168, Additional Geologic markers required Haibin, During the review of the Well Completion Report Form 10-407 submitted for KRU 2E-04, it was noted that the list of formations and geologic markers encountered (Box 29) is incomplete. Please provide an updated list of formations and markers encountered, including the MD and TVD of each formation. The list can be sent via email. Please provide the list by 8/9/2014. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 2E-04 Pick MD TVD TVDSS base permafrost 1499 1486 1353 Top Ugnu(Ugnu C) 2057 2011 1878 Top W Sak (W Sak D) 2936 2685 2552 base W Sak 3699 3199 3066 top HRZ 7573 5717 5584 upper_kalubik (base HRZ) 8002 5925 5792 lower_kalubik (K-1 mkr) 8220 6013 5880 Kuparuk C (top C4) 8493 6100 5967 Kuparuk B1 8527 6108 5975 Kuparuk A6 8635 6135 6002 Kuparuk A5 8738 6150 6017 TD (Kuparuk A5) 14823 6259 6126 2E-04 MD where entered Top of Fm at TD Fm at TD Kuparuk A5 8738 2E-04PB1 _ Pick KOP from 2E-04 top HRZ upper_kalubik (base HRZ) lower_kalubik (K-1 mkr) Kuparuk C (top C_4) Kuparuk B1 Kuparuk A6 Kuparuk A5 Kuparuk A4 Miluveach TD (Miluveach) MD j - 5550 7004 7217 7301 7391 7395 7423 7439 7471 7533 7900 TVD 4438 5700 5913 5997 6087 6091 6119 6135 6166 6229 6595 TVDSS 4305 5567 5780 5864 5954 5958 5986 6002 6033 6096 6463 2E-04PB1 MD where entered Top of Fm at TD Fm at TD Miluveach 7533 ,.,Schlumberger Drilling &Measurements MWD/LWD Log Product Delivery Customer: ConocoPhillips Alaska Well No: 2E - 04 Job#: 13AKA0119 Dispatched To: Date Dispatched Dispatched By: �G4�-6 Transmittal #: 6819 DATA4000ED 'L/ • /2014 M K BENDER Makana Bender 2 -Apr -14 Stephanie Pacillo Well / Product Hardcopy Digital Copy E -Delivery Date Color Log Prints: 4 Vision Service 2" MD leach Contents on CD Vision Service 2" TVD 1 each Contents on CD Vision Service 5' MD 1 each Contents on CD Vision Service 5' TVD 1 each Contents on CD LAS Digital Data Contents on CD SURVEYS 1 Contents on CD FINAL SURVEY 1 each EOW CD 1 CD 111C M IAOGCC Received By: Please sign and email a copy to: Cho(@-slb.com Jason Ho 907-265-6519 ATO 1525 N Please sign and email/fax a copy to: spacilloCa)-slb.com Stephanie Pacillo Fax: 907-561-8317 Report Date: March27,2014-D3:34PM Client ConoccPhillps(Aaska) Inc.-Kup2 Field: Kuparuk River U,12 Structure/Slot: Kuparuk 2E Pad 12E-04 Well: 2E-04 Borehole: 2E-04 UWI/API#: 10350556/50-029-23505-00 Survey Name: 2E-04 Final Survey Data: February 12, 2014 Tart / AHD / DDI / ERD Ratio: 240 86 ° 111548.718 It 16.819 / 1.845 Coordinate Reference System: NAD83 Alaska State Pane, Zone 04, US Feet Location Let / Long: N 70° 1530.15358", W 149° 45'39.0754a Location Gritl WE mN 5943973.000 flUS, E 167OW3470 flUS CRS Grid Convergence Angle: 0.2251 ° Grid Scall Factor: 0.99990099 Version / Patch: 27,1043.0 • 2E-04 Final Survey Report (Def Survey) Survey l DLSCamputation: Minimum Curvature/Lubinaki rti VecalSection Azimuth: 180.000 ° (True North)Verb-, Section Origin:0,000 gin: ft, 0 000 ft TV" Reference Datum: RK8 TVD Reference Elevation: 132,520 fl above Mean Sea Level Seabed/ Ground Eleva6om 105.1 ft above Mean Sea Level Magnetic Declination: 79.524 ° Total Gravity Field Strength: I001.9572mgn (9.80665 Based) Gravity Model: GARM Total Magnetic Field Strength: 57605.129 nT Magnetic Dip Angle: 80,861 ° Declination Date: January 10, 2014 Magnetic Declination Model: BGGM 2013 North Reference: True North Grid Convergence Used: 0.0000 ° Total Corr Mag Willi 27.42 North' 195239- 95239°North: Local Coord Referenced To: Well Head ConocoPhillips APR 0 2 2014 Commends MD IMI Azim True TVOSS TVD VSEC AHD Closure NS EW DLS Ncrtl Easting Latitude Longitude T ffll 0.00 !°I 0.00 I°I 0.00 IRI -132.52 IRI 000 1R1 0.00 ffl1 0.00 Iftl 0.00 IRI 000 ffll 0.00 I /100R1 N/A IRUSI 594397300 fflU51 167000347 f 1 1 ) 7025837600 Ground Level 27.42 ODD 0.00 -105.10 27.42 0.00 0.DO 0.00 0.00 0.00 0.00 5943873.00 1670003.47 -149.76085428 70.25837600 -149.76085428 10800 006 3651 -24.52 108.00 -003 0.04 0.04 0.03 003 007 5943973.03 1670003.49 70.25837609 -149.76085407 785.00 277.00 0.23 8401 52.48 785.00 -0.08 023 0.22 0.08 0.20 0.25 5943973.08 7670003.67 70.25837622 -149.76085264 0.24 99.28 144.48 27]00 -007 0.60 0.58 007 0.58 007 594397307 167000405 7025837619 -149.76084962 368.00 462.00 0.81 1.81 250.29 235.48 368.00 0.18 1.18 0.24 -0.18 0.16 1.13 5943972.62 1670003.63 70.25837551 -149.76085299 555.00 2.W 25470 261.79 329.45 422.38 4619] 0.79 333 2,06 -0.79 -190 1.07 594397220 1670007.58 7025837383 -149.76086962 649.00 3.29 26289 51626 554.90 1.48 6.90 5.60 -1.48 5.40 0.90 5943971.50 1689998.07 70.25837195 -149.76089794 742.00 4.29 287.82 60905 648.78 2.12 1173 1041 -2.12 -10.19 0.74 5943970.84 16 999329 70.25837020 -149.76093663 768.37 4.26 26870 63535 741.57 2,58 17,87 18.52 -2.58 -16.31 1,13 5943970.35 1669987.17 70.25836884 -149.76098612 86102 5.00 270.12 727.70 767.87 264 1984 1847 -2.64 -18.28 027 5943970.29 1669985.20 7025836878 -149.76100200 952.98 6.03 267.11 51923 No 22 95175 2.71 2.95 27.32 36.15 25.90 34.71 -2.71 -2.95 -25.76 34.59 0.81 1.16 5943970.19 594396992 1669977.73 1669988.90 7025836859 -149.76106244 7025836]94 -149.76113382 1045.63 8.48 282.05 911.13 1043.65 4.14 47.85 46.40 -4.14 -46.22 2.73 5943968.68 1669957.28 70.25836469 -149.76122779 113837 9.82 26131 1002.69 1135.21 6.28 6259 61.13 3.28 -60.81 1.45 5943966.48 1669942.69 70.25835884 -149.76134571 1231.19 12.83 259.70 1093.1 1226.21 9.32 1.82 79.32 -9.32 -78.77 3.26 5943963.37 1669924.74 70,25835054 -1,1761 49 0 93 1323.55 14.43 25891 1183.45 1315.97 1336 102.58 101.05 -13.36 -1 DO 16 174 594395924 766990337 70.25833948 -149.76166376 1416.77 15.28 255.48 127292 1405.44 18.64 126.30 12469 -18.64 -123.28 1.32 5943953.88 1669880.27 70.25832506 -149.76185066 1508.96 1596 25426 136234 1494.86 25.17 151.30 149.55 -25.17 -147.41 0.81 594394]25 1669856.17 70.25830722 -149.76204568 1601.36 15.1 250.03 1451.24 1583.78 32.89 176.49 774.57 32.88 -1]1.39 1.28 5943939.45 1669832.23 70.25828615 -149.76223941 1(59355 16.(54 24399 1539.79 1672.31 42.93 202.13 199.64 -02.93 -19497 2.09 594392931 1669808.69 70.25825870 -149.76242999 1787.15 18.73 233.93 7628.98 1761.50 57.66 230.50 226.62 57.66 -219.17 3.95 5943814.48 1869784.55 70.25621845 -149.76262557 187].58 2018 22976 1714.25 1846.77 76.29 26WO5 254.51 -76.29 -24281 222 594389577 1669760.99 7025816756 -149.76281665 1972.34 26.22 223,02 180132 1933.1 102.18 297.88 288.31 -702.18 -21.10 895 5943869.77 781734.30 70.25809(582 -149.78303315 2064.63 2971 22185 1882.82 2015.34 134.13 341.15 32].50 -134.13 -298.78 3.83 5943937.71 166970525 70.25800953 -149.76326894 2157.53 30.38 219.72 1963.24 2095.76 169.35 387.66 370.76 -11.35 -328,15 1.36 5943W2.38 1669675.02 70.25791331 -149.76351440 224]55 35.09 21601 203895 2171.47 20781 436.32 41475 -207.81 -358.93 5.66 59437(5380 1669645.40 70.25780821 -149.76375505 234242 37.42 214.14 2115.45 2247.97 253.74 492.41 486.23 -253.74 -397.14 2.72 5943717.75 166961337 70.2571275 -149.76407537 2435.19 40.13 212.75 21 877] 2320.29 30222 55050 51998 -302.22 -423.14 307 5943669.15 166958156 7025755029 -149.76427395 2527.58 40.78 210.33 2258.06 2390.58 353.30 610.43 575.65 -353.30 454.48 1.84 594361796 1669550.43 70.25741074 -149.76452720 2619.23 4171 207.23 2326.99 2459.51 40626 67086 63156 -40626 -083.55 2.l5 5943564.88 1669521.56 7025726604 -149.76476215 2712.35 2804.38 41.84 47.20 20699 2396.44 2528% 481.48 732.90 689.15 481.48 511.82 0.22 5943509.56 1669493.51 70.25711517 -149.76499059 2898.39 205.24 2462.03 259455 51942 797.40 74939 519.42 -540.17 5.97 594345152 1(569465.40 7025695688 -149.76521965 299100 48.02 205.84 2525.41 2657.93 582.06 866.83 81475 58206 -570.11 0.99 5943388.7(5 1669435.71 70.25678572 -149.76546155 3082.87 46,70 205.51 2588.15 2720.67 643.46 934.96 57954 -(543.46 -59963 1.45 5943327.25 165940844 7025661797 -149.76570006 47.22 205.95 2650.85 2783.37 703.95 7002.70 943.88 -703.95 528.78 0.67 5943266.66 161377.53 7025645272 -149.76593559 3176.58 4]55 206.32 2714.30 284(5.82 ]65 86 10]1.06 101046 -]65.86 -659.16 5943204.63 161347.39 7025628356 -149.76618104 321.24 47.1 20457 2776.81 291.33 827.62 1139.46 1076.59 -827.1 -fde.54 146 1.40 5943142.77 161318.26 70.25611483 -149.]611845 3362.37 47.50 203.83 2839.6] 2972.19 89030 1208.18 1142.93 -890.30 -71671 0.60 594307999 1669290.34 7025594358 -14976664604 3454.33 47.52 205.02 2901.78 3034,3p 95204 1275.% 1208.73 -952.04 -744.75 0.95 143018.14 16126254 70.25577490 -149.76687258 354]8 47.66 205.02 2964.71 3097.23 1014.46 1344.87 1275.94 -1014.46 -77388 0.15 5942955.61 16123366 7025550435 -749.7(5710796 3638.87 48.02 204.92 3025.95 3158.47 107577 7412.51 1342.06 -1075.77 -802.43 040 5942894.19 1669205.35 70.25543684 -149.76733863 3732.23 4786 20568 3088.49 322101 113844 1481.82 141009 -113844 -832.05 0.63 5942631.42 161175.98 70.25526563 -149.76757794 103/4°Sudace 3755.85 4804 205.59 3104.31 3236.83 1154.25 1499.36 1427.34 -7754.25 -839.64 0.81 5942815.56 1669168.45 70.25522242 -149.76763924 Casng 3816.30 4864 205.26 3144.49 327701 1195.04 1544.52 14]1.75 -1195.04 -859.03 1.07 59427]4.]2 1669149.23 70.25511098 -149.76779586 385386 49.01 205,05 311.29 3301.81 1220.70 1572.87 1499.62 -1220.70 -871.08 1.07 5942749.02 161737.28 70,25504088 -149.76789319 3908.96 4861 205.60 3205.51 3338.03 1258.11 1614.26 1540.36 -1258.11 -886.78 705 594271154 1669119.73 70.25493866 -149.76803621 401.85 48.40 206S2 3266.39 3398.91 1 31 9.83 1683.08 1608.39 -1319.83 -919.23 1.10 5942649.70 1669089.52 70.25477003 -149.76828221 4094]9 47.86 207.34 332909 346161 1382.08 175303 1677.74 -138208 -951.13 O.fifi 5942587.33 166905]87 70.25459993 -149.76853990 4187.26 47.78 206.46 3391.18 W2370 7443.19 1821.56 1745.68 -7443.19 482.13 0.71 142526.71 188902].11 70.2544329] -149.76879035 428026 4787 206.59 3453.62 3586.14 1504.86 1890.48 1814.00 -150486 -701291 0.14 142464.32 1668996.58 70.25426448 -149.76903900 4373.12 47.73 207.26 3516.00 3648.52 151.19 191.27 1882.29 -1566.79 -7044.06 0.56 5942402.88 1668965.67 70.25409690 -749.76929063 4465.14 47.60 208.15 3577.97 3710.49 162642 2027.29 1949.96 -1626.42 -1075.69 073 594234253 166693429 7025393236 -149.76954609 4555,94 47.83 20929 3639.74 3772.26 1685.97 2095.27 201],84 -1685.97 -1108.32 0.95 5942282.88 7668901.89 70.2537163 -149.76980972 4649.38 4764 20973 370191 3834.43 1745.51 2163.62 208591 -1745.51 -114202 0.41 5942223.19 1668868.43 70.25360697 -749.77008192 47 47.77 47.77 21.72 3764.31 3896.83 1805.07 2232.21 2154.36 -1805.07 -1178.03 0.14 5942163.50 1668834.66 70.25344422 -149.7]035665 4834.1 4]75 21004 3826.35 - 3958.87 1864.31 23153 2222.59 -1864.31 -1210.06 0.26 5942104.14 166880066 70.25328237 -149.77063158 4926.71 47.1 209.68 3888.46 4020.W 1923.55 2368.83 2290.80 -7923.55 -7244.07 0.30 142044.77 1668767.08 70.25312052 -149.77090628 5020.11 47.58 20849 3951.39 4083.91 1983.85 2437.84 2359.66 -198385 -127767 0.95 5941984.34 166873379 7025295575 -149.77117725 5113.35 47,76 208.94 4014.18 4146.70 2044.87 2506.77 2428.32 -2044.87 -1309.67 7.24 14192321 1668701.96 70.2527102 -149.7714816 5206.14 4809 206.06 4076.36 4208.88 210651 25]564 2496.81 -210651 -1340.40 079 594186145 761671.49 7025262061 -149.77768437 5298.54 48.19 205.73 4138.02 4270.54 211.42 26M.46 2565.19 -2768.42 -1370.45 0.29 594179943 1668841.68 70.25245146 -149.77192710 5390.24 4833 208.59 419907 4337.1 2229.83 2712.88 2633.23 -2229.83 -1400.62 072 594173].91 1668611.76 70.25228366 -149.77217075 Tle-lh 548.34 48.28 205.93 4267.00 4393.52 2292.17 2782.40 2702.39 -2292.17 -143138 0.53 5941675.45 1668581.25 70.25211333 -14577241916 5576.27 4890 202.98 222.48 4455.00 2355.61 2852.09 2771.48 -235561 -1460.22 247 594161191 156855267 7025794001 -149.]72(55207 56 7.77 48.81 194.85 4382.74 4515.26 2420.1 2920.94 2838.59 -2420.69 -1482.52 6.69 941646.75 1668530.62 70.25176219 -149.7728217 5761.81 49.12 193.95 4444AS 4577,00 2489.39 2991.88 2906.47 -2489.39 -1500.16 079 594147798 166851325 7025757448 -149.7/297458 585475 49.20 195.97 4505.26 4637.78 2557.32 3062.19 2974011 -2557.32 -1518.31 765 5941410.00 1666495.37 70.2513890 -149.77312111 5947.13 49.17 19825 4565.65 4698.17 2624.13 3132.10 304207 -2624.13 -153888 1.87 5941343.11 16(58475.07 7025120635 -149.77328716 6039.77 48.96 200.30 462635 4758.87 2690.19 3202.08 311077 -2690.19 -156198 1.69 5941276.97 1668452.23 7025102587 -149.77347366 6133.38 49.05 202.23 4(58776 4820.28 2]56.02 3272.73 3180.59 -275602 -1587.60 1.55 594121104 1668426.87 7025084599 -149.77368057 631 48.82 204.38 4748.42 488.94 2819.96 3342.35 3249.74 -2819.98 -1815.14 1.77 594114700 166839959 7025087130 -149.77390294 11 878.11 4864 20721 4809.37 4941.89 2882.47 3477.78 3319.00 -288247 -164535 2.31 5941084.38 16683(59.62 ]025050050 -149.77414689 6410.8 47.81 208.00 4871.01 5003.53 2943.33 348.78 3387.97 -2943.33 -1677.84 1,70 5941023.40 161337.37 7025033421 -749.77440931 6504.37 4765 209.48 4934.06 5066,58 3003.86 3550.14 345].33 3003.56 -1711.72 042 594/6275 1666303.73 7025016882 -149.]7468293 6596.95 47.44 209 88 4896.55 5129.07 3063.20 3618.45 3525.64 3063.20 -1745.55 0.39 5940903.27 1668270.15 70.25000887 -149.77495606 6689.39 4]40 209.44 159.10 5191.62 3122.35 3686.52 3593.71 -312235 -1 T/923 0.35 5940844.00 1668236.70 70.24984506 -149.7]522806 6761.1 48.20 208.51 5121.03 5253.55 3182.10 3754.81 3661.99 -3182.10 -181231 1.15 5940784.13 1668203.86 70.24968180 -149.77549519 6873.58 49.74 208.13 5181.42 5313.94 3243.19 3824.21 3731.37 -3243.19 -184523 1.70 594072291 1668171,18 7024951 48] -149.77576102 166.91 51.57 207.39 5240,59 5373.11 3307.06 388638 3803.57 3=7.06 -1878.84 2.05 5940658.92 166813]83 70.24934036 -149.7703241 705853 52.92 207.18 5296.68 5429.20 3371.44 3966.82 3875.89 337144 -191204 148 5940594.42 166810488 7024916445 -1497]630052 7151.8 8.87 206.57 5352.20 5484.72 3438.10 4043.56 3950.54 3438.10 -1945.83 1.15 5940527.63 1668071.36 70.248982= -149.77657329 ]244.88 5497 20589 5406.45 5538.97 3506.13 4119.39 4026.26 -3506.13 -197934 1.32 5940459.47 1668038.12 70.24879641 -149.77684390 7337,93 56.8 205.37 5459.16 5591.8 3575.27 4198.08 41027] 3575.27 -2012.51 1.23 5940390.21 1668005.22 70.2480750 -149.7]711169 7430.28 57.26 204.19 5509.93 564245 3645.31 42 321 4179.67 -3645.31 -2044.84 1.71 594032006 1667973.18 7024841614 -149.77]37266 7524.94 58.12 20327 5559.8 5692.35 3718.94 4353.1 4259.73 3718.94 -2077.20 2.13 940246.30 1867941.10 70.24821493 -149.7778393 ](516.18 5966 202.76 5606.29 5738.81 3791.22 4432.18 4337.81 3791.22 -210]90 0.76 5940173.91 166791089 70.24801]45 -149.7778817] ]]08.31 6.07 203.00 5852.54 578.06 3864.8 451186 4417.03 3864.63 -2138.88 O.W 5940100.39 1667850.00 7024781687 -149.7781318 7801.59 6.60 20199 5698.71 5831.23 393951 459291 449758 -393951 -216989 1.10 5940025.39 1667849.29 7024761225 -1497]838216 7893.92 61.8 207.68 5743.27 5875.79 4014.58 4873.77 4577.84 -4014.58 -2199.96 1.21 5939950.22 1667819.52 70.24740716 -149.77882492 798637 8.24 200.09 578602 5918.54 4091.16 4755.74 4659.06 -409116 -2229.18 2.27 593987353 166779061 70.24719790 -149.77886071 1]9.8 8.32798.61 ' Sit 959.11 4170.62 4839.95 4742.20 -4770.62 -225].07 2.64 5939793.97 1667763.03 702469BOW -149.77908583 8172.17 67.40 197.71 5863.61 5996.13 4251.11 02452 4825.35 -4251.11 -228300 2.70 593971338 1667737.42 70.24676087 -149.77929506 _ 8265.30 69.11 195.78 518.77. 60=.63 4334.07 5011.02 4910.05 -0334.07 -2307.48 2.27 5939630.34 1667713.27 70.24653420 -149.7794926 835528 71.02 794.91 5928.79 6061.31 4415.64 5095.61 4992.61 -441564 -2329.86 2.31 593954869 166769121 70.24631133 -149.77967316 8445.97 73.26 193.61 59 .6 W69.12 449929 5181.92 5076.55 4499.29 -2351.11 2.82 5939464.96 1667670.29 70.2468276 -1497798448 8540.58 7637 19117 598138 6113.90 458846 5273.21 516470 4588.46 -237068 4.12 5939375.73 166781.07 7024583915 -148.78000250 8633.90 79.38 18960 10098 6133.5) 4678.19 864.44 5252.03 -4678.19 -2387.12 3.52 5939285.94 166784.98 70.24559398 -149.78013504 8726.91 81.62 188.96 6016.33 6148.85 4768.72 5456.17 5339.16 -4768.72 -240191 2.50 593919537 1667620.55 70.24534664 -149.78025427 8771.51 8296 189.19 6022.32 6154.84 4812.36 550037 5381.59 4812.36 -2408.88 3.05 5939151.70 1667613.75 7024522741 -149.]8031046 7-5V Casing 8830.70 85.76 18863 6028.13 6160.65 4870.55 5559.26 543774 -4670.55 -2418.01 4.83 5939093.48 1667604.86 70.24506843 -149.78038399 869.8 87.1 188.27 6030.38 6162.90 4908.89 5598.03 5474.8 4908.89 -242370 4.83 5939055.72 1667599.31 70.24496367 -149.78042991 Drilling Office 2.7.1043.0 Kuparuk River Unit2\Kuparuk 2E Pad\2E-04\2E-04\2E-04 Final 3/31/2014 5:21 PM Page 1 of 2 Comments MD Incl Azim True NDSS NO VS AHD Closure NS EW D -Northing 10.750 SLB_NSG*SSHOT-Depth Easting 11111"61 Lengftude Ad Sh1s IRI 896392 1°I 81 1°7 18].84 is 6033.22 IR) 6165.74 IRI 5002.30 Iftl 5692.37 IRl 5564.32 Iftl 5002.30 fRl -2436.92 (/700ft1 1.50 IftU51 5938967.67 (ftU51 1667586.46 1 1 1 7 70.24470845 Ad Stns 9058.17 9152.95 91.38 187.19 6032.95 8165.47 5095.74 5786.67 5653.79 -5085,74 -2449.25 2.67 5938868.20 166757450 -149.78053643 70.24445318 -749.780635]4 9248.17 9294 187.87 6029.38 61fi1.90 5189.65 5881.32 5]43.82 -5189.65 -246150 172 593877425 166756263 70.24419659 -149.78073440 9342.20 92.35 91.27 18995 6024.98 6157.50 5283.58 5976.38 5834.99 -5283,58 -2476.05 2.47 5938680.27 7667548.44 7024383996 -149.78085174 9437.07 69.01 190.32 189.68 602206 615458 5375,16 607043 5925.89 -537616 -249260 7.27 593858]64 t6fi753226 7024368702 -149.78098514 ° 953273 8813 190.66 8021.88 6024.27 6154.40 5469.52 6165.23 6017.56 -5469.52 -2509.07 2.42 593849422 1667516.16 70,24343193 -149.78111764 9626.93 88.47 190.90 615679 5563.70 6260.92 6110.26 5563.70 -252596 1.38 593839998 1667499.64 70.24317460 -149.78125404 9721.72 8905 19097 8027.08' 6159.58 5656.20 6355.08 6201.80 -5656.20 -2543.57 0.44 5938307.42 7687482.38 70.24292188 -149.78739602 9816.03 8922 791.51 fi029.11 8030.54 8161.63 574925 6449.84 fi294p7 -5749.25 -256155 062 5938214.32 7667464.78 70 42667 -149.78754094 9911.18 8934 79281 6031.73 616306 5847.74 6544.14 6386.07 -5841.74 -257993 0.80 5938121.76 168749fi.7] 70.24241495 -149.78168812 10005.70 87.54 6034.31 6164.25 5934.73 6639.29 6479.29 5934.73 -2600.05 1.48 593802871 166]42701 70.24216089 -149.78185136 10100.95 195.24 6166.83 '26 1 :733.77 6572.47 1026.36 -2623.03 3.11 5937936.99 1667404.40 70.24191051 -149.78203664 8637 85.91 19529 186.09 6039.37 6045.74 617169 611812 6828.88 6666.61 -6118.12 -2648.07 123 5937845.14 1667379.72 7024165980 -149.78223861 10795.60 10290.96 87.44 194.88 6057.27 6178,26 618379 6209.04 6923.32 676020 -6209.04 -2673.61 0.97 5937754.14 1667354.54 7024141139 -149.78244458 10385.80 87.92 194.39 6055.11 6187.63 6300.78 7018.51 6854.52 -6300.78 -2699.02 2.04 593766231 166732949 7024116073 -149.78264954 1048023 87.68 194.02 605873 6191.25 6392.46 7113.27 6948.25 1392.46 -2722.96 0.72 593757053 1667305.91 70.24091021 -749.78284282 10575.91 87.58 194.24 6062.69 6195.21 6483.94 720].63 7041.49 -648394 -2746.92 0.47 593747898 1667263.12 7024066027 -149.78302933 ,� _.... 70670.75 8775 19425 fi06655 6578.64 7303.23 7135.98 -6576.64 -2769.46 0.25 5937386.19 1667260.15 70.24040697 -149.78321751 _ 70764.80 87.44 193.64 6070.50 6199.07 6203.02 666849 6759.89 739799 722969 -666849 -2]9277 0.18 593]29426 166]237.19 70.24015602 -149.78340552 _ 90859.30 9138 191.23 60]1.47 7491.96 7322.57 1759.69 -2815.42 0.73 5937202.99 166721491 70.23990684 -149.78358810 10954.26 97.56 190.03 6089.04 6203.99 6201.56 6851.94 ]586.44 7415.57 105194 -2835.76 4.89 5937110.66 1fi67194.93 70.23965478 -149.78375208 11047.66 9166 189.16 606641 6198.93 6945.24 7681.37 7508.50 -6945,24 -285327 1.28 5937017.31 7667177.79 70.23939987 -149.78389319 11142.29 9169 18747 6083.65 6196.17 7037.30 7130.89 7]7473 759959 -7037.30 -206883 094 593692520 166716259 70.23914835 -149.78401856 11237.64 91.14 785.69 6061.29 7869.32 7691.5 -7130.89 -2882.51 1.79 5936831.56 166]149.28 70.23889264 -149.78412872_'.: 11332.3] 90.68 184.01 6059.79 619389 7225.58 7964.64 7783.38 -7225.58 -2893.43 1.95 593673684 166713873 70.23863394 -149.78421661 11520,66 8786 784.10 6060.99 6192.37 7379.95 8059.36 7874.01 -7319.95 -2901.44 1.84 5936642.45 1667131.10 70.23837609 -149.78428098. � �. 71520.68 88.64 185.38 W6316 6193.51 7413.89 8153.53 7963.84 -741369 -290810 DO 593654849 166712481 70.23811945 -749.78433445- 11615.66 8551 184.41 606871 6196.38 75 I'M 8247.59 8053.99 -7507.62 -2915.87 7.59 1 5936454.74 1667117.40 70.23786336 -149.78439691i [. ;.. 17709.38 87.83 717230 6074.15 6201.23 7602.14 834245 8145.0] -7602.14 -29239] 3.45 593636020 1667109.68 70.23760513 -149.78446198 1180258 88.16 180]3 60T 41 8206.67 6209.93 7885.53 8436.01 8234.25 -7695.53 -2929.44 3.34 5936266.80 1867104.58 70.23734997 -149.784505811 -_ 11898.53 08.54 180.40 6080.18 6212.70 7788.64 8529.15 8322.19 -T8864 -293190 1.72 5936173.69 166710248 70.23]09560 -14978452546 11993.76 8988 179.60 6081.49 621401 ]884.54 8625.06 8412.35 -7884.54 -2932.85 0.52 5938077.80 1667101.91 70.23683358 -749.78453280', [;'_....... 92088.80 90.48 178.42 8081.21 6213.73 797976 8720.28 8501.66 -7979.76 -2932.85 164 5935982.59 1667702.28 70.2365]344 -749.78453250 12181.82 8994 17963 6080.88 621340 807479 8815.32 859014 1074.79 -2932.04 0.64 5835887.57 1667103,47 70.23831380 -149.78452584'; 12T74.46 90.18 179.07 8080.79 8213.31 8167.81 8908.34 8677.87 -8167.81 -2931.27 0.60 5935794.56 166110461 70.23605968 -149.78451912 12369.15 8891 6081.54 0260.44 9000.98 8764.75 1260.44 -2930.17 0.72 5935701.94 1667106.07 70.23580660 -149.78450M 12462.92 72552.25 87.37 8671 18040 181.39 8084.58 621406 6217.10 8355.73 8448.83 9095.66 9789.38 8853.88 8942.84 -8355.13 43448.83 -292968 -2931.14 1.99 1.95 5935607.27 5935513.57 166710693 1667105.83 70.23554]93 -749.784505]2 7023528182 -149.78451724'. 12646.99 87.37 182,43 78282 608920 6221.72 853799 9278.59 9028.08 -8537.99 -2934.12 130 5935424.41 1667103.21 7023504833 -149.78454096 12744.06 8757 18183 609409 60983] 6226.61 8632.50 937320 9118.91 1832.50 -2938.45 0.81 5935329.89 1667099.25 7023479011 -149.78457584 a ,.. 1283947 12932.08 89.15 179.69 6101.10 6230.89 6233.62 8729.40 6824.75 94]0.18 9565.54 9211.95 9302.76 -8]2940 1824.75 -294238 -2943.65 1.04 2.79 593523299 5935137.64 1667095.70 166709481 7023452539 -149.78460709 70.23426488 -149.78461700. ,. 13021.75 90.42 87.94 17979 181.38 6101.45 6233.97 8917.36 9650.15 939052 -8917.36 -2943.23 1.38 5935045.05 166709559 7023401187 -149.78467331 13116.73 86.92 181.73 6102.73 610699 6235.25 9007.00 9747.81 9475.98 -900700 -2944.14 3.29 593495541 1667095.03 70.23376895 -149.78462042 13278.46 90.57 783.21 6109.78 6239.51 9101.85 9842.69 956697 -910985 -2946.72 7.14 5934860.56 166]092.83 7023350782 -149.78464090 ,. 1331558 89.20 1]9.00 6109.38 624770 6241.90 9201.45 9942.38 96fi3.08 -920145 -2957.01 3.85 593476096 1687088.92 7023323572 -149.78467527 '...- 13409.32 90.47 1]7.79 6109.65 6242.17 9300.52 9394.21 1004150 9758.25 -930052 -2953.62 3.71 593466789 ifi67086.71 7023296506 -149.78459597 13503.37 9008 17899 6 09.19 10135.23 9846.85 539421 -2951.15 3.10 5934568.22 1867089.54 70.23270908 -149.78467580' 13597.37 90.08 180.84 6 0906 6241.71 9486.20 70229.28 993564 -9488.20 -294802 1.96 593447425 166709304 7023245229 -749.78465020 _. 13692.84 90.68 181.61 6108.43 6241.58 6240.95 9582.20 96T 65 10323.28 10418.75 1002535 10117.16 -9582.20 -9677.65 -2947.72 -2949.59 1.76 1.19 5934380.28 5934284.82 1667093.71 16fi7092.21 70.23219549 -149.78464746 70.23193472 13787.81 1388005 89.43 183.017 8108.34 6240.86 9772.54. 10513.72 10209.09 -9772.54 -2953.47 2.02 5934189.93 1687088.71 -149.78466228 70.23167548 -149.78469328 139]5.53 89.36 18429 6109.31 6241.83 9864.58 10605.95 10290.93 -98fi458 -295939 1.32 5934097.87 1667083.75 70.23142401 -14978474077 ,... 74068.63 89.50 8926 183.68 6110.26 6242.78 9959.82 10701.43 10392.08 5359.82 -2966.01 0.88 5934002.81 1667078.91 70.23118379 -749.784]9389 f 74160.86 88.74 18309 180.54 61128 6243.80 1005375 1079552 1048370 -1005375 -297155 066 593390867 166707174 7023090776 -749.78483830 14258.86 89.09 180.79 6112.87 6114.73 6245.39 10144.92 10886.74 10571.97 -10144.92 -29]444 2.85 5933817.50 1867069.21 70.23065810 -149.78486133 14354.10 88.98 781.56 6116.33 624725 10242.90 10984.72 10666.20 -10242.90 -2975.06 0.51 5933719.53 166706897 7023039041 -149.78486605 -_........ 1444777 88.98 18124 6118.00 8248.85 6250.52 70338.11 11079.85 10]58.07 -10338.11 -2976.51 1.44 6933624.32 1667067.89 70.23013028 -149.78487749 14540.01 88.19 18255 6178.47 6251.99 1043174 11173.60 10848.70 -70431.74 -2978.80 0.34 593353070 166]06597 7022987449 -149.78489565 ,.. 74630.45 88.30 184.47 fii 2145 6253.97 10523.91 11265.83 10938.20 -10523.91 -2981.85 1.44 5933438.52 1667083.28 70.22962266 -149.78499997 14704.68 88.26 184.86 6123.88 6256.20 10614.16 1135625 11026.55 -1 W14.96 -298739 2.34 5933348.26 1667058.10 70.22937610 -148.78486436 _. 1473131 8843 785.50 6124.45 70698.11 11430.44 11099.38 -10688.11 -2933.42 0.53 5933274.30 166705236 70.22977406 -149.70501282 4-!/2'TO !4818.00 88.42 185.26 8126.78' 6256.97 6259.30 10714.62 !0798.90 1145].06 11125.56 -10714.62 -2995.82 249 5933247.78 1667050.06 70.22910163 -149.78503213 Proj to TO 14823.00 88.42 18524 6126.97 11541.72 11208.67 -!0798.90 -3003.76 0.28 5933!63.47 1667042.45 70.22887135 -149.78509592 6259.49 10805.87 11548.72 11215.76 -10805.87 1004.40 028 5933156.50 166704184 7022885231 -149.78510706 Survey Type: Der Survey Survey Error M16el: Srrvey Program: Description ISCWSA Rev 0' 3-D 95.000% Confidence 2.7955 sigma Part MD From MD To �1 (ft) 0.000 33.520 33 520 742.000 742000 3878.300 38163M 5483.340 5483 340 14731 310 14731.310 14823 000 EOU Freq Hole Size Casing Diameter (ft) (in) (in) Survey Tool Type Borehole/Survey AG Sfis 13.500 10.750 SLB_NSG*SSHOT-Depth Only 2E-04PB9/2E-04PB9 Final Ad Sh1s 73.500 70750 SLB_NSG+SSHOT 2E-04P81/2E-04PS1 Final Ad Stns 13.500 10.750 SLBMWD+GMAG 2E-04PBI /2E-04PB1 Final Ad Stns 9.875 7000 SLB_MWD+GMAG 2E-04PB7/2E-04P61 Final Ad Stns 6.500 4500 SLB MWD+GMAG 2E-04/2E-04Final Ad Stns 6.500 4500 SLB BLIND+TREND 2E-04/2E-04Final Drilling Office 2.7.1043.0 Kuparuk River Unit2\Kuparuk 2E Pad\2E-04\2E-04\2E-04 Final 3/31/2014 5:21 PM Page 2 of 2 ro-6 Ildh l erger ConocciiMillps 2E-04PB1 Final Survey Report (Def Survey) Report Date: March 27, 2014-03:31 PM Survey l DLS Computation: Minimum Curvature/ -.Moak, Client ConocoPhillips(Alaska) Inc.-Kup2 Vertical Section Azimuth: 205.000°(True North) Kuparuk2EPad/er 2 VerticalSection O.000Rable ft ® A CFieltl: Structure/Slot: Kupamk 2E Pad/2E-04 renceOrigin: ND Reference Datun: Rotary Table ■ IV Well: 2E-04 ND Reference Elevation: 132.520 R above Mean Sea Level H -�' v V G Borehole: 2E-04PB7 Seabed I Ground Elevation: 105.1 R above Mean Sea Level UWI I "I9: 10350556 / 50-029-23505-00-00 Magri Declination: 19,524- 9524°Survey SurveyName: Survey Data: 2E-D4PB1 Final January 24, 2014 Total Gravity Fieltl Sheri Gravity Model. 1001.9572mgn(9.80665 GARM Based) PR 0 2 2014 Tort /AHD / DDI / ERD Ratio: 132,592 ° / 3473 540 R / 5.]42 / 0.527 Total Magnetic Field Strength: 57605.129 nT Coordinate Reference System: NAD83 Alaska State Plane, Zone 04, US Feet Mag-bP Dip Angle: 80.861 ° Location Lal/Long: N W149°45'39.075S Date: January fit\ Location Grid N/EYI%: 59415'30.15356", N 5943973.000 RUS, E 1670003.470 ftU5 Magnation Magnefic Declination Model: 012074 BGGM 2013 CRS Grid Corvergence Angle: 0.2251° North Reference: True North ®� �/`u/ray Grid Scale Factor: 0.99990099 Grid Convergence Used: 0.0000 ° Version/Patch: 271043.0 Total Corr Mag North ->True North: 195239, Local Coord Referenced To: Well Head Comments MD Incl Azim True TVDSS ND VSEC AHD Closure NS EW DLS Nor�Mng Easting Latitude Longdutle T IRI 0.00 f°I 000 M 0110 Ifll 132.52 Iftl 0.00 Iftl 0.00 !flu 0.00 IRI 0.00 IRI 000 Ifll 0.00 1 /100R1 N/A fftUSl fRUSI I 1 I 1 Grouts Level 2742 10800 0.00 0.06 0.00 -105.10 27.42 0.00 :DO 0.00 0.00 0.00 0.0D 594397300 5943973.00 1670003.47 1670003.47 70.25837600 -149.76085428 70.25837600 -149.78085428 185.00 0.23 36.51 84.01 -24.52 708.00 -0.04 004 0.04 0.03 003 0.07 594397303 1670003.49 702583]609 -149.76085407 27/.00 0.24 9928 52.48 144.48 185.00 -0.18 0.23 0.22 0.08 0.20 0.25 5943973.08 1670003.87 70.25837622 -7 43.76085284 ..00 0.81 250.29 235.48 277.00 368.00 -0.31 060 056 007 0.58 0.07 59439]307 767000405 70.25837619 -749.76084962 462.00 1.81 254.70 32945 009 7.18 0.24 -0.18 0.78 1.13 5943972.82 1670003.63 70.25837551 -149.76085298 555.00 2.60 261.79 422.38 461.97 554.90 1.52 333 2.06 -0.79 -1.90 107 594397220 167000158 70.2583]383 -149.76086962 64900 3.29 26289 51826 648.76 3.63 6.90 _ 5.60 -1.48 5.40 0.90 5943971.50 1669990.07 70.25837195 -149.76089794 742.00 4.29 28782 609,05 6.23 11 ]3 1041 -2.12 -10.19 0.74 5943970.84 1669993.29 70.2583]020 -149.76093663 76837 4.26 26870 635.35 741.57 9.24 17.87 16.52 -258 -16.31 1.13 594397035 7689987.17 70.25836894 -749.76098612 86102 5.00 270.12 727.70 767.87 10.12 19.04 1847 -264 -18.28 0.27 59439]0 29 166998520 70.25836878 -749.761 00200 952.98 fi.03 267.11 819.23 860.22 73.34 2].32 25.90 -2.71 -25.76 0.81 5943970.19 186997773 70.25836859 -749.76106244 1045.63 8.48 262.05 911.73 95175 17.29 36.15 34.71 -2.95 -34.59 1.16 5943969.92 1669968.90 70.25836794 -149.76113382 113837 982 261.31 1002.69 1043.85 23.28 47.85 46,40 4.14 -06.22 2.73 5943968.68 7689957,28 70.25836469 -749.76122779: 1231 A9 12.83 259.70 113521 31.39 62.59 61.13 -628 -60.81 1.45 594396848 166994269 70.25835884 -149.76134571 1323.55 14.43 25891 1093.69 1226.21 41.74 80.82 79.32 9.32 -78.77 3.26 5943963.37 1869924.74 70.25835054 -149.76749083'. 7528 255.48 1183.45 1272.92 1315.97 54.44 10258 10705 -13.36 -100.76 7.74 5943959.24 166990337 7025833948 -1=.76766376 1416.11 7508.96 15.96 254.26 136234 1405.44 69.00 126.30 124.89 -18.64 -123.28 1.32 5943953.88 166988027 70.25832506 -143.76185066 1601.36 15.89 250.03 1451.24 1494.85 85.11 15130 149.55 -25.17 -14741 0.81 594394725 1669856.17 70.25830722 -143.76204568 1693.55 1fi.64 243.99 7539.79 1583.76 102.23 176.49 174.51 -32.89 -171.39 1.28 5943939.45 1669832.23 70.25828615 -149.76223941 17177.15 78.73 233.93 1628,98 1672.31 121.31 202.13 19964 42.93 -19497 209 594392931 166980869 70.25825870 -149.]6242999 187758 20.18 229]6 171425 1781.50 149.80 230.50 226.62 57.66 -279.17 3.95 5943914.48 7689784.55 70.25827845 -149.76262557 1972.34 26.22 22302 1807.32 1846.7! 171]6 26061 25457 -76.29 -24281 2.22 594389577 166976099 70.25816756 -149.76287865 2064.63 29.71 221.85 1933.84 206.54 29788 268.31 -102.18 -269.60 6.95 5943869.77 1669734.30 70.25809682 -149.7003315 2157.53 30.38 219.72 1882.82 1%.24 201534 247.83 341.15 327.50 -134.13 -298.78 594383771 166970525 70.25800953 -149.76326894 2247.55 3509 216.01 2038.95 2095.76 292.59 38768 370.16 -169.35 -329.15 1 7.38 5943802.38 7669675.02 70.25797331 -149.76351440''. 2342.42 37.42 214.14 2115,45 217147 2247.97 3=.03 39527 436.32 492.41 41475 46623 -207.81 -253.74 -35893 -391.14 5.fi8 2.72 5943763.80 5943717.75 1669645.40 7689613.37 70.25780821 -149.76375505 70.25768275 -749.76401537 2435.19 40.13 212.75 2187.7] 232029 452 ]3 55050 519.98 -302.22 423.14 3.07 5943669.15 1669581.56 70.25755029 -149.76427395 2527.56 2619.23 40.78 41.]1 210.33 225806 2390.58 512.27 61043 575.65 -353.30 -454.48 7.84 5943617.96 1669550.43 70.25741074 -149.76452720 2]12.35 47 B4 207.23 2326.99 2459.51 572.56 670.86 631.56 -406.26 -483.55 245 5943564.08 166952156 7025726604 -149.76476215 2804.38 47.20 20699 205.24 2396.44 2528.96 63455 732.90 689.15 -461.48 511.82 0.22 5943509.56 1669493.51 70.25711517 -149.76499059''.. 2898.39 48.02 205.84 2462.03 2525.41 259455 699.04 797.40 74939 -519.42 5=17 5.97 5943451.52 1669465.40 70.25695688 -1076521965 2991.00 43.70 20551 2588.15 2657.93 768.47 666.83 874.75 -58206 570.11 0.99 5943388.76 1669435.71 70.25678572 -149.76546155`.: 3082.87 47.22 205.95 2650.85 2720.67 2783.37 83659 934.96 879.54 -643.46 -599.63 1.43 594332725 166943644 7025661797 -149.76570006 3176.58 47.55 206.32 2714.30 903.73 1002.10 943.88 -703.95 -628.78 0.67 5943266.86 166937753 70.25645272 -143.76593558:3 3269.24 47.60 204.57 277687 284682 97288 1071.06 1010.46 -765.86 -659.16 0.46 5943204.63 166934739 ]0.25628356 -149.76618104 336237 47.50 20383 2839.67 2909.33 1041.07 1139.46 1076.59 -827.62 -688.54 1.43 5943142.77 166937826 70.25611483-1497fi641845 345433 3547.63 47.52 205.02 2901.70 2972.19 .3034.30 1109.78 1177.58 1208.18 1275.99 1142.93 7208.73 -89030 -952.04 -71671 -744.]5 0.60 0.95 59430]999 5943018.14 166929034 1669262.54 70.25594358 -1 Q,76664604 70.25577490 -149.76687256': 3638.87 47.66 20502 2964.]1 309].23 1246.47 1344.87 12]5.94 -101446 -7]3.88 0.15 594295561 1669233.66 70.25560435 -149.76710796 3732.23 48.02 204.92 302595 3158.47 1314.10 1412.51 1392.08 -7075.]7 -80243 0.40 5942894.19 1889205.35 7025543584 -143.76733863.'1 3755.85 47.86 205.68 3088.49 322101 1383.41 1481.82 141009 -7138.44 -632.05 0.63 594283142 1669175.98 70.25526563 -149.76757794 10-3/4'Surlace 48.04 205.59 3104.31. 3236.83 1400.95 1499.36 1427.34 -1754.25 4739.64 0.81 5942875.55 768978845 70.25522242 -143.76763924' Casing 3816.30 48.64 205.26 3144.49 327701 1446.11 1544.52 1471.75 -1195.04 -859.03 1.07 5942774.72 1669149.23 70.25511098 449.76779586 3853.% 3908.96 0,01 205.05 316929 3301.87 1474.46 15] 287 1499.62 -1220.70 -071.08 1.07 5942749.02 1669137.28 70.25504388 -143.76789319' 4000.85 48.61 205.60 320551 3338.03 1515.85 1614.26 154038 -1258.11 -88878 105 5942711.54 1669119.73 70.25493866 -143.76803621 4094.79 4B.= 47.86 206.92 32fi8.39 3398.81 1584.65 1883.08 7608.39 -1379.83 -919.23 1.10 5942649.70 1669089.52 70.25477003 -743.76828721 4187.26 47.78 207.34 3329.09 3461.61 1654.56 1753.03 167].74 -138208 -951.13 0.66 594255733 166905787 70.25459993 -74976853990 4280.26 206.46 3391.78 3523.70 1723.04 1621.56 1]45.68 -1443.19 -982.73 0,71 5942526.11 1869027,11 70.25443297 -143.76679035% 4373.12 47.87 47.73 206.59 207.26 343.62 3586.14 1]91.94 1690.48 7814.W -1504.86 -101291 0.14 594246432 1668996.58 70.25426448 -149.76903900 4465.14 47.60 208.15 3516.00 357797 3648.52 1880.69 1959.27 1682.29 -7566.19 -7044.06 0.56 5942432.88 186896567 70.25409690-149.769290fi5: 4556.94 47,83 209.29 363174 3710.49 192864 202729 1949.96 -1626.42 -1075.69 0.73 5942342.53 1660934.29 ]0.25393236 -149.76954609 434938 47.64 20973 3772.26 1996.41 2095.21 2017.64 -7685.97 -1108.32 0.95 5942282.86 1868901.89 70.25376963 -149.76980972 4742.11 47,77 3]0191 3834.43 2064.61 2163.62 2085.91 -1]45.51 -114202 041 5942223.19 1668868.43 70.25360697 -14.77008192 4834.39 4775 209.72 21004 3764.31 3896.83 2132.96 2232.21 2154.38 -1805.07 -1176.03 0.14 5942163.50 1668834.66 70.344422 -149.77035665 4926.71 4769 209.68 3826.35 388846 3958.87 2201.03 2WO53 2222.59 -1864.31 -1210.06 026 5942104.14 166880086 70,2255328237 -149.77063158 5020.71 47.58 208.49 395739 4320.96 2269.09 2368.83 2290.80 -7923.55 -1244.07 0.30 594204477 1868767.09 70.25312052 -149.77090625 5113.35 47.76 206.94 437418 =8391 2337.92 2437.84 235966 -1983.85 -1277.61 0.95 5941984.34 1668733.79 ]0.25295575 -1077117725 5206.14 48.09 206.06 40]6.36 4146.70 4208.88 2=8.77 2506.77 242832 -2044.87 -7309.67 1.24 5841923.21 1668701.98 70.25278902 A49,77 43616 5298.54 48,19 205.73 4138.02 4270.54 2475.62 2544,43 2575.64 2496.81 -2106.51 -13=40 0.79 5941861.45 166867149 70.25262061 -749.77168437 5390.24 4833 20659 4199.0] =3159 2644.46 2565.79 -2188.42 -1370.45 0.29 5941799.43 1668647.68 7025245146 -149.77192710 5483.34 48.28 205.93 4261.00 2612.84 2712.88 2633.23 -2229.83 -7400.62 0.72 5941737.91 1668611.76 7025228366 -1=.77217075 5576.88 566920 48.34 205.98 4323.21 4393.52 445573 2682.34 2752.18 2782.= 2852.25 270239 2777.86 -229 AT -2354.98 A431.38 -1461.95 0.53 0.08 5947875.45 5941612.53 1668581.25 1666550.93 70.25211333 -149.77241916 70.25194172 -143.7/266807 576091 48.28 46.43 206.31 4384.62 4517.14 2821.71 2921.19 28=.47 -2418.87 -1492.33 0.27 5941550.53 1668520.80 70.25177283 -149.77291141 5854.46 42.72 20651 4446.74 4579.26 2888.55 2988.65 2907.65 -247728 -152233 202 594149001 1668491.04 7025160755 -1=.]7315371 5946.35 30.95 207.82 20933 4513.37 4645.89 2954.14 3054.29 2973.10 -2535.70 -1552.28 4.09 594143148 1668461.32 7025144795 -149.77339557 4339.80 34.66 458288 4715.= 3014.10 3114.36 303309 -2588.43 -1580.98 4.24 5941378.61 166843283 70.25130377 -149.7]362743 613230 30.57 208.87 4657.69 4790.21 3088.93 3170.34 3089.02 -2637.38 -1608.19 4.60 5941329.59 166843582 70.25117012 -149.77394713 6225.73 26.18 20632 4735.59 4868.11 3719.71 3220.18 313875 -268153 -163131 4.65 594128535 166838288 70.25104948 -149.77403380 631771 22.82 201.26 4817.79 4950.31 3164.06 3264.54 3182.75 -2722.06 -76033 5.35 5941244.76 166636507 70.25093875 -149.7/417938 6410.27 18.94 19491 4981.49 5034.01 3201.88 330265 3219.88 -275822 -166129 4.64 5941208.56 1668353.20 70.25083995 -149.77427592 6502.53 15.54 191.35 191.00 498796 5120.48 3234.17 3335.62 3251.29 -2790.30 -1668.87 4.41 5947176.44 7868345.74 70.25075229 -149.77433708 659 AS 13.99 18739 507806 5166.62 520556 3260.72 3362.96 327705 -2817.12 -1674.17 3.69 59411 tS.61 1668340.54 70.25067901 -14.77437990 668821 13.54 17/.73 5256.02 5289.14 3283.68 3386.82 3299.26 -2043.87 -1678.02 1.92 5941126.05 1668336.79 70.25061469 -149.77441096 6780.17 77.15 170.08 5345.85 5386.54 5478.37 3303.86 3320.72 34086] 3428.W 3318.56 3334.43 -2862= -288198 -1679.03 -1677.07 254 3.14 594110425 5941084.74 166833587 1668337.90 70.25055513 -1=.77441904 70.25050181 68]3.32 8.96 16692 543756 55]0.08 3333.82 3444.56 3346.61 -2897.92 -1673.88 2.42 5941068.82 1668341.16 -149.774=310 70250=826 -149.77437735 6965.24 7058.39 733 183.62 552855 5561.07 334386 3457.58 3355.90 -2910.52 -1670.60 1.84 5941056.23 1668344.48 70.25042384 -149.77435088 7157.77 4.47 055 16621 14154 5621.20 5714.47 575372 3351.15 3=7.15 3362.64 -291975 -166806 3.08 594104701 1666347.06 7D.25039863 -14.7]433033 7245.43 0.34 308.36 5808.16 5846.99 5940.68 3354.18 3471.21 3365.45 -2923.64 -1668.97 4.26 5941043.13 166834822 70.25038801 -149.77=2106 7336.97 0.25 182.01 5899.67 3354.32 3471.67 3365.58 -292382 -1666.85 0.94 594104295 166834828 70.25038752 -149.7]432056 ]363.95 0.21 188.18 5926.65 6032.79 3354.44 347193 3365.71 -2923.85 -7867.07 0.58 5941042.92 1668346.06 70.25038744 -149.77432234 7=0.64 7993.88 0.05 204.05 596334 6059.17 4395.86 3354.54 3354.62 3472.03 3472.12 3365.81 3365.89 -2923.96 -292404 -166].08 -1667.10 0.17 0.44 5941042.81 5941042.73 1668348.06 1668348.04 7025038714 -1=.77432241 70.25038692 -149.77432254 7586.14 034 127.03 605658 618910 335472 3472.41 3365.96 -292424 -1666.89 0.36 594104253 166834825 70.25038637 -749.7/432089 0.19 40.85 6148.84 6281,36 3354.63 3472.77 3365.85 -2924.29 -1666.57 0.41 5941 D42.43 1668348.58 70.25038623 -149.77431632 767].86 0.18 85.90 6240.56 6373.08 3354.42 3473.05 3365.62 -2924.16 -1666.33 0.15 5941042.61 166834881 7025038657 -149.77431635 7770.78 7839.14 0.23 0.72 335.35 6333.48 6466.00 3354.22 3473.29 3365.43 -292398 -1666.28 0.36 594104279 166834SB7 70.25038707 -149.77431580 Project to Bit 7900.00 142.12 6431.84 6534.36 3354.77 3473.41 3365.38 -2923.92 -1666.28 051 594104286 1668348.86 7025038725 -149.]]431597 0.12 142.72 6462.70 6595.22 3354.23 3473.54 336543 -2924.02 -1666.20 0.00 5941042.76 16683=.94 7025030698 -149.77431528 Survey Type: Oef Survey Survey Error Motlel: ISCWSA Rev 0'- 3D 95.000% Confidence 2.7955 sigma Survey Program: Drilling Office 2.7.1043.0 Kuparuk River Unit2\Kuparuk 2E Pad\2E-04\2E-04PB1\2E-04PB1 Final 3/31/2014 2:24 PM Page 1 of 2 Drilling Office 2.7.1043.0 Kuparuk River Unit2\Kuparuk 2E Pad\2E-04\2E-04PB1\2E-04PB1 Final 3/31/2014 2:24 PM Page 2 of 2 • 0 Comments MD Irrel IRI I°I Ad. Tnle TVDSS TVD VSEC AHD Closure NS EW DLS NorRdng EasHrg Latitude LongRYde 1% lilt /ill IR1 1R1 IRI IRI fRl f°/100 /flU51 IRU31 Description Pari MD From MD To EOU Freq Hole Sae Casing Diameter (ft) (it) (m) (in) Stw.y Tool Type Borehole / Survey 1 0,000 33.520 All Sins 13.500 70.750 SLS HOT -Depth Only 2E-0 Bi /2E-04 iFinal i 33.520 74?000 Ad Skis 13.500 10.750 _NSG♦S SLB NSG-SSHOT 2E-04PB1 /2E4WP81 Final 1 742.000 3816.300 Ad Stns 13.500 10.750 SLB MWD-GMAG 2E-04PS112E-04PS1 Finel 1 3816.300 7638.140 Ad Sina 9.875 7.000 SLB MWD�GMAG 2E-04PB1/2E-04PB1 Final 1 7830.140 7900A00 Ad Sins 9875 7.000 SLB_SLIND+TREND 2E-04PBI /2E-04PBI Final Drilling Office 2.7.1043.0 Kuparuk River Unit2\Kuparuk 2E Pad\2E-04\2E-04PB1\2E-04PB1 Final 3/31/2014 2:24 PM Page 2 of 2 n+c ' MIPS TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, AT03-0340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave, Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 2E-04PB1 DATE: 03/31/2014 Kuparuk River Unit, Alaska 2E-04PB 1 11 2t3- tre'K 2--Aa91 RECEIVED APR 0 2 2014 AOGCC DATA LOGGED AA / 74/2014 M K BENDER Canrig Final well report mudlogging data; 3/4/2014; table of contents, mudlogging equipment; general well details,geologic data, pressure/formation strength, drilling data, show reports, daily reports and formation logs; color log presentations; Formation log MD/TVD Gas ratio MD/TVD Combo log MD/TVD Drilling dynamics MD/TVD SCD contains daily reports, DML data, final well report, LAS files, Log PDF files, remarks, TIFF files Sign, scan and return electronically to Sandra.D.Lemke(--COP.com CC: 2E-04PB1 transmittal folder, production well files, eSearch Receipt:M8Date: GIS -Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 ConocoPhimps Alaska, Inc. RECEIVED APR 0 2 2014 AOGCC FINAL WELL REPORT MUDLOGGING DATA 2E-04 PB1 Provided by: CANRIG DRILL- TECHNOLOGY LTo. Approved by: Laird Little Compiled by: Harry E. Bleys Eric Andrews Distribution: 3/4/2014 T.D. Date: 01/21/2014 2A V9 \ • • ConocoPhimps Alaska, Inc. FINAL WELL REPORT MUDLOGGING DATA 2E-04 PB1 Provided by: Approved by: Laird Little Compiled by: Harry E. Bleys Eric Andrews 0 Distribution: 3/4/2014 T.D. Date: 01/21/2014 0 0 Co['toa;P'iiiilp5 Ajiv,a Ir c 2E — 04 P1131 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ............ 1.1 Equipment Summary ............................... 1.2 Crew ...................................................... 2 GENERAL WELL DETAILS ............................ 2.1 Well Summary ........................................ 2.2 Hole Data ............................................... 2.3 Daily Activity Summary ............................ 3 GEOLOGICAL DATA ..................................... 3.1 Lithostratigraphy..................................... 3.2 Mudlog Summary .................................... 3.3 Connection Gases ................................... 3.4 Trip (Wiper) Gases .................................. 3.5 Sampling Program / Sample Dispatch....... 4 PRESSURE / FORMATION STRENGTH DATA 4.1 Pore pressure evaluation .......................... 5 DRILLING DATA ............................................ 5.1 Survey Data ............................................ 5.2 Bit Record .............................................. 5.3 Mud Record ............................................ 5.4 Drilling Progress Chart ............................. 6 SHOW REPORTS ........................................ 7 DAILY REPORTS ......................................... Enclosures: 2"/100' Formation Log (MD/TVD) 2"/100' Drilling Dynamics Log (MD/TVD) 2'7100' LWD / (Lithology Log) MD/TVD) 2"/100' Gas Ratio Log (MD/TVD) Final Data CD ...............2 ...............2 ...............2 ...............3 ...............3 ...............3 ...............4 ..............6 ..............6 ............7 ............9 ...............9 .............10 .............11 .............11 .............12 .............12 .............15 .............16 .............17 .............18 .............19 1 • • of ConocoPhillips .i oj,z; 2E — 04 PB1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Downtime Comments Das y QGM Agitator (Mounted in possum Days Ditch gas belly) Flame ionization total gas & 0 chromatography. Harry E. Ble s 14 Effective Circulating Density From MI SWACO 43' to TD 0 Howard Lamp ECD Eric Andrews 2 21 Hook Load / Weight on bit Totco WITS Feed 0 Derived from Strokes/Minute and 0 Mud Flow In Pump Output Mud Flow Out Totco WITS Feed 0 Mudlogging unit computer Intel(R)Core(TM)2 Duo CPU 0 system In -unit data collection/distribution 0 Mudlo in unit DAC box gg g center Pit Volumes, Pit Gain/Loss Totco WITS Feed 0 Pump Pressure Totco WITS Feed 0 Pump stroke counters Totco WITS Feed 0 Totco Well Monitoring Totco computer networked in 0 Components Mudlogging Unit Rate of penetration Totco WITS Feed 0 RPM Totco WITS Feed 0 Torque Totco WITS Feed 0 1.2 Crew Unit Type Steel Arctic Unit Niimhar MI nin Mudloggers Years •1 Days *z Sample Years Das y Technician Days Catchers Harry E. Ble s 14 25 Steve Franzen 7 14 Howard Lamp 5 Eric Andrews 2 21 Dean g Kekaualua 14 Years experience as Mudlogger 2 Days at wellsite between spud and total depth of well 2 C� • ConocoPhillips Aiic*;=a ir,';. 2E — 04 PB1 2 GENERAL WELL DETAILS 2.1 Well Summary Well: 2E-04 PB1 API Index #: 50-029-2305-70-00 Field: Kuparuk River Field Surface Co -Ordinates: 580'FSL, 160'FWL, Sec 36, T11 N, R9E, UM Borough: North Slope Primary Target Depth: HRZ Sand: 7038' MD / 5721'TVD KUPARUK C: 7428' MD / 6111' TVD State: Alaska TD Depth: 7900' MD / 6595' TVD Rig Name / Type: Doyon 141, Arctic Triple License: 213-168 Primary Target: HRZ C37 Sands Ground Elevation: 105.90' AMSL Spud Date: 1/05/2014 RT Elevation: 133.23' AMSL Completion Date: 01/23/2014 Secondary Target: Depth: A3 SAND Completion Status: Plugged Back TD Date: 01/21/2014 PILOT HOLE Classification: Producer Days Testing: I NONE TD Formation: Miluveach Days Drilling: 1 15 2.2 Hole Data Hole Maximum Depth TD Mud Dev. Casing Shoe Depth LOT MD TVDSS MD TVDSS Section Formation Weight ai (nc) Coring Liner (ppg) ft (ppg) ft 13.75" 3814' -3142 C-80 9.6 49.01 none 10.75' 3814 9.875" 7425' -7292 Base 11.0 27.87 none 3710 3190 13.6 Ku aruk 8.5" 7515' -7382 A6 11.0 0.16 coring 9.875" 7900' -7767 MILIVEACH 10.5 0.12 none Additional Comments The grass roots drill project of well 2E-04 in Kuparuk River Field was spud at 01/05/2014. An ice plug was tagged at 43', and drilling commenced down hole with a 13.5" bit to 222 Ft, where the mud system was circulated to clean the hole. BHA #1 was pulled out of the hole and laid down. BHA #2 tripped back in the hole with the original bit, RR Bit #1. The drilling resumed through the T-3 Sand and the base of the Perma-Frost. The Intermediate Casing Point was reached at 3827' within the Ugnu C. No samples were taken in this upper pilot -hole section. Samples were taken after the intermediate casing point. The HRZ sands were of particular interest in the lower pilot -hole section. Samples from Canrig consisted of one wet and one dry taken in 25 ft intervals to the bottom of the hole at 7425 Ft MD in the HRZ Formation. Casing was run and drilled out into the new formation in the HRZ. Later a 90 Ft. section was cored using a 8.5" bit. The core barrel drilled a core from the Kpbaruk C, the Kuparuk B, The Kuparuk A, and the Miluveach Formtion. Oil was found oozing out of fractures in the chips taken from the now exposed core. Success in this case comes with the realization that to produce this well fracturing the overall formation must be a high priority. Re -running BHA# 3 with the 9.875" bit drilling resumed from 7425 to 7499 Ft. The dominate formations were composed of siltstone, mudstone (shale) and traces of a very fine unconsolidated quartz sands down to the Miluveach formation. k r., Como Phillips 2E — 04 PB1 . 2.3 Daily Activity Summary 1/5/2014: Finish Rigging up Canrig Logging Unit. The logging crew will be waiting on Totco, rig -phone, the regular phone and network lines. The rig phone lines were installed and Phone Line installed, and Totco WITS feed rigged -up. The rig continues to nipple up and get ready to test BOP's. 1/6/2014: Drilled from 107' to 222', Circulated, pulled out of hole, and laid down BHA#1. Made up BHA#2, picked up, and ran in hole to 222 Ft., and continued drilling from 222 Ft. to 1301 Ft. 1/7/2014: Drilling continues from 1301 Ft. to 1858 Ft. The hole istorquing up, so a decision is made to bring up the mud viscosity. Drilling continues to 2228 Ft., and than to 2970 Ft. 1/8/2014: Drilling from 2970 Ft. to 3242 FT., reaming back each stand. Gas was recorded at 300 units. Drilling continues to 3525 Ft., than on to 3827 Ft. The crew held a pre -job safety meeting about plans to pull out of the hole. It was decided to slow the pump rate between 3530 Ft. and 1027 Ft. as pipe pulled up out of hole through the permafrost. 1/9/2014: Held a pre job safety meeting concerning back reaming out of the hole from 1027 Ft. to 749 Ft. Blew down top drive. Began tripping back down hole from 749 Ft. Ran in the hole to 3807 Ft., and washed and reamed to 3827 Ft. Circulated and conditioned mud. The mud weight was coming back too high. A decision was made to continue to circulate with the pumps turned down. The crew blew down the top -drive, and monitored the well. It was found the well was static. Pulled out of the hole from 3520 Ft. to 749 Ft., and racked back five stands. The crew laid down BHA #2 and held a pre -job safety meeting, and after continued to lay down the BHA. The rig floor was cleaned and the crew held a safety stand down meeting, than held a pre -job safety meeting concerning rigging up the casing crew. The mud was staged up and circulated after the casing tools were rigged up. 1/10/2014: Ran in hole with casing crew to 3783 Ft. Made up landing joint and hanger and landed the casing at 3814 Ft., and rigged up cement head to circulate through cement lines. Held pre -job safety meeting and began batched up cement per Schlumberger rep. Pumped cement spacers and shut down drop bottom plug and chased with 11.0 Ib ALC lead cement. Continued to pump cement and dropped top plug kick out with fresh water. Pumped plug and bleed pressure off and checked that the floats were good. Flushed stacks and held a pre -job safety meeting to rig down cement equipment. Laid down landing joint, and drained stack and laid down riser in pipe shed. Nippled down diverter and rigged up casing spool, than tested metal seals. Finally rigged down valves on conductor and made up tubing spool. 1/11/2014: Made up well head diverter, Tested BOP's. Began running in hole at time of midnight report 1/12/2014: Rigged up and tested 10.75" casing. Ran in hole from 3603' to 3695'; washed and reamed out shoe track and rat hole to 3827'. Drilled out from 3827' to 3847', displaced old mud, circulated hole clean, and then commenced drilling from 3847' to 5097' at time of midnight report. 1/13/2014: Pulled out of hole from 5072' to 3788', Changed out brake bands. Began running in hole from 3788' to 4992', washed and reamed from 4992' to 5082' and proceeded to drill to 6293' at time of midnight report. 1/14/2014: Continued drilling from 6293' to 7425', circulated and began pulling out of hole. 1/15/2014: Continued circulating hole clean and began pulling out of hole making sure to back ream over any tight spots. Pulled out of the hole and laid down tools. 1/16/2014: Held pre -job safety meeting than organized and laid down BHA #3. Checked the seals on power - drive and flushed out with water. Cleaned and cleared rig floor, and held pre -job safety meeting concerning Coma fillips 2E — 04 PB1 . making up and picking up core barrels for coring job. Crew slid core barrels up beaver slide and made up core barrels on drill floor. Crew continued to make up collars, heavy weight pipe and jars for BHA #3. Driller ran in hole from 756 Ft. to 7239 Ft. filling pipe every twenty stands. Washed and reamed from 7239 Ft to 7425 Ft. to clean hole. Circulated and conditioned mud circulating bottoms up. 1/17/2014: Cored from 7425' to 7515'. 1/18/2014: Continued coring from 7510' to 7515', pulled off bottom, circulated and conditioned mud through phase 3 weather. 1/19/2014: Pulled out of hole from 7515' 1/20/2014: Laid down core; coring tools, made up BHA #3 and re -run 9.875" bit. Picked up BHA and began running in hole to bottom. 1/21/2014: Ran in hole; circulated mud, and displaced mud. Began opening up cored section from 7425' to 7515' and continued drilling into new formation from 7515' to 7519' at time of midnight report. 1/22/2014: Canrig rigged down with the ending of their responsibilities at the completion of the Pilot hole. CJ is 5 Nw- Corvoco hillips 2E — 04 PB1 0 3 GEOLOGICAL DATA 3.1 Lithostratigraphy LWD tops refer to provisional picks by the operations geologist. FORMATION PROGNOSED MD TVD ft ft LWD PICK MD TVD ft ft KB 0 0 0 0 To T-3 Sand 978 976 970 969 K-15 Marker 1213 1209 1212 1208 Base Permafrost 1497 1486 1499 1486 Top U nu (U nu C) 2061 2010 2057 2011 Top W Salk W Salk D) 2961 2695 2936 2685 Top W Salk Al 3501 3056 3458 3038 Base W Salk 3743 3217 3699 3199 Surface Casing 3856 3293 3826 3284 C-80 4467 3701 4396 3665 C-50 6350 5051 6325 5041 C-40 6468 5161 6450 5161 C-37 (Top Arete 6561 5251 6552 5258 AML Mid (Top Iceberg) 6786 5471 6771 5471 K-3 Marker (Top Moraine) 6938 5621 6899 5596 Top HRZ K-2 Marker 7038 5721 6999 5696 Upper Kalubik Base HRZ 7249 5931 7219 5913 Lower Kalubik (K-1 Marker) 7339 6021 7302 5998 C (To C4) 7428 6111 7393 6090 B2 7434 6116 7405 6101 B1 7436 6118 7411 6107 CORE POINT 7461 6143 7425 6120 A6 7472 6155 7424 6119 A5 7489 6170 7440 6135 A4 7517 6200 7470 6165 Miluveach 7582 6264 7540 6236 TD WP08(Miluveach) 7851 6534 7423 6119 • ConocoPhillips Alaska, Inc. 2E — 04 PB1 0 3.2 Mudlog Summary Casing Point to Top HRZ 3814' to 6999' MD 3681' to 6866' TVDSS Drill Rate (ft/hr) I otal Gas units Maximum Minimum Average Maximum Minimum Avera e 477 2.9 127.7 1348 0 105.1 This interval includes siltstone, silty shale, shale, sand, and sandstone, to the top of the HRZ @ 6999 Ft. There was one notable show #1 of 1091 units of gas at 4550 Ft to 4575 Ft. with sample fluorescence of 75% bright yellow and a instant cut fluorescence of a milky bright white, and a residual ring of yellow. SAND, SANDSTONE: A gray to dark medium gray to dark gray color; loose unconsolidated sands were disaggraged very fine upper to fine lower grain sized, but well sorted and subrounded to round. The clasts were a moderate to high sphericity. The textural maturity moderate to well aged. Evidence of black streaks in cut sandstone clasts were ascertained by the slick cut face. The sandstone graded towards the siltstone and was interbedded with sandstone and loose disaggraged sands. A trace of golden yellow sample fluorescence in less than 1 %, was found. The overall basal structure of sand/sandstone was very thick with the dominant mineral quartz in a translucent clear to a opaque grayish white. The closer to the HRZ pyrite, black carbonaceous material, limestone, and white marl appeared. SILTSTONE: A medium gray to dark gray with slight green hues; crumbly to very firm tough tenacity; irregular fracture; argillaceous matrix cement; gritty texture; dull earthy luster; interbedded with stringers of disaggraged sands, and sandstone; thick basal structure. • SHALE AND SILTY/SHALES were dark gray to grayish black. The overall color changed more and more to a grayish dark brown and graded to towards carbonaceous shale as the HRZ approached. Shales and silty shales were crumbly to firm tough in tenacity; planar to splintery in fracture with overall flat rectangular cuttings. Shales were smooth textured and graded to a slightly grittiness with the intrusion of silt stringers. The overall basal structure was thinly bedded. The show #1 SAND/SANDSTONE was medium dark gray to very dark gray color. It was moderately hard thus indurated and than in other parts weakly cemented and friable. Grains ranged from lower very fine to lower fine grain size. The sand/sandstone was well sorted and had moderate to high sphericity and was subrounded to round. The show sand/sandstone had a moderate petroleum odor with a 75% yellow sample fluorescence. It had a instant cut fluorescence of a bright white color. The cut fluorescence gains a little green color with time and left a yellow residual ring upon evaporating. Peaks Depth ft Total Gas units C1 PPM C2 PPM C3 PPM C41 PIPM C4N PPM C51 PPM C5N PIPM 4549 1229 169959 11396 4812 1479 2131 1029 540 4550 1297 179051 12096 5098 1567 2266 1092 572 4551 1334 183981 12521 5268 1620 2350 1130 591 4552 1349 115763 7937 3333 1025 1492 716 374 4523 1347 117536 7998 3385 1025 1493 723 378 4554 1333 116430 7862 3355 1000 1458 713 372 4555 1317 115232 7722 3322 975 1422 701 367 4556 1298 113724 7562 3279 947 1382 689 360 7 • • ConocoPhillips Alaska, Inc. 2E — 04 PB1 HRZ to Coring Point 6999' / 7425' MD ( -6866/ -7292 TVDSS ) Drill Rate ft/hr Total Gas units Maximum Minimum Average Maximum Minimum Average 294 2.3 122.5 1025 18 282 The HRZ includes carbonaceous shales and some interbedded sands siltstone and shale. The shale is a typical HRZ, variably organic claystone base seen through out the other interbedded minerals. With tightly packed black carbonaceous laminae throughout with traces pyrites, associated with carbon matter. Thin laminations of black carbonaceous material in sandstone, siltstone, shales, carbonaceous shale that grades towards a very dark brown associated with the HRZ. Peaks Depth ft Total Gas units C1 PPM C2 PPM C3 C41 PIPM PPM C4N PPM C51 PPM C5N PPM 7051 973 121651 736 541 157 1234 457 220 7052 1026 129191 780 574 166 1310 482 233 7059 934 117772 703 517 150 1192 423 205 7060 972 122537 731 537 1 156 1239 438 1 212 7061 965 121658 724 533 155 1230 432 1210 CORING POINT TO MILUVEACH 7425' to 7540' MD (-7292' to -7407 TVDSS) Drill Rate ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 94 5 47 137 1 18 56 This is primarily a siltstone shale section with dark brown to dark brownish gray to brown black mudstones grading towards Shale. Traces found of calcite fracture fill. The mudstone in part, is slightly to moderately calcareous. Intermittent interbedded thin laminations of siltstone and sandstone, and mudstone with fracture fill noted between bounded laminae. Sands are very fine lower to very fine upper on the grain size chart. Peaks Depth ft Total Gas C1 units PPM C2 PPM C3 PPM C41 P m C4N PPM C51 PIPM C5N PPM 7425 137 12381 436 310 88 484 125 7425 7426 109 9865 357 249 70 384 100 7426 7427 107 9683 359 247 68 375 98 7427 CANRIG CQrocoPhillips AJw;P,3.irf• 2E — 04 PB1 3.3 Connection Gases 1unit = 0.05% Methane Equivalent Depth Gas over BGG Depth Gas over BGG (feet) (units) (feet) (units) 3917 0 5772 32 4063 17 5818 30 4152 0 5912 25 4243 62 6008 0 4337 10 6097 4 4430 0 6188 22 4523 40 6282 16 4618 22 6378 40 4707 65 6468 35 4803 30 6563 13 4892 0 6652 52 4993 0 6747 1 5077 25 6837 7 5173 16 6932 9 5263 5 7033 141 5358 16 7117 0 5447 17 7207 117 5542 8 7303 51 5637 24 7393 106 0 3.4 Trip (Wiper) Gases 0 1unit = 0.05% Methane Eauivalent Depth Trip to Gas Downtime (feet) (feet) (units) hours 7423 0 191 12 hrs 7423 3596 398 12 hrs 7515 3688 44 12 hrs 7425 3588 320 24 hrs CANRIG W Conoa;Pf fillips At k:r 4rr;. 2E — 04 PB1 0 3.5 Sampling Program / Sample Dispatch Set Type / Purpose Frequency Interval Dispatched to Alaska Archive Core Facility Washed & dried Reference— 25' 7 Att.- Dan Przywojski A Samples 50' 742900 742' 5' — 7900 1300 West56t'Avenue, Unit 14 Anchorage, AK 99518 Alaska Archive Core Facility 25' ' — 7900 Att: Dan Przywojski B Wet In Reference Samples 50' 7425' — 7900 742 1300 West 56"' Avenue, Unit 14 Anchorage, AK 99518 Sample frequency was locally altered according to drill rate constraints and zones of interest. • • 4 PRESSURE / FORMATION STRENGTH DATA msilli Cts p 2E — 04 PB1 Connection gas occurred through most of the drilling, but peaks were consistently difficult to distinguish from background gases, indicating pore pressure remained close to balanced with mud weight. Connection gas encountered was consistently low and not easily found above background gas. This was due to the mud weight being close to formation pressure with pump pressure from start of the well while drilling with a 9.5 ppg mud; to the end of the Pilot hole.. The mud weight was not increased thus the background gases and connection gases were close together all the way to the HRZ top and to the coring point. The pore pressure is estimated to have varied from 9.4 to 9.6 from casing point to the HRZ, remaining close to the mud weight within the equivalent circulating density of the mud plus pump pressure. 4.1 Pore Pressure evaluation NOTE: Clyst = Claystone/Clay, Sd = Sand, Sitst = Siltstone, Sh = Shale, Sst = Sandstone, Ash = Ash Fall Tuff, RS= Carbonaceous, Shale Primary Secondary Interval Tops Pore Pressure EMW Trend MD TVD Min Max Trend Formation Lithology Lithology Indicators Interval (%) (%) ft ft Kick off Point Slst/SS 70% Sd/Sh 30% 3855 3303 9.4 9.6 Sli up BG,CG HRZ Slst/Sh 60% RS/Sd/SS 7415 6111 9.4 9.6 Sli up BG,CG,TG 30% Total Depth i 7900 1 6595 1 9.4 9.6 1 Flat BG,CG, TG NOTE: Clyst = Claystone/Clay, Sd = Sand, Sitst = Siltstone, Sh = Shale, Sst = Sandstone, Ash = Ash Fall Tuff, RS= Carbonaceous, Shale I� Congo Phillips wC 2E - 04 PB1 5 DRILLING DATA 5.1 Survey Data Measured Depth (ft) Incl. (0) Azim. (0) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (°/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 108.00 0.06 36.51 108.00 -0.05 0.05 0.03 0.06 185.00 0.23 84.01 185.00 -0.09 0.09 0.21 0.25 277.00 0.24 99.28 277.00 -0.08 0.08 0.59 0.07 368.00 0.81 250.29 368.00 0.17 -0.17 0.17 1.13 462.00 1.81 254.70 461.97 0.78 -0.78 -1.89 1.07 555.00 2.60 261.79 554.90 1.47 -1.47 -5.39 0.9 649.00 3.29 262.89 648.78 2.11 -2.11 -10.18 0.74 742.00 4.29 267.82 741.57 2.57 -2.57 -16.31 1.13 768.37 4.26 268.7 767.87 2.63 -2.63 -18.27 0.27 861.02 5.00 270.12 860.22 2.70 -2.70 -25.75 0.81 952.98 6.03 267.11 951.75 2.94 -2.94 -34.58 1.16 1045.63 8.48 262.05 1043.65 4.13 4.13 -46.21 2.73 1138.37 9.82 261.31 1135.21 6.27 -6.27 -60.80 1.45 1231.19 12.83 259.70 1226.21 9.31 -9.31 -78.77 3.26 1323.55 14.43 258.91 1315.97 13.35 -13.35 -100.15 1.74 1416.11 15.28 255.48 1405.44 18.63 -18.63 -123.28 1.32 1508.96 15.96 254.26 1494.86 25.16 -25.16 -147.41 0.81 1601.36 15.69 250.03 1583.76 32.87 -32.87 -171.38 1.28 1693.55 16.64 243.99 1672.31 42.92 -42.92 -194.96 2.09 1787.15 18.73 233.93 1761.50 57.65 -57.65 -219.16 3.95 1877.58 20.18 229.76 1846.77 76.28 -76.28 -242.8 2.22 1972.34 26.22 223.02 1933.84 102.17 -102.17 -269.59 6.95 2064.63 29.71 221.85 2015.34 134.12 -134.12 -298.771 3.83 2157.53 30.38 219.72 2095.76 169.34 -169.34 -329.14 1.36 2247.55 35.09 216.01 2171.47 207.80 -207.80 -358.92 5.68 2342.42 37.42 214.14 2247.97 253.73 -253.73 -391.13 2.72 2435.19 40.13 212.75 2320.29 302.21 -302.21 -423.13 3.07 2527.56 40.78 210.33 2390.58 353.28 -353.28 -454.47 1.84 2619.23 41.71 207.23 2459.51 406.25 -406.25 -483.55 2.45 2712.35 41.84 206.99 2528.96 461.47 -461.47 -511.82 0.22 2804.38 47.20 205.24 2594.55 519.41 -519.41 -540.16 5.97 2898.39 48.02 205.84 2657.93 582.05 -582.05 -570.10 0.99 2991.00 46.70 205.51 2720.67 643.45 -643.45 -599.62 1.45 3082.87 47.22 205.95 2783.37 703.94 -703.94 -628.77 0.67 3176.58 47.55 206.32 2846.82 765.85 -765.85 -659.15 0.46 3269.24 47.60 204.57 2909.33 827.61 -827.61 -688.53 1.40 3362.37 47.50 203.83 2972.19 890.28 -890.28 -716.70 0.60 3454.33 47.52 205.02 3034.30 952.02 -952.02 -744.74 0.95 3547.63 47.66 205.02 3097.23 1014.45 1 -1014.45 -773.87 0.15 4W 12 r � f • Conocci)hillips a :k. ,r., 2E - 04 P131 Measured Depth (ft) Inc I. ( zi A) ( 0) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (0/100ft) 3638.87 48.02 204.92 3158.47 1075.76 -1075.76 -802.43 0.40 3732.23 47.86 205.68 3221.01 1138.42 -1138.42 -832.05 0.63 3755.85 48.04 205.59 3236.83 1154.24 -1154.24 -839.63 0.81 3853.96 49.01 205.05 3301.81 1220.68 -1220.68 -871.07 1.07 3908.96 48.61 205.60 3338.03 1258.09 -1258.09 -888.77 1.05 4000.85 48.40 206.92 3398.91 1319.82 -1319.82 -919.22 1.10 4094.79 47.86 207.34 3461.61 1382.07 -1382.07 -951.12 0.66 4187.26 47.78 206.46 3523.70 1443.18 -1443.18 -982.12 0.71 4280.26 47.87 206.59 3586.14 1504.85 -1504.85 -1012.90 0.14 4373.12 47.73 207.26 3648.52 1566.18 -1566.18 -1044.05 0.56 4465.14 47.60 208.15 3710.49 1626.41 -1626.41 -1075.68 0.73 4556.94 47.83 209.29 3772.26 1685.96 -1685.96 -1108.31 0.95 4649.38 47.64 209.73 3834.43 1745.50 -1745.50 -1142.01 0.41 4742.11 47.77 209.72 3896.83 1805.06 -1805.06 -1176.02 0.14 4834.39 47.75 210.04 3958.87 1864.30 -1864.30 -1210.05 0.26 4926.71 47.69 209.68 4020.98 1923.54 -1923.54 -1244.06 0.30 5020.11 47.58 208.49 1 4083.91 1983.84 -1983.84 -1277.61 0.95 5113.35 47.76 206.94 4146.70 2044.86 -2044.86 -1309.66 1.24 5206.14 48.09 206.06 4208.88 2106.50 -2106.50 -1340.39 0.79 5298.54 48.19 205.73 4270.54 2168.41 -2168.41 -1370.44 0.29 5390.24 48.33 206.59 4331.59 2229.82 -2229.82 -1400.61 0.72 5483.34 48.28 205.93 1 4393.52 2292.16 -2292.16 -1431.37 0.53 5576.88 48.34 205.98 4455.73 2354.97 -2354.97 -1461.94 0.08 5669.20 48.28 206.31 4517.14 2416.86 -2416.86 -1492.32 0.27 5760.91 46.43 206.51 4579.26 2477.27 -2477.27 -1522.32 2.02 5854.46 42.72 207.82 4645.89 2535.68 -2535.68 -1552.27 4.09 5946.35 38.95 209.33 4715.40 2588.45 -2588.45 -1580.97 4.24 6039.80 34.66 208.81 4790.21 2637.37 -2637.37 -1608.18 4.60 6132.30 30.57 206.32 4868.11 2681.52 -2681.52 -1631.30 4.65 6225.73 26.18 201.28 4950.31 2722.05 -2722.05 -1649.32 5.35 6317.71 22.82 194.91 5034.01 2758.21 -2758.21 -1661.28 4.64 6410.27 18.94 191.35 5120.48 2790.29 -2790.29 -1668.86 4.41 6502.53 15.54 191.00 5208.58 2817.11 -2817.11 -1674.17 3.69 6596.18 13.99 187.39 5299.14 2840.65 -2840.65 -1678.02 1.92 6688.21 13.54 177.73 5388.54 2862.45 -2862.45 -1679.02 2.54 6780.17 11.15 170.08 5478.37 2881.97 -2881.97 -1677.06 3.14 6873.32 8.96 166.92 5570.08 2897.91 -2897.91 -1673.87 2.42 6965.24 7.33 163.62 5661.07 2910.51 -2910.51 -1670.59 1.84 7058.39 4.47 166.21 5753.72 2919.74 -2919.74 -1668.05 3.08 7151.77 0.55 141.54 5846.99 2923.63 -2923.63 -1666.91 4.26 7245.46 0.34 308.36 5940.68 2923.81 -2923.81 -1666.84 0.94 7336.97 0.25 182.01 6032.19 2923.84 -2923.84 -1667.06 0.58 7363.95 0.21 188.18 6059.17 2923.94 -2923.94 -1667.07 0.17 7400.64 0.03 198.12 6095.86 2924.02 -2924.02 1 -1667.09 0.44 13 LJ • • ConocoPhillips 2E - 04 PBI Measured Depth (ft) Incl. (0) A 0) (�) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (°/100ft) 7493.88 0.24 125.27 6189.10 2924.16 -2924.16 -1666.93 0.36 7586.14 0.19 40.85 6281.36 2924.28 -2924.28 -1666.57 0.41 7677.86 0.18 85.90 6337.08 2924.15 2924.15 -1666.32 0.15 7770.78 0.23 335.35 6466.00 2923.97 -2923.97 -1666.25 0.36 7839.14 0.12 142.12 6534.36 2926.90 -2923.90 -1666.27 0.51 7900.00 0.12 142.12 6595.22 2924.01 -2924.01 -1666.19 0.00 14 C] 5.2 Bit Record Cono h -flips Ah"ka Iry 2E — 04 PB1 Bit Size Make Type / S# Jets / Depth In Depth In Drilled Bit MAX Flow MAXMAX WOB Wear BHA TFA MD/ MD /(ft) Hrs (GPM) (Klbs) RPM 1 13.5" Baker MXL-1X 16X3 107' 170' 63' 1.25 500 5 30 --- 1 S# 5232073 20X1 1RR 13.5" Baker MXL-1X 16X3 282' 3,827' 3,545' 33.46 700 30 212 2 -4 -WT -N -E- 2 2 S# 5232073 20X1 -ER -TD PDC: 2X141 -1 -WT -A -X 2 9.875" Smith MSi519EPX 3X15 3,827 7,425' 3,598' 30.98 740 22 150 O -NO -CP 3 S# JH7408 3 8.5" HTC CORE CORE BIT1-1-WT-A-X 6X12 7,425' 7,515' 90' 29.25 200 20 80 1- 4 S# 7148275 NO -BHA BIT PDC: 2X141 -1 -WT -A -X 1- 2RR 9.875" Smith MXL-1X 3X15 7,515' 7,900' 385' 36.98 650 17 140 NO TD 5 S# JH7408 15 CANRIG Cvno hillips ..,..J.r, 2E - 04 PB1 5.3 Mud Record Contractor: RAI SWACC) Date Depth MW ECD VIS S/qt) PV YP Gels FL cc FC Sols a /o O/W Ratio Sd o /a pH CI ml/I Ca ml/I Spud Mud (Water Based) 1/05/14 186 8.8 0 300 32 54 34/57/64 0 0 6.00 /94 0.00 10.8 140 80 1/06/14 1296 9.6 10.32 327 40 70 30/55/69 0 0 9.00 /91 0.75 9.7 130 100 1/07/14 2970 9.5 10.9 336 63 69 23/6/54 4.9 2 1 6.25 /92 0.75 9.5 500 40 Kla-Shield 1/08/14 3830 9.6 11.04 322 49 72 32/71/76 4.1 3 10.00 2/88 1.00 9.4 280 20 1/09/14 3830 9.6 0 298 52 60 16/39/52 4.8 3 10.50 1/89 1.00 9.0 280 40 1/10/14 3830 9.6 0 63 24 18 3/4/4 0 0 9.50 1/90 0.50 9.0 280 40 1/11/14 3830 9.6 0 63 24 18 3/4/4 0 0 9.50 1/90 0.50 9.0 280 40 1/12/14 5082 9.5 0 61 16 30 12/20/26 4.8 1/ 9.00 3/88 tr 9.9 31000 160 1/13/14 6288 9.5 0 56 17 32 11/15/21 5.1 1/ 9.00 3/88 0.25 10.1 32000 120 1/14/14 7425 10.5 0 54 17 34 11/19/24 5.2 1/ 14.00 3/83 0.25 9.8 32000 100 1/15/14 7425 11.0 0 214 48 44 12/35/44 5.2 1/ 13.00 1/87 0.25 8.7 34000 200 Coring Fluid 1/16/14 7432 11.1 0 248 45 37 11/32/39 8.5 - 14.00 /86 0.25 9.0 33000 200 1/17/14 7510 11.0 0 374 59 52 15/34/42 3.8 1/2 15.00 1/85 0.25 8.6 1 35000 180 Kla Shield 1/18/14 7515 11.2 0 380 54 74 15/36/43 3.5 2/1 17.00 2/82 0.25 8.6 35000 160 1/19/14 7515 11.0 0 343 51 43 11/30/36 3.2 1/ 15.00 1/84 0.25 8.7 34000 160 1/20/14 7515 11.0 0 283 46 39 8/27/32 3.6 1/ 15.00 1/84 0.25 8.6 34000 160 1/21/14 7517 10.5 0 68 17 26 8/15/20 4.8 1/ 13.00 3/85 0.25 9.9 34000 120 Abbreviations MW = Mud Weight WL = Water or Filtrate Loss Ca = Hardness Calcium YP = Yield Point Gels = Gel Strength Sd = Sand content Cl = Chlorides VIS = Funnel Viscosity PV = Plastic Viscosity Sols = Solids ECD = Effective Circulating Density FC = Filter Cake O/W = Oil to Water ratio 16 CANRIG 5.4 Drilling Progress Chart 0 1000 2000 3000 4000 5000 F 6000 a w Q 7000 8000 9000 10000 11000 12000 v v v V co lips 2E - 04 P131 It v v v v v v v v v v a a v v v 17 CANM 96 SHOWREPORTS 0 • Hydrocarbon Show Report # Operator: ConocoPhilrps Well: 2E - 04 PB1 API Number: 50-029-23505-70-00 Field: Kuparuk River Unit Date: 1/12/2014 Rig: Doyon 141 Time: 18:30 County: North Slope Borough Depth Start End State: Country: Alaska USA 4550' MD 4575' MD 3768 TVD 3785' TVD Averages Pixler Plot 10000 — Before During After Maximum ROP (fph) 157.0 208.9 157.5 250 WOB 10.6 6.6 13.5 18 RPM 156.2 156.0 156.0 152 ,000 Mud Weight 9.5 9.5 9.5 9.5 Chloride 31,000 31,000 31,000 31,000 E ,00 Total Gas 420 1,091 231 1,348 C1 (ppm) 58,408 101,550 20,977 183,981 10 C2 (ppm) 3,781 6,510 1,126 12,521 1 2 3 4 C-2 .11.3 C„C< c„c5 C3 (ppm) 1,611 2,930 610 5,267 C4 (ppm) 1,196 1,935 265 1 3,969 C5 (ppm) 1523 913 167 1 1,720 i Lithology SANDSTONE/SAND = MEDIUM DARK GRAY TO DARK GRAY; MODERATELY HARD TO FRIABLE; LOWER VERY FINE TO LOWER FINE GRAINS; MODERATE TO HIGH SPHERICITY; SUBROUNDED TO ROUNDED; MODERATE SORTING; CONSOLIDATED SANDSTONE WITH UNCONSOLIDATED SAND GRAINS DOMINANTLY QUARTZ; MATRIX CEMENT OF SANDSTONE; MODERATE ODOR FROM SAMPLE; SAMPLE FLUORESCENSE IS ABOUT 75% BRIGHT YELLOW CUTTINGS FROM 4550' TO 4576; MILKY YELLOW, GREENISH SAMPLE FLUORESCENSE; NO NOTICABLE STEAMERS, SAMPLE INSTANTLY CUTS TO THE MILKY WHITE; RESIDUAL FLUORESCENSE RING IS BRIGHT YELLOW. Cuttings Analysis Odor IModerate Fluorescence Cut Fluorescence Residual Cut Stain Amount Distribution Intensity Color 75%, Type Intensity Color Fast Mod Amount None Color Clear Amount Color None Scattered Bright Milky Residual Fluorescence Cut Color Yellow Yellow Intesity Color Bright Yellow Show Rating Fair I Free Oil in Mud I None noted Comments A rapid gas rise in sand/sandstone of very fine to fine grain size with good visual porosity. A immediate bright white with yellow fluorescence and a strong yellow residual ring that turned to a yellow orange. Report by: Eric Andrews ConocoPhillips rc, 2E — 04 PBI 4 7 DAILY REPORTS • 0 19 C NM • ConocoPhillips Alaska Inc. Kuparuk River Unit DAILY WELLSITE REPORT RIG 2E-04 REPORT FOR Robert Wall/Robert Reinhardt DATE Jan 21, 2014 DEPTH 7520' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 7425' 24 HOUR FOOTAGE 95' CASING INFORMATION 10.75" @ 3814' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7245.46' 0.34 308.36 5940.68' 7336.97' 0.25 182.01 6032.19' SURVEY DATA 7363.95' 0.21 188.18 6059.17' 7400.64' 0.03 198.12 6095.86' 7493.88' 0.24 125.27 6189.10' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 9.875" MSi519EPX JH7408 2x14,3x15 7425' 95' 3:30 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 450.9 @ 7425' 5.6 @ 7462' 55.5 27.23476 FT/HR SURFACE TORQUE 11 @ 7428' 8 @ 7483' 10.7 10.40000 AMPS WEIGHT ON BIT 10 @ 7520' 0 @ 7427' 3.4 10.30000 KLBS ROTARY RPM 121 @ 7517 89 @ 7457 106.4 121.00000 RPM PUMP PRESSURE 2382 @ 7520' 1327 @ 7438' 1593.3 2382.00000 PSI DRILLING MUD REPORT DEPTH 7517' MW 10.5 VIS 68 PV 17 YP 26 FL 4.8 Gels 8/15/20 CL- 34000 FC 1/ SOL 13 SD 0.25 OIL 3/85 MBL 7.1 pH 9.9 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 137 @ 7425' 10 @ 7436' 51.6 TRIP GAS 320u CUTTING GAS 0 @ 7520' 0 @ 7520' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 12381 @ 7425' 923 @ 7436' 4468.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 471 @ 7490' 42 @ 7436' 333.4 AVG 0 PROPANE (C-3) 309 @ 7425' 25 @ 7436' 155.2 CURRENT 0 BUTANE (C-4) 572 @ 7425' 40 @ 7436' 162.1 CURRENT BACKGROUND/AVG 55u/40u PENTANE (C-5) 249 @ 7425' 18 @ 7436' 83.6 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Sandstone, Shale, Carbonaceous Shale, Sand DAILY ACTIVITY Ran in hole; circulated mud, and displaced mud. Began opening up cored section from 7425' to 7515' and SUMMARY continued drilling into new formation from 7515' to 7519' at time of midnight report. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3,035.00 • REPORT BY Eric Andrews 17-� • Is ConocoPhillips Alaska Inc. Kuparuk River Unit DAILY WELLSITE REPORT 2E-04 mMRiCj* REPORT FOR Robert Wall/Andy Lundale DATE Jan 20, 2014 DEPTH 7423' PRESENT OPERATION Reaming hole TIME 23:59 YESTERDAY 7423' 24 HOUR FOOTAGE 0' CASING INFORMATION 10.75" @ 3814' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 9.875" MSi519EPX JH7408 2x14,3x15 7423' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM CO) @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7515' MW 11.0 VIS 283 PV 46 YP 39 FL 3.6 Gels 8/27/32 CL- 34000 FC 1/ SOL 15 SD 0.25 OIL 1/84 MBL 7.5 pH 8.6 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Layed down core;coring tools, made up BHA, Picked up BHA and began running in hole to bottom. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3,035.00 REPORT BY Eric Andrews 01, • 0 ConocoPhillips Alaska Inc. Kuparuk River Unit DAILY WELLSITE REPORT RIG 2E-04 REPORT FOR Robert Wall/Andy Lundale DATE Jan 19, 2014 DEPTH 7515' PRESENT OPERATION Pulling out of hole TIME 23:59 YESTERDAY 7515' 24 HOUR FOOTAGE 0' CASING INFORMATION 10.75" @ 3814' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7515' MW 11.0 VIS 343 PV 51 YP 43 FL 3.2 Gels 11/30/36 CL- 34000 FC 1/ SOL 15 SD 0.25 OIL 1/84 MBL 7.5 pH 8.7 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 44u CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 7u/30u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Pulled out of hole from 7515' CANRIG PERSONNEL ON BOARD 4 DAILY COST $3,035.00 REPORT BY Eric Andrews Li • ConocoPhillips Alaska Inc. Kuparuk River Unit DAILY WELLSITE REPORT 2E-04 OmRIG REPORT FOR Robert Wall/Andy Lundale DATE Jan 18, 2014 DEPTH 7515' PRESENT OPERATION Circulating TIME 23:59 YESTERDAY 7510' 24 HOUR FOOTAGE 5' CASING INFORMATION 10.75" @ 3814' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5" BHC 406 C 7148275 1.75 7423' 7515' 92' 24.60 TD Core DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 2.1 @ 7510' 1.8 @ 7511' 0.8 0.00000 FT/HR SURFACE TORQUE 10 @ 7511' 9 @ 7510' 4.0 0.00000 AMPS WEIGHT ON BIT 37 @ 7515' 24 @ 7511' 17.4 37.50000 KLBS ROTARY RPM 77 @ 7510' 76 @ 7511' 30.6 0.00000 RPM PUMP PRESSURE 1238 @ 7510' 963 @ 7515' 676.0 963.00000 PSI DRILLING MUD REPORT DEPTH 7515' MW 11.2 VIS 380 PV 54 YP 74 FL 3.5 Gels 15/36/43 CL- 35000 FC 2/1 SOL 17 SD 0.25 OIL 2/82 MBL 7.5 pH 8.6 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 52 @ 7515' 18 @ 7511' 18.5 TRIP GAS 0 CUTTING GAS 0 @ 7515' 0 @ 7515' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 4820 @ 7515' 2140 @ 7511' 1883.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 612 @ 7515' 266 @ 7511' 236.7 AVG 0 PROPANE (C-3) 522 @ 7515' 222 @ 7511' 199.6 CURRENT 0 BUTANE (C-4) 379 @ 7515' 153 @ 7511' 141.0 CURRENT BACKGROUND/AVG N/A/40u PENTANE (C-5) 195 @ 7515' 78 @ 7511' 72.1 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Continued coring from 7510' to 7515', pulled off bottom, circulated and conditioned mud through phase 3 SUMMARY weather. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3,035.00 REPORT BY Eric Andrews • • III ConocoPhillips Alaska Inc. Kuparuk River Unit DAILY WELLSITE REPORT 2E-04 OMRIG REPORT FOR Rober Wall/Andy Lundale DATE Jan 17, 2014 DEPTH 7510' PRESENT OPERATION Coring TIME 23:59 YESTERDAY 7424' 24 HOUR FOOTAGE 86' CASING INFORMATION 10.75" @ 3814' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5" BHC 406 C 7148275 1.75 7423' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 450.9 @ 7425' 0.5 @ 7449' 8.9 2.10011 FT/HR SURFACE TORQUE 15 @ 7431' 6 @ 7449' 8.8 9.90000 AMPS WEIGHT ON BIT 28 @ 7485' 18 @ 7438' 21.6 24.80000 KLBS ROTARY RPM 120 @ 7424' 66 @ 7476' 71.3 77.00000 RPM PUMP PRESSURE 1524 @ 7424' 796 @ 7431' 930.2 1238.00000 PSI DRILLING MUD REPORT DEPTH 7510' MW 11.0 VIS 374 PV 59 YP 52 FL 3.8 Gels 15/34/42 CL- 35000 FC 1/2 SOL 15 SD 0.25 OIL 1/85 MBL 7.5 pH 8.6 Ca+ 180 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 236 @ 7435' 2 @ 7458' 100.3 TRIP GAS 0 CUTTING GAS 0 @ 7510' 0 @ 7510' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 23324 @ 7435' 377 @ 7458' 11281.7 CONNECTION GAS HIGH 0 ETHANE (C-2) 2508 @ 7476' 8 @ 7458' 814.4 AVG 0 PROPANE (C-3) 1721 @ 7476' 6 @ 7458' 595.2 CURRENT 0 BUTANE (C-4) 763 @ 7435' 11 @ 7449' 384.5 CURRENT BACKGROUND/AVG 46u/80u PENTANE (C-5) 358 @ 7502' 3 @ 7449' 161.2 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Shale, Sandstone, Siltstone, Sand DAILY ACTIVITY SUMMARY Cored from 7430' to 7510'. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3035.00 REPORT BY Eric Andrews • n U ConocoPhillips Alaska Inc. Kuparuk River Unit 2E-04 REPORT FOR Robert Wall/Andy Lundale DATE Jan 16, 2014 TIME 23:59 CASING INFORMATION 10.75" @ 3814' JETS IN DEPTH SURVEY DATA BIT INFORMATION LOW AVERAGE NO. SIZE TYPE S/N 4 8.5" BHC 406 C 7148275 DRILLING PARAMETERS @ RATE OF PENETRATION SURFACE TORQUE @ WEIGHT ON BIT ROTARY RPM 37 FL Gels PUMP PRESSURE /86 MBL 7.5 pH DRILLING MUD REPORT MW 11.1 VIS 248 PV FC SOL 14 SD MWD SUMMARY INTERVAL TO TOOLS Y (units) HI 7HA r DAILY WELLSITE REPORTj' CANRIG DEPTH 7424' PRESENT OPERATION Circulating YESTERDAY 7423' 24 HOUR FOOTAGE 1' INCLINATION AZIMUTH VERTICAL DEPTH INTERVAL JETS IN OUT FOOTAGE 1.75 7423' HIGH LOW AVERAGE @ @ FT/HR @ @ KLBS @ @ DEPTH 7432' 45 YP 37 FL Gels 0.25 OIL /86 MBL 7.5 pH GH LOW AVERAGE @ @ @ @ CHROMATOGRAPHY (ppm) CONDITION REASON HOURS T/B/C PULLED CURRENT AVG FT/HR AMPS KLBS RPM PSI 11/32/39 CL- 33000 9.0 Ca+ 200 CCI TRIP GAS 0 WIPER GAS 0 SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Layed down BHA #3, picked up core barrels, coring tools, collars, HWDP, jars, and began running in hole from 756' SUMMARY to 7239' filling every 20 stands. Washed and reamed from 7239' to 7425'. Began coring from 7425' to 7431' and started taking losses to hole. Pulled off bottom two stands and circulated mud. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3,035.00 REPORT BY Eric Andrews • U ConocoPhillips Alaska Inc. Kuparuk River Unit DAILY WELLSITE REPORT RIG 2E-04 REPORT FOR Pat Krupa/Andy Lundale DATE Jan 15, 2014 DEPTH 7423' PRESENT OPERATION Laying down BHA TIME 23:59 YESTERDAY 7423' 24 HOUR FOOTAGE 0' CASING INFORMATION 10.75" @ 3814' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7525' MW 11.0 VIS 214 PV 48 YP 44 FL 5.2 Gels 21/35/44 CL- 34000 FC 1/ SOL 13 SD 0.25 OIL 1/87 MBL 7.5 pH 8.7 Ca+ 200 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 398u CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0/0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Continued circulating hole clean, and began pulling out of hole making sure to back ream over any tight SUMMARY spots. Pulled out of hole and layed down tool. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3035.00 REPORT BY Eric Andrews • • ConocoPhillips Alaska Inc. Kuparuk River Unit DAILY WELLSITE REPORT OMG 2E-04 REPORT FOR Larry Hill/Dave Coates DATE Jan 14, 2014 DEPTH 7423' PRESENT OPERATION Pulling out of the hole TIME 23:59 YESTERDAY 6293' 24 HOUR FOOTAGE 1130' CASING INFORMATION 10.75" @ 3814' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6873.32' 9.01 166.92 5570.28' 6965.24' 7.29 163.64 5661.27' SURVEY DATA 7058.39' 4.46 166.6 5753.92' 7151.77' 0.67 141.38 5847.19' 7245.46' 0.24 307.23 5940.88' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875' Smith PDC JH7404 2x14,3x15 3842' 7423' 3581' 33:28:26 Still In Hole TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 347.8 @ 6378' 2.3 @ 7373' 118.4 46.82107 FT/HR SURFACE TORQUE 12 @ 7245' 7 @ 6593' 9.8 10.7 AMPS WEIGHT ON BIT 29 @ 7093' 0 @ 7246' 6.4 10.4 KLBS ROTARY RPM 152 @ 6842' 109 @ 7245' 148.8 150 RPM PUMP PRESSURE 2624 @ 7197' 1799 @ 6454' 2410.1 2606 PSI DRILLING MUD REPORT DEPTH 7423' MW 9.5 VIS 56 PV 17 YP 32 FL 5.1 Gels 11/15/21 CL- 32000 FC 1/ SOL 9 SD 0.25 OIL 3/88 MBL 3 pH 10.1 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1025 @ 7052' 4 @ 6318' 205.0 TRIP GAS 0 CUTTING GAS 0 @ 7423' 0 @ 7423' 0.0 WIPER GAS 191 u CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 129191 @ 7052' 706 @ 6318' 29575.1 CONNECTION GAS HIGH 141u ETHANE (C-2) 4416 @ 6605' 14 @ 7053' 616.6 AVG 0 PROPANE (C-3) 2883 @ 6555' 10 @ 7053' 359.1 CURRENT 0 BUTANE (C-4) 1476 @ 7052' 2 @ 6318' 366.0 CURRENT BACKGROUND/AVG 43u/60u PENTANE (C-5) 714 @ 7052' 0 @ 6354' 147.7 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Carbonaceous Shale, Shale, Siltstone, Sandstone, Sand DAILY ACTIVITY SUMMARY Continued drilling from 6293' to 7423', circulated and began pulling out of hole. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3,035.00 0 REPORT BY Eric Andrews • • ConocoPhillips Alaska Inc. Kuparuk River Unit DAILY WELLSITE REPORT 2E-04 OMRIG REPORT FOR Larry Hill/Dave Coates DATE Jan 13, 2014 DEPTH 6293' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 5097' 24 HOUR FOOTAGE 1196' CASING INFORMATION 10.75" @ 3814' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6039.8' 34.67 208.76 4791.08' 6132.3' 30.56 206.4 4868.99' 6225.73' 26.18 201.58 4951.21' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875" Smith PDC JH7404 2x14,3x15 3842' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 308.7 @ 5996' 2.9 @ 5730' 108.9 204.69392 FT/HR SURFACE TORQUE 11 @ 6137' 5 @ 5361' 7.3 9.90000 AMPS WEIGHT ON BIT 29 @ 5795' 1 @ 6194' 16.1 10.70000 KLBS ROTARY RPM 160 @ 5393' 108 @ 6006' 142.7 150.00000 RPM PUMP PRESSURE 2323 @ 6209' 1485 @ 5363' 2029.1 2308.00000 PSI DRILLING MUD REPORT DEPTH 6288' MW 9.5 VIS 56 PV 17 YP 32 FL 5.1 Gels 11/15/21 CL- 32000 FC 1/ SOL 9 SD 0.25 OIL 3/88 MBL 3 pH 10.1 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 96 @ 6165' 0 @ 6074' 43.7 TRIP GAS 0 CUTTING GAS 0 @ 6293' 0 @ 6293' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 95424 @ 6035' 26 @ 6074' 9997.5 CONNECTION GAS HIGH 0 ETHANE (C-2) 2646 @ 6034' 0 @ 6071' 340.8 AVG 0 PROPANE (C-3) 1411 @ 6058' 0 @ 6071' 197.9 CURRENT 0 BUTANE (C-4) 230 @ 6255' 0 @ 5893' 58.4 CURRENT BACKGROUND/AVG 67u/25u PENTANE (C-5) 190 @ 6255' 0 @ 6143' 31.7 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Siltstone, Sandstone, Shale PRESENT LITHOLOGY Siltstone, Sandstone, Shale DAILY ACTIVITY Pulled out of hole from 5072' to 3788', Changed out brake bands. Began running in hole from 3788' to 4992', SUMMARY washed and reamed from 4992' to 5082' and proceeded to drill to 6293' at time of midnight report. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3035.00 REPORT BY Eric Andrews • • ConocoPhillips Alaska Inc. Kuparuk River Unit DAILY WELLSITE REPORT R co 2E-04 II REPORT FOR Larry Hill/Dave Coates DATE Jan 12, 2014 DEPTH 5097' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 3839' 24 HOUR FOOTAGE 1258' CASING INFORMATION 10.75" @ 3814' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4649.38' 47.65 209.69 3834.68' 4742.11' 47.74 210.10 3897.10' SURVEY DATA 4834.39' 47.72 210.63 3959.18' 4926.71' 47.65 210.12 4041.33' 5020.11' 47.56 209.06 4084.30' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875" Smith PDC JH7404 2x14,3x15 3842' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 477.1 @ 4809' 5.5 @ 3839' 153.4 15.20399 FT/HR SURFACE TORQUE 8 @ 4654' 4 @ 4005' 6.2 5.90000 AMPS WEIGHT ON BIT 22 @ 5078' 0 @ 4070' 7.8 11.40000 KLBS ROTARY RPM 153 @ 4434' 66 @ 3891' 143.0 148.00000 RPM PUMP PRESSURE 1923 @ 5077' 1125 @ 3847' 1743.2 1832.00000 PSI DRILLING MUD REPORT DEPTH 5082' MW 9.5 VIS 61 PV 16 YP 30 FL 4.8 Gels 12/20/26 CL- 31000 FC 1/ SOL 9 SD tr OIL 3/88 MBL 3 pH 9.9 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1348 @ 4552' 1 @ 4874' 132.4 TRIP GAS 0 CUTTING GAS 0 @ 5097' 0 @ 5097' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 183981 @ 4551' 218 @ 4874' 18593.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 12521 @ 4551' 0 @ 3902' 589.6 AVG 0 PROPANE (C-3) 5267 @ 4551' 0 @ 3902' 336.8 CURRENT 0 BUTANE (C-4) 3969 @ 4551' 0 @ 3902' 173.9 CURRENT BACKGROUND/AVG 45u/1 20u PENTANE (C-5) 1720 @ 4551' 0 @ 3902' 100.2 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 4550'-4575' Sandstone/Sand Peaked SANDSTONE/SAND (4540'-4600') = MEDIUM DARK GRAY TO DARK GRAY; MODERATELY FIRM at 1,349 TO FRIABLE; LOWER VERY FINE TO LOWER FINE GRAINS; MODERATE TO HIGH SPHERICITY; Units SUBROUNDED TO ROUNDED; MODERATE SORTING; CONSOLIDATED SANDSTONE WITH UNCONSOLIDATED SAND GRAINS, DOMINANTLY QUARTZ; MATRIX CEMENT OF SANDSTONE; MODERATE ODOR FROM SAMPLE; SAMPLE FLUORESCENSE ABOUT 75% BRIGHT YELLOW CUTTINGS FROM 4550' TO 4575; MILKY YELLOW, GREENISH SAMPLE FLUORESCENSE; NO NOTICABLE STEAMERS, SAMPLE INSTANTLY CUTS TO MILKY YELLOW; RESIDUAL FLUORESCENSE RING SHOWS BRIGHT YELLOW; NO VISIBLE RESIDUAL RING. LITHOLOGY PRESENT LITHOLOGY Siltstone, Sandstone, Sand DAILY ACTIVITY Rigged up and tested 10.75" casing. Ran in hole from 3603' to 3695; washed and reamed out shoe track and rat hole to 3827'. Drilled out SUMMARY from 3827' to 3847'. Displaced old mud, circulated hole clean, and then commenced drilling from 3847' to 5097' at time of midnight report. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3,035.00 . REPORT BY Eric Andrews • • 0 ConocoPhillips Alaska Inc. Kuparuk River Unit DAILY WELLSITE REPORT RIG 2E-04 REPORT FOR Larry Hill/Dave Coates DATE January 11, 2014 DEPTH 3839' PRESENT OPERATION Running In Hole TIME 23:59 YESTERDAY 3839' 24 HOUR FOOTAGE 0' CASING INFORMATION 10.75" @ 3814' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875" Smith PDC JH7408 2X14,3X15 3842' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 3830' MW 9.6 VIS 63 PV 24 YP 18 FL Gels 3/4/4 CL- 280 FC SOL 9.5 SD 0.5 OIL 1/90 MBL 30 pH 9.0 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Made up well head diverter, Tested BOP's. Running in hole at time of midnight report. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2,160.00 REPORT BY Eric Andrews • • is ConocoPhillips Alaska Inc. Kuparuk River Unit DAILY WELLSITE REPORT CoMRIG 2E-04 REPORT FOR Larry Hill/Dave Coates DATE January 10, 2014 DEPTH 3839.00000 PRESENT OPERATION Nipple Down Diverter TIME 23:59 YESTERDAY 3839.00000 24 HOUR FOOTAGEO' CASING INFORMATION 10.75" @ 3814' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE PSI DRILLING MUD REPORT DEPTH 3830' MW 96 VIS 63 PV 24 YP 18 FL Gels 3/4/4 CL- 280 FC -/- SOL 9.5 SD 0.5 OIL 1/90 MBL 30 pH 9.0 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGHO ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Finished running casing to 3814' and rigged up cement head. Pumped cement job and began nippled SUMMARY down diverter. CANRIG PERSONNEL ON BOARD4 DAILY COST$2,910.00 REPORT BY Eric Andrews • • ConocoPhillips Alaska Inc. Kuparuk River Unit DAILY WELLSITE REPORT 2E-04 OMRIG REPORT FOR Larry Hill/Dave Coates DATE January 9, 2014 DEPTH 3830' PRESENT OPERATION Casing TIME 23:59 YESTERDAY 3830' 24 HOUR FOOTAGE 0' CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 13.5" MT MXL-1 5232073 3x16,1 x20 222' 3830' 3608' TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 3830' MW 9.6 VIS 297 PV 52 YP 60 FL 4.8 Gels 16/39/52 CL- 280 FC 3/- SOL 10.5 SD 1 OIL 1/89 MBL 25 pH 9.0 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Ran back in hole from 749' to 3807', washed and reamed from 3807' to 3830'. Circulated and conditioned. SUMMARY Pulled out of hole, layed down BHA#2. Rigged up and began running casing. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2,060.00 REPORT BY Eric Andrews • 0 ConocoPhillips Alaska Inc. Kuparuk River Unit DAILY WELLSITE REPORT 2E-04 OMRIG REPORT FOR Larry Hill/Dave Coates DATE January 8, 2014 DEPTH 3830' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 2970' 24 HOUR FOOTAGE 860' CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 13.5" MT MXL-1X 5232073 3x16,1 x20 222' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 422.6 @ 3030' 2.4 @ 3317' 139.4 0.00000 FT/HR SURFACE TORQUE 8 @ 3681' 0 @ 3828' 5.5 0.00000 AMPS WEIGHT ON BIT 39 @ 3152' 0 @ 3047' 16.9 0.00000 KLBS ROTARY RPM 82 @ 3480' 56 @ 3043' 70.6 0.00000 RPM PUMP PRESSURE 2471 @ 3676' 1550 @ 3082' 2129.7 0.00000 PSI DRILLING MUD REPORT DEPTH 3830' MW 9.6 VIS 322 PV 49 YP 72 FL 4.1 Gels 32/71/76 CL- 280 FC 3/- SOL 10 SD 1 OIL 2/88 MBL 32.5 pH 9.4 Ca+ 20 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 496 @ 3007' 27 @ 3092' 188.1 TRIP GAS CUTTING GAS 0 @ 3830' 0 @ 3830' 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 124209 @ 3007' 4227 @ 3827' 29844.9 CONNECTION GAS HIGH ETHANE (C-2) 649 @ 3527' 2 @ 3243' 123.8 AVG PROPANE (C-3) 328 @ 3527' 0 @ 3125' 47.0 CURRENT BUTANE (C-4) 10 @ 3528' 0 @ 3292' 1.1 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 3830' 0 @ 3830' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Drilled from 2970' to 3820' Reaming back after each stand. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2,060.00 REPORT BY Eric Andrews • • ConocoPhillips Alaska Inc. Kuparuk River Unit DAILY WELLSITE REPORT 2E-04 wMR1Gftb REPORT FOR Larry Hill/ Dave Coates DATE Jan 07, 2014 DEPTH 2970' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 1301' 24 HOUR FOOTAGE 1669' CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 13.5" MT MXL-1 X 5232073 3x16,1 x20 222' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 0 @ 0.0 FT/HR SURFACE TORQUE 0 @ 0 @ 0.0 AMPS WEIGHT ON BIT 0 @ 0 @ 0.0 KLBS ROTARY RPM 0 @ 0 @ 0.0 RPM PUMP PRESSURE 0 @ 0 @ 0.0 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL - FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 0 @ 0.0 TRIP GAS CUTTING GAS 0 @ 0 @ 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 0 @ 0 @ 0.0 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 0 @ 0.0 AVG PROPANE (C-3) 0 @ 0 @ 0.0 CURRENT BUTANE (C-4) 0 @ 0 @ 0.0 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 0 @ 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continued drilling from 1301' to 2970'. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2,060.00 REPORT BY Eric Andrews • 0 ConocoPhillips Alaska Inc. Kuparuk River Unit 2E-04 REPORT FOR Larry Hill/ Rob Reinhardt DATE Jan 06, 2014 TIME 23:59 CASING INFORMATION INTERVAL 0 @ 0.0 DEP SURVEY DATA OUT BIT INFORMATION 3x16,1 x20 NO. SIZE TYPE S/N 1 13.5" MXL-1 X 5232073 2 13.5" MXL-1X 5232073 DRILLING PARAMETERS HIGH RATE OF PENETRATION AVERAGE SURFACE TORQUE @ WEIGHT ON BIT 0.0 ROTARY RPM @ PUMP PRESSURE 0.0 DRILLING MUD REPORT @ MW 9.3 VIS 327 PV FC SOL 9 SD MWD SUMMARY 0.0 INTERVAL TO @ TOOLS 0.0 GAS SUMMARY (units) DITCH GAS 0 CUTTING GAS 0 DAILY WELLSITE REPORT DEPTH 1301' PRESENT OPERATION Drilling Ahead YESTERDAY 186' 24 HOUR FOOTAGE 1115' TH INCLINATION AZIMUTH VERTICAL DEPTH HIGH LOW AVERAGE @ 0 @ 0.0 @ 0 @ 0.0 CHROMATOGRAPHY (ppm) CONDITION REASON HOURS T/B/C PULLED TD CURRENT AVG FT/HR AMPS KLBS RPM PSI Gels 30/55/69 CL- 130 pH 9.7 Ca+ 100 CCI TRIP GAS 0 WIPER GAS 0 SURVEY 0 METHANE (C-1) INTERVAL 0 @ 0.0 JETS IN OUT FOOTAGE 3x16,1 x20 38' 222' 184' 3x16,1 x20 222' 0 @ 0 @ 0.0 CURRENT HIGH LOW AVERAGE 0.0 @ 0 @ 0.0 0 @ 0 @ 0.0 0 @ 0 @ 0.0 0 @ 0 @ 0.0 0 @ 0 @ 0.0 DEPTH 1301' 40 YP 70 FL 0.75 OIL /91 MBL 26.25 HIGH LOW AVERAGE @ 0 @ 0.0 @ 0 @ 0.0 CHROMATOGRAPHY (ppm) CONDITION REASON HOURS T/B/C PULLED TD CURRENT AVG FT/HR AMPS KLBS RPM PSI Gels 30/55/69 CL- 130 pH 9.7 Ca+ 100 CCI TRIP GAS 0 WIPER GAS 0 SURVEY 0 METHANE (C-1) 0 @ 0 @ 0.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 0 @ 0.0 AVG 0 PROPANE (C-3) 0 @ 0 @ 0.0 CURRENT 0 BUTANE (C-4) 0 @ 0 @ 0.0 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 0 @ 0 @ 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Drilled from 107' to 222', Circulated, pulled out of hole, and layed down BHA#1. Made up BHA#2, picked up, SUMMARY and ran in hole to 222'. Continued drilling from 222' to 1301'. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2,060.00 REPORT BY Eric Andrews STATE OF ALASKA ALASK 00IL AND GAS CONSERVATION COMMIS ON RAR 14 2014 WELL COMPLETION OR RECOMPLETION REPORT AND WCC 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development O Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No. of Completions: Service ❑ StratigraphicTest❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: February 17, 2014 • 213-168/ , 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 January 5, 2014 50-029-23505-00 & 50-029-23505-70 - 4a. Location of Well (Governmental Section): 7. Date TO Reached: 14. Well Name and Number: Surface: 580' FSL, 160' FWL, Sec. 36, T11 N, R9E, UM January 30, 2014 KikI ,_ 2E-04 & 2E-04PB1 8. KB (ft above MSL): 133' RKB 15. Field/Pool(s): Top of Productive Horizon: 1228' FSL, 2222' FEL, Sec. 2, T1 ON, R9E, UM GL (ft above MSL): 105.9' AMSL Kuparuk River Field 9. Plug Back Depth (MD + TVD): Total Depth: 333' FSL, 2852' FEL, Sec. 11, TI ON, R9E, UM 14816' MD / 6259' TVD Kupuruk River Oil Pool . 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x-529972 y- 5944222 Zone -4 14823' MD / 6259' TVD ADL 25658, 25665 11. SSSV Depth (MD + TVD): 17. Land Use Permit: TPI: x-527612 y- 5939582 Zone -4 Total Depth: x-527011 y- 5933406 Zone -4 nipple @ 613' MD / 613' TVD 2584, 2586 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) 1 N/A (ft MSL) 1499' MD / 1486' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-drill/Lateral Top Window MD/TVD GR / Res, Sonic not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.58# H-40 28' 107' 28' 107' 24" 290 sx CS II 10.75" 45.5# L-80 28' 3816' 28' 3277' 13.5" 1518 sx ALC, 211 sx ALC 7.625" 29.7# L-80 25' 8237' 25' 6020' 9.875" 571 sx Class G 7.625" 39# L-80 1 8237' 8831' 6020' 6161' 9.875" included above 4.5" 12.6# L-80 8585' 14816' 6123' 6259' 6.5" open hole liner 24. Open to production or injection? Yes No Q If Yes, list each 25. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 4.5 x 3.5 8631' 8585' MD / 6123' open hole liner from 8586-14816' MD 6123'-6259' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes❑ No Q' PLETIQ6� DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED suit LATE plug 1 from 7263-7827' 411 sx Class G 1-' plug 2 from 6719-7180' 337 sx Class G VERT plug 3 from 6069'-6718' 348 sx Class G plug 4 from 5490'-6087' 505 sx Class G 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) waiting on facility hook-up Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS -OIL RATIO Test Period --> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API(corr) Press. 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes Q No ❑ Sidewall Cores Acquired? Yes '❑✓ No 1:1 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. Conventional Core: Formations cored: Kuparuk A sand . depths cored: Core #1: 7425' MD - 7515' MD Summary of Lithology: see attached core chip descriptions p� Sidewall Core: Formations cored: Brookian Tarn / Meltwater, HRZ - RBDMS APR 17 204 depths cored: 6559- MD - 7230' MD see attached core chip descriptions Form 10-407 Revised 10/2012 �� �' C(I �� CONTINUED ON REVERSE �/ submit onginai only 1 / _ P ---zI -4 /3 1 / 4- .e !/7/l j"C (•C 29. GEOLOGIC MARKERS (List all formations and marke ountered): 30. FORMATION TESTS NAME MD TVD Well tested? R Yes 2] 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 1499' 1486' needed, and submit detailed test information per 20 AAC 25.071. Kuparuk C (top C4) 8493' 6100' Kuparuk A6 8635' 6135' Kuparuk A5 8738' 6150' N/A 2E-04 PB1 total depth 7900' 6595' Formation at total depth: Kuparuk A5 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic, final directional survey, core chip descriptions (2 summaries) 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Haibin Guo Email: Haibin.Guo(c�conocophillips.com 4�1 Printed Name G. L. Alvord Title: Alaska Drilling Manager ar Date 3 /lo // el Signature Phone 265-6120 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 UP PROD 2E-04 %AA rvLvr a rnutxa Alaska, Inc.Wellbore ,®...,....... API/UWI Fietd Name 500292350500 KUPARUK RIVER UNIT - Wellbore Stat ncl () MD (ftKB) Act Btm (ftKB) PROD 14,823.0 HORIZONTAL -2E-04;3/131201411;47:23 AM Comment SSSV: Nipple H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date LesI WG: 27.42 2/17/2014 e wa tw acwa Annotation Last Tag: Depth (ftKB) End Date Annotation Last Mod By End Date Rev Reason: NEW WELL postojl 3/12/2014 HANGER, 22.9 „, Casing Description CONDUCTOR OD (in) 16 ID (in) Top (ftKB) 15.250 27.0 Set Depth (ftKB) Set Depth (ND)... Wt/Len 11... Grade Top Thread 107.5 107.5 62.50 H-00 Welded but Casing Description SURFACE OD (in) 103!4 ID (in) Top (ftKB) 9.950 28.0 Set Depth (ftKB) Set Depth (ND)... WtlLen (I... Grade Top Threatl 3,816.3 3,277.0 45.50 L80 HYD 563 CONDUCTOR; 270-107.5 NIPPLE; 612.9 Casing Description OD (in) INTERMEDIATE 75/8 ID (in) Top (ttK8) Set Depth (ftKB) Set Depth (ND)... WtlLen (I... Grade Top Thread 6.875 25.4 8,830.7 6,160.7 29.70 L-80 Hydril 563 Casing Description OD (in)ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (ND)... WtlLen (I... Grade Top Thread LINER 4 12 3.910 8,584.8 14,816.0 6,259.3 12.60 L-80 Hyd 563 Uner Ntaus, Nominal ID GAS LIFT; 2,830.0 Top (ftKB) Top (ND) (ftKB) Top Incl C) Item Des Co. (in) 8,584.8 6,123.8 77.80 PACKER BAKER HRD ZXP LINER TOP PACKER 4.900 8,604.8 6,127.9 78.44 NIPPLE BAKER RS NIPPLE TSH -521 PxB 4.890 SURFACE; 28.1-3,8163 8,619.1 6,130.7 78.90 SEAL ASSY BAKER 80-40 20'x 4" ID Seal Bore Extension TSH 4.000 521 PXP (effective seals 37 ft) 8,852.1 6,162.0 86.77 SWELL FREECAP I FSC -11 6.13" OD SWELL PACKER 3.910 GAS LIFT, 4,619.4 PACKER 9,238.5 6,157.9 92.41 FRAC SLEEVE FracSleeve (Ball Actuated) (2.073" Seat for 2.125" 2.063 Ball) GAS LIFT; 5.946,0- ,946.09,801.2 r801 26,162.9 89.19 SWELL FREECAP I FSC -11 6.13" OD SWELL PACKER 3.910 PACKER GAS LIFT; 6,898.3 9,994.1 6,166.4 87.76 SWELL FREECAPIFSC-11 6.13"OD SWELL PACKER 3.910 PACKER 10,380.4 6,187.4 87.89 FRAC SLEEVE FracSleeve (Ball Actuated) (2.011" Seat for 2.063" 2.000 GAS LIFT; 7,599.0 Ball) 10,712.0 6,200.7 87.61 SWELL FREECAP I FSC -11 6.13" OD SWELL PACKER 3.910 PACKER NIPPLE; 7,8446 11,097.9 6,197.5 91.68 FRAC SLEEVE FracSleeve (Ball Actuated ) (1.938" Seat for 2.000" 1.938 11,427.0 6,193.5 87.86 SWELL FREECAPI FSC -11 6.13" OD SWELL PACKER 3.910 PACKER GAUGE; 8,569.9 11,773.5 6,209.0 88.06 FRAC SLEEVE FracSleeve (Ball Actuated ) (1.886" Seat for 1.938" 1.875 Ball) 12,104.2 6,213.6 90.37 SWELL FREECAP I FSC -11 6.13" OD SWELL PACKER 3.910 PACKER 12,297.4 6,213.3 89.87 SWELL FREECAP I FSC -11 6.13" OD SWELL PACKER 3.910 PACKER SEAL ASSY; 8,620.9 12,758.6 6,231.5 87.81 FRAC SLEEVE FracSleeve (Ball Actuated) (1.823" Seat for 1.875" 1.813 Ball) 13,051.4 6,236.4 87.62 SWELL FREECAP I FSC -11 6.13" OD SWELL PACKER 3.910 PACKER 13,168.0 6,241.4 88.79 SWELL FREECAP I FSC -11 6.13" OD SWELL PACKER 3.910 INTERMEDIATE; 25.4-8,830.7 APACKER 13,669.2 6,241.2 90.53 FRAC SLEEVE FracSleeve (Ball Actuated) (1.761" Seat for 1.813" 1.750 Ball) 14,103.6 6,244.3 89.07 SWELL FREECAP I FSC -11 6.13" OD SWELL PACKER 3.910 PACKER Tubing Description TUBING String Ma... ID (in) Top (ftKB) Set Depth (ft.. Set Depth (ND) (... Wt (INR) Grade Top Connection 31/2 2.992 22.9 8,631.6 6,133.1 9.20 L-80 EUE 8Rd - Nominal ID Top (ftKB) Top (ND) (ftKB) Top Incl (°) Item Des Com (in) 22.9 22.9 0.00 HANGER TUBING HANGER 4.500 612.9 612.7 3.02 NIPPLE CAMCO DS NIPPLE W/ 2.875" Profile 2.875 7,844.9 5,852.3 61.11 NIPPLE SLB DS NIPPLE W CAT STANDING VALVE (65°) 2.812 8,569.9 6,120.6 77.32 GAUGE SLB GAUGE CARRIER 3-1/2" EUE P x P 2.992 8,620.9 6,131.1 78.96 SEAL ASSY BAKER 8040 GBH LOCATER SEAL ASSY (- 18 fl Fully 2.990 located. �, : Shot Dens Top (ftKB) lop (TVD) St. (ND) Bum (ftKB) (ftKB) (ftKB) (shotsn Zone Date 0 Type Com 14,584.5 14,623.0 6,252.8 6,253.8 2/13/2014 SLOTS Slotted Liner, Hydril-563 Pref Joint (36 Holes @ 12") Mandrel Inserts st ati on N Top (ftKB) Top (Typ) (ftKB) Make Model OD (in) Valve Latch Port Size TRO Run Serv, Type Type (in) (psi) Run Date Co. 11 2,830.0 1 2,611.9 CAMCO MMG 11/2 GAS LIFT JDIMY RK 1 0.0001 0.0 2/15/2014 21 4,619.41 3,814.3 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 2/15/2014 31 5,946.01 4,697.4 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 2/15/2014 4 6,898.31 5,329.8 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 2/15/2014 5 7,599.0 5,730.1 CAMCO MMG 11/2 GAS LIFT SOV RKP 0.000 0.0 2/152014 DCR-1 NOteS ,i3enerai\ ;Sefe£y End Date I Annotation NOTE: SLOTS; 14,584.5-14,623.0 LINER; 8,584.8-14,816.0 t ` Time Log & Summary ConocoPhillips We/!view Web Reporting Report r Well Name: 2E-04 Rig Name: DOYON 141 Job Type: DRILLING ORIGINAL Rig Accept: 1/4/2014 6:00:00 PM Rig Release: 2/17/2014 11:59:00 PM Time Logs Date From To Dur'' S. Depth E. Depth Phase Code Subcode T Comment 1/01/2014 24 hr Summary Rig release from 1 C-151. Wait on weather / truck removed from road 08:00 12:00 4.00 0 0 MIRU MOVE SVRG T Work on MP2's, weld water line between rig floor and choke house, MP2 top drive, grease blower motors, Test koomey bottles, mechanic made hydraulic repairs, inspect and clean brakes, inspected gear box and oilers, trollies, bolts, pins, shackles, safety wires and keepers. 12:00 21:00 9.00 0 0 MIRU MOVE SVRG T PJSM- Phase II weather. Assemble mud pumps, C/O lights on rig floor and dog house. Re-plumb water line from test pump.Blow down rig for move and prep for move. Switch to cold start power, un-plug electrical connects, steam and water service loops. Jack pipe sheds. Drove road to 2E to evaluate conditions, roads are in good condition. Called trucks to commence rig move. Called highline crew to drop power cable. 21:00 00:00 3.00 0 0 MIRU MOVE SVRG T PJSM, continue cleaning rig while waiting on Highline power crew to move cable at 1 C pad exit. Trucks arrived at 20:00. Highline crew called, cannot get a permit to move cable in Phase II weather. Sent trucks back to yard. D1/02/2014 Wait on highline crew and weather. 00:00 12:00 12.00 0 0 MIRU MOVE MOB T Wait on highline crew and weather. Weather degraded to Phase III. Rig working on MP2's, KPA's and procedures. 12:00 00:00 12.00 0 0 MIRU MOVE MOB T Wait on highline crew and weather. Weather improved to Phase I, called highline crew and drove road to 2E to evaluate. Access roads still in Phase III, turnoff at 2C and 2C pad drifted badly, wait for roads and pads to clean up area. Rig working on MP2's, KPA's and procedures. 1 /03/2014 Wait on highline crew and weather until 18:00. Higline disconnected from camp, trucks arrived at 19:00. 00:00 12:00 12.00 0 0 MIRU MOVE DMOB I T Wait on highline crew and weather. } Time Logs 'Date From To DurS.'De th E. De th`Phase' Code Subcode T' Comment 12:00 18:00 6.00 0 0 MIRU MOVE DMOB T Continue to wait on highline crew and weather. Highline arrived @ 17:00, disconnected camp and rolled wire out of road. Drive road out to 2E to evaluate conditions, acceptable. Tool house, Roads and pads will clean up 2C, 2D and 2E pad prior to move. 18:00 00:00 6.00 0 0 MIRU MOVE DMOB P Peak trucks arrived on location @ 19:30. PJSM with operators and rig crew. Separate support modules, and park on pad. Call DSO, Pull sub off well @ 22:00. Sub, pipe sheds and rockwasher left 1 C @ 23:00. D11/04/2014 Move rig to 2E-04, move camp to 2D pad. Rig up and accept rig @ 18:00. 00:00 02:30 2.50 0 0 MIRU MOVE MOB P Mobilize sub, pipe sheds and rockwasher from 1 C to 2E pad. 02:30 04:00 1.50 0 0 MIRU MOVE MOB P Spot sub over well 2E-04. 04:00 05:30 1.50 0 0 MIRU MOVE MOB P Mobilize power pack from 1C to 2E pad. 05:30 07:00 1.50 0 0 MIRU MOVE MOB P Prepare pad and lay containment and mats. 07:00 10:45 3.75 0 0 MIRU MOVE MOB P Spot power pack, pipe sheds and rockwasher. 10:45 12:00 1.25 0 0 MIRU MOVE MOB P Plug in electrical lines, hook up innerconnects. SIMOPS- work on rig acceptance checklist. 12:00 18:00 6.00 0 0 MIRU MOVE MOB P PJSM- Work on rig acceptance checklist. Test and calibrate gas alarms. 18:00 00:00 6.00 0 0 MIRU MOVE MOB P PJSM- N/U Diverter, take on spud mud. Rig accepted at 18:00 hrs. PJSM- Take on spud mud, spot Canrig shack, unload trucks, tools into pipe shed. Dl/05/2014 Rig up and function test diverter with AOGCC witness. P/U DP and HWDP. M/U BHA #1 and spud well in, drill to 170' MD. 00:00 08:00 8.00 0 0 MIRU MOVE RURD P PJSM- N/U diverter system, Install riser, take on spud mud, Load 5" drill pipe in pipe shed and strap. Mobilize lift subs to rig floor. 08:00 10:00 2.00 0 0 SURFA( WHDBO BOPE P Test diverter system, witness by AOGCC John Crisp. Knife valve open=10 sec, Annular diverter closed=24 sec. Accumulator test system pressure=2900 psi, Pressure after closed= 1800 psi, 200 psi attained=40 sec, Full pressure attained=172 sec. 5 bottle nitrogen average=2025 psi. Tested gas alarms. 10:00 12:00 2.00 0 0 SURFA( DRILL PULD P PJSM- P/U 5" drill pipe via mouse hole. 12:00 18:45 6.75 0 0 SURFA( DRILL PULD P PJSM- Continue P/U 5" drill pipe via mouse hole and stand back. L/D mouse hole and thread protectors. Time Logs Date From To " Dur S. De th E. De th Phase Code Subcode T Comment 18:45 19:15 0.50 0 0 SURFA( DRILL RURD P Clean and clear rig floor, measure RKB's. 19:15 20:30 1.25 0 0 SURFA( DRILL PULD P P/U bit from beaverslide, M/U BHA #1 per SLB rep. 20:30 21:00 0.50 0 0 SURFA( DRILL PRTS T Flood conductor, notice 4" conductor valve leaking, drain stack. 21:00 22:15 1.25 0 0 SURFA( DRILL EQRP T Blow down topdrive, fix 4" leak on conductor valve. SIMOPS re -attach SLB drawworks drill line encoder. (Unknown why it was removed) 22:15 22:45 0.50 0 107 SURFA( DRILL WASH P Tag ice plug @ 38' MD. Wash and ream ice to 107' MD. 22:45 00:00 1.25 107 170 SURFA( DRILL DRLG P Drill from 107' MD to 170' MD, 170' TVD. ART=1.25, ADT=1.25, Jars=O, Bit hrs=1.25, P/U=40k, S/0=43k, ROT=41k, Tq on/off=.5/.5, Flow out -75%, WOB=5-10k, RPM=30, 500 gpm @ 400 psi, Dl/06/2014 Drill to 222' MD with cleanout BHA #1, M/U BHA #2 and R/U Eline Gyro. Drill ahead, gyro every stand to 1 100'MD, released HES at 1200' MD, drill to 1305' MD. 00:00 01:00 1.00 170 222 SURFA( DRILL DRLG P Drill from 170' MD to 222' MD, ART=1.0, AST=O, ADT=1, Bit hrs=2.25, P/U=42k, S/O=43k, ROT=42k, Tq on/off=1/1k, 88% Flow out, WOB=5-8k, 40 rpm, 500 gpm @ 450 psi. 01:00 01:45 0.75 222 38 SURFA( DRILL TRIP P Circulate hole clean and POOH f/ 222' MD to 38' MD. Blow down top drive. 01:45 03:00 1.25 38 179 SURFA( DRILL PULD P PJSM, M/U BHA #2 per SLB. 03:00 04:15 1.25 179 179 SURFA( DRILL RURD P PJSM, R/U Eline and Gyrodata tools 04:15 05:30 1.25 179 222 SURFA( DRILL PULD P Continue making up BHA#2 per SLB 05:30 06:00 0.50 222 282 SURFA( DRILL DRLG P Drill from 222' MD, to 282' MD, 282' TVD. ART=. 11, AST=O, ADT=.11, Jar Hrs=59.8, Bit hrs=3.61, P/U=55k, S/0=53k, ROT=56k,Tq on/off= 1/1 k, 75% Flow out, WOB=5-7k, 50 rpm, 500 gpm @ 950 psi. 06:00 12:00 6.00 282 525 SURFA( DRILL DDRL P Directional drill from 282' MD, to 525' MD, 525' TVD. ART=2.45, AST=.67, ADT=3.12, Jar Hrs=59.8, Bit hrs=6.73, P/U=59k, S/0=62k, ROT=62k,Tq on/off= 1/1k, 80% Flow out, WOB=10-12k, 50 rpm, 575 gpm @ 1000 psi. Perform Gyro survey every stand. 12:00 13:30 1.50 525 651 SURFA( DRILL DDRL P Directional drill from 525' MD, to 651' MD, 650' TVD. ART=.53, AST=.28, ADT=.81, Jar Hrs=59.8, Bit hrs=7.54, P/U=63 k, S/0=65k, ROT=65k,Tq on/off= 2/1k, 87% Flow out, WOB=10-15k, 50 rpm, 575 gpm @ 1100 psi. Perform Gyro survey every stand. -_rv_ �_ Page 3 of 4 ^ Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T ! Comment 13:30 14:00 0.50 651 651 SURFA( DRILL RGRP T PJSM, change out top drive grabber dies due cracked die. Circulate @ 150 gpm to keep hole from packing off around BHA. 14:00 18:00 4.00 651 839 SURFA( DRILL DDRL P Directional drill from 651' MD, to 839' MD, 838' TVD. ART=.74, AST=.76, ADT=1.50, Jar Hrs=61.3, Bit hrs=9.04, P/U=73k, S/0=76k, ROT=76k,Tq on/off= 3.5/1 k, 86% Flow out, WOB=20-30k, 50 rpm, 550 gpm @ 1300 psi. Perform Gyro survey every stand. 18:00 00:00 6.00 839 1,305 SURFA( DRILL DDRL P Directional drill from 839' MD, to 1305' MD, 1296' TVD. ART=1.91, AST=1.62, ADT=3.53, Jar Hrs=64.83, Bit hrs=12.57, P/U=80k, S/0=80k, ROT=82k,Tq on/off= 3.5/1k, 84% Flow out, WOB=20-30k, 70 rpm, 600 gpm @ 1300 psi. Perform Gyro survey every stand to 1100' MD. Rig down HES Eline unit after 1200' MD and clean MWD surveys. Dl/07/2014 Drilling ahead from1305' MD - 2970' MD, 2707' TVD. Total daily footage 1665', ADT 12.32 00:00 05:00 5.00 1,305 1,858 SURFA( DRILL DDRL P Directional drill from 1305' MD, to 1858' MD, 1827' TVD. ART=1.26, AST=2.03, ADT=3.29, Jar Hrs=68.12, Bit hrs=15.86, P/U=95k, S/0=87k, ROT=93k,Tq on/off= 3-3/1.5k, 86% Flow out, WOB=10-20k, 70 rpm, 600 gpm @ 1550 psi. 05:00 07:00 2.00 1,858 1,858 SURFA( DRILL CIRC T While performing mud dilution weight and viscosity dropped causing hole to pack off and torque up. Circulate and condition spud mud. 07:00 12:00 5.00 1,858 2,228 SURFA( DRILL DDRL P Directional drill from 1858' MD, to 2228' MD, 2152' TVD. ART=.43, AST=1.96, ADT=2.39, Jar Hrs=70.51, Bit hrs=18.25, P/U=104k, S/0=89k, ROT=96k,Tq on/off= 5/3k, 86% Flow out, WOB=10-30k, 70 rpm, 600 gpm @ 1600 psi. 12:00 18:00 6.00 2,228 2,688 SURFA( DRILL DDRL P Directional drill from 2228' MD, to 2688' MD, 2472' TVD. ART=1.73, AST=1.65, ADT=3.38, Jar Hrs=73.89, Bit hrs=21.63, P/U=108k, S/0=90k, ROT=99k,Tq on/off= 6/4k, 82% Flow out, WOB=5-25k, 70 rpm, 650 gpm @ 2025 psi. zz � - .. Time ., Date = nm From "`Dur S. De th E. De th Phase Code ' §ubcode Tk' 18:00 00:00 6.00 2,688 2,970 SURFA( DRILL DDRL P Directional drill from 2688' MD, to 2970' MD, 2707' TVD. ART= 2.48, AST= .78, ADT= 3.26, Jar Hrs= 77.15, Bit hrs= 24.89, P/U= 111 k, S/O= 94k, ROT= 101 k,Tq on/off= 5/5k, 85% Flow out, WOB= 15-30k, 70 rpm, 700 gpm @ 2150 psi. Dl/08/2014 Drill from 2970' MD - TD @ 3827' MD, 3284' TVD. CBU 3X, BROOH to HWDP. 00:00 06:00 6.00 2,970 3,243 SURFA( DRILL DDRL P Directional drill from 2970' MD, to 3243' MD, 2892' TVD. ART= 4.28, AST= .41, ADT= 4.69, Jar Hrs= 81.84, Bit hrs= 29.58, P/U= 116k, S/O= 95k, ROT= 104k,Tq on/off= 6/4k, 87% Flow out, WOB= 20-25k, 70 rpm, 700 gpm @ 2200 psi, Max Gas = 300 Units. 06:00 10:00 4.00 3,243 3,525 SURFA( DRILL DDRL P Directional drill from 3243' MD, to 3525' MD,3083' TVD. ART= 2.33, AST= .19, ADT= 2.52, Jar Hrs= 84.36, Bit hrs= 32. 10, P/U= 118k, S/O= 97k, ROT= 107k,Tq on/off= 6-8/4k, 78% Flow out, WOB= 30-35k, 80 rpm, 650 gpm @ 1850 psi. 10:00 12:00 2.00 SURFA( DRILL SFTY P Conoco Phillips Alaska Safety Stand Down 12:00 16:45 4.75 3,525 3,827 SURFA( DRILL DDRL P Directional drill from 3525' MD, to 3827' MD,3284' TVD. ART= 3.72, AST= 0, ADT= 3.72, Jar Hrs= 88.08, Bit hrs= 35.82, P/U= 124k, S/O= 100k, ROT= 112k,Tq on/off= 6/4k, 87% Flow out, WOB= 15-30k, 70 rpm, 700 gpm @ 2150 psi. 16:45 17:00 0.25 3,827 3,827 SURFA( CASING SRVY P Ream 30', obtain torque & drag info, survey on bottom. 17:00 19:30 2.50 3,827 3,530 SURFA( CASING CIRC P CBU 3x @ 750 GPM = 2350 PSI, 70 RPM = 5-6K TQ, L/D single, Rack back stand per BU, P/U= 124K, S/O= 100K, ROT= 112K. 19:30 00:00 4.50 3,530 1,027 SURFA( CASING REAM P Back reaming from 3530' MD to 1027' MD, PJSM, 650 gpm, 1750 psi, 80 rpm, Tq. = 5K, P/U = 75K. Slowed pump rate to 550 gpm, 1000 psi, 70 rpm, Tq = 2K through permafrost. 31/09/2014 RIH to TD, circulate and condition for casing run. POOH, lay down BHA, and clear rig floor. Rig up Doyon casing equip, PJSM, RIH with 10.75" casing to 2300' MD as per detail. 00:00 00:15 0.25 1,027 749 SURFA( CASING REAM P Back reaming from 1027' MD to 749' MD, PJSM, 550 gpm, 1000 psi, 70 rpm, Tq = 1 K, Up = 75K, Dwn = 74K 00:15 00:45 0.50 749 749 SURFA( CASING CIRC P CBU 2X @ 550 gpm, 1000 psi, blow down TD. 00:45 02:15 1.50 749 3,807 SURFA( CASING TRIP P RIH from 740' MD to 3807' MD, Up=122K, Dwn=98k. Actual displacement 206bl, calculated 25.74Bbl. AN i1 Awk 'Time Logs Date From To Dur S. De th E. De' th,Phase Code Subcode T- Comment 02:15 02:30 0.25 3,807 3,827 SURFA( CASING REAM P Ream from 3807' to 3827' MD, 750 gpm, 2350 psi, 88% flow, 80 rpm, 5K Tq, Up=122K, Dwn=98K, Rot=125k. 02:30 08:15 5.75 3,827 3,530 SURFA( CASING CIRC P Circulate and condition from 3827' to 3530' MD, 750 gpm, 2350 psi, 88% flow, 80 rpm, 5K Tq, Up=122K, Dwn=98K, Rot=125k. Reduce rate to 550 gpm, 1350 psi, 80% flow, Blow down TD. 08:15 08:45 0.50 3,530 3,530 SURFA( CASINGOWFF P Monitor well (static). 08:45 10:00 1.25 3,530 749 SURFA( CASING TRIP P POOH from 3530' to 749' MD, Up=75K, Dwn=74k. 10:00 11:00 1.00 749 101 SURFA( CASING TRIP P POOH from 749' to 101' MD, stand back HWDP, Jars, & NMFC. 11:00 13:00 2.00 101 0 SURFA( CASING TRIP P Lay down BHA # 2 as Schlumberger. Actual displacement 42.84Bbl, Calculated 37.24Bbl. 13:00 14:15 1.25 0 0 SURFA( CASING TRIP P Clear floor of BHA and clean rig floor. 14:15 15:15 1.00 0 0 SURFA( CASING SFTY P Safety stand down. Discuss recent incident and initiate hazard hunt. 15:15 18:15 3.00 0 0 SURFA( CASING RURD P PJSM, rig up Doyon casing equipment. 18:15 22:00 3.75 0 1,460 SURFA( CASING RNCS P PJSM, RIH from surface to 1460', Dwn 70K 22:00 22:45 0.75 1,460 1,460 SURFA( CASING CIRC P Circulate casing volume, stage up pumps 2-5 bpm, 200-250 psi, 45-70% flow. 22:45 00:00 1.25 1,460 2,306 SURFA( CASING RNCS P RIH from 1460' to 2306' MD, Jt # 58, Dwn 90K. Actual displacement 47.6, calculated 37.11 Bbl. 31/10/2014 Circulate and condition for cement. Perforn cement as per well plan for 10.75" casing. Rig down surface equipment and rig up well head / BOPE. 00:00 00:30 0.50 2,306 2,709 SURFA( CASING RNCS P RIH with 10.75" casing from 2306' - 2709' MD. 00:30 01:30 1.00 2,709 2,709 SURFA( CASING CIRC P Circulate & condition at 3 bpm, 290 psi, 37% flow. 01:30 03:00 1.50 3,783 SURFA( CASING RNCS P RIH from 2709'- 3783' MD, 56 centrilizers used. 03:00 03:45 0.75 3,783 3,816 SURFA( CASING RURD P Make up landing Jt. and hanger. Land at 3816.27' MD. Lay down Franks tool and blow down TD. Make up cement head and rig up to circulate through cement line. 03:45 09:30 5.75 3,816 3,816 SURFA( CEMEN- CIRC P Circulate and conditon for cement. Stage up pumps 2-7 bpm, 300 -380 psi, 28 - 55% flow, up 198K, dwn 135K. 09:30 09:45 0.25 3,816 3,816 SURFA( CEMEN- SFTY P PJSM for cementing 10.75 casing. 09:45 10:45 1.00 3,816 3,816 SURFA( CEMEN" CMNT P Batch up cement as per SLB Rep. k Ank Time Logs Date From To Dur S.'De th E. De th Phase . Code ` Subcode T < Comment 10:45 15:00 4.25 3,816 3,816 SURFA( CEMEN' CMNT P Pump 10Bbls cw100 spacer, shut down and psi test lines t/ 350-3000 psi (good). Pump 40Bbls. CW100 chem wash spacer, mix and pump 50BbIs. 10.5 ppg mud push. Shut down and drop first plug, then chase w/ 521 Bbls of 11.0ppg ALC lead cement. Followed by 626b1s of 12.Oppg LiteCRETE tail cement. Shut down drop second plug w/ 10Bbls. of H2O. Displace cement with rig pumps w/ 9.6ppg mud @ 7 bpm, 550 psi, 61% flow. Reduce rate to 3 bpm to bump plug at 3440 strokes. Pressure up to 1100 psi and hold for 5 min. Check floats (good). 15:00 15:45 0.75 3,816 3,816 SURFA( CEMEN' CMNT P Flush stack w/ 30BbI of black water 2X 15:45 17:30 1.75 3,816 3,816 SURFA( CASING RURD P PJSM, rig down cement equipment and lay down landing joint. 17:30 18:45 1.25 3,816 3,816 SURFA( CASING RURD P Drain stack and lay down surface riser in pipe shed. 18:45 21:30 2.75 3,816 3,816 SURFA( CASING NUND P PJSM, clean & rig down surface BOPE. 21:30 23:00 1.50 3,816 3,816 SURFA( CASING NUND P Rig up casing spool. FMC test metal to metal seals to 1000 psi for 10 min, tested good. 23:00 00:00 1.00 3,816 3,816 SURFA( CASING NUND P Rig up tubing spool and remove 4" valves on conductor. 1/11/2014 Finish nippling up BOPE. Tested BOPE 250-3500 psi. Picked up drill pipe for next hole section. Made up BHA #3 and singled in the hole to 3232' MD. 00:00 01:00 1.00 0 0 SURFA( CEMEN- NUND P N/U wellhead equipment as per FMC 01:00 08:00 7.00 0 0 SURFA( CEMEN' NUND P N/U BOPE, clear rig floor, and pick up FMC equipment. Added 7" to riser. 08:00 09:30 1.50 0 0 SURFA( CEMEN- RURD P Rig up test equipment for BOPE test. 09:30 13:00 3.50 0 0 SURFA( CEMEN' BOPE P Test BOPE to 250 psi and 3500 psi w/5" test joint. #1 top pipe rams; CMV's 1,12,13,14; and manual kill line valve. #2 upper IBOP; CMV's 9 & 11. #3 lower IBOP & CMV's 5,8,10. #4 dart valve & CMV's 4,6,7. #5 FSV & CMV 2. #6 HCR choke & 4" kill line Demco. #7 Manual choke vavle & HCR kill. #8 Annular. #9 lower pipe rams. #10 Blind rams & CMV 3. Initial sys. psi 3000 psi. Psi after closing 1850 psi. Attained 200 psi at 37 seconds. Full psi attained at 157 seconds. Nitrogen bottles psi averaged 1975 psi. Test waived By Chuck Scheve 13:00 13:45 0.75 0 0 SURFA( CEMEN' RURD P Rig down test equipment. 777 �fi,, Time Logs Date From To Dur S.':De th E. De th Phase Code Subcode T Comment 13:45 14:00 0.25 0 0 SURFA( CEMEN' RURD P Drift wear bushing ID to bit OD 9.875" ID. Wear bushing ID 9.8125". Lay down wear bushing. 14:00 14:30 0.50 0 0 SURFA( CEMEN- RURD P Rig up to pick up 5" DP in the mouse hole. 14:30 14:45 0.25 0 0 SURFA( CEMEN- PULD P Pick up 5" DP in mouse hole. 14:45 15:00 0.25 0 0 SURFA( CEMEN RURD P Pick up wear bushing ID 10" and drift with bit. Install wear bushing. 15:00 15:15 0.25 0 0 SURFA( CEMEN- RURD P Lay down mouse hole and pick up mule shoe. 15:15 17:15 2.00 0 0 SURFA( CEMEN- PULD P Single 42 joints of 5" DP in hole and stand back in derrick. 17:15 18:00 0.75 0 0 SURFA( CEMEN- PULD P Clear rig floor and stage BHA on the floor. 18:00 20:30 2.50 0 733 SURFA( CEMEN TRIP P RIH from surface to 733' MD. Pick up BHA and load nukes as per SLB 20:30 21:15 0.75 733 1,411 SURFA( CEMEN'TRIP P RIH from 733'to 1411' MD. Single, drill pipe in the hole from shed. 21:15 21:45 0.50 1,411 1,411 SURFA( CEMEN' DHEQ P Shallow test SLB BHA, 450 gpm, 800 psi. 21:45 00:00 2.25 1,411 3,232 SURFA( CEMEN-TRIP P RIH from 141 V to 3232' MD, up 115k, dwn 87k. Calculated displacement 39.81 Bbls. Actual 39.5 Bbls. DI/12/2014 Drill out shoe track and 20' of new hole to preform FIT to 14.7 ppg EMW. Displace mud system to 9.5 ppg Kla-shield system. Drill ahead from 3847' to 5098' MD as per SLB. 00:00 00:45 0.75 3,232 3,633 SURFA( CEMEN' TRIP P I RIH picking up singles from 3232' to 3633' MD, up 115k, dwn 87k. 00:45 01:30 0.75 3,633 3,633 SURFA( CEMEN- CIRC P Circulate B/U with 600 gpm, 1650 psi, 72% flow. 01:30 01:45 0.25 3,633 3,633 SURFA( CEMEN' RURD P Rig up to test 10.75" casing 01:45 02:15 0.50 3,633 3,633 SURFA( CEMEN- PRTS P Test 10.75" surface casing to 3000 psi for 30 min and chart tfie same. 02:15 02:30 0.25 3,633 3,603 SURFA( CEMEN- RURD P Rig down test equipment and lay down a single. 02:30 02:45 0.25 3,603 3,695 SURFA( CEMEN TRIP P RIH from 3603' to 3695' MD. 02:45 03:15 0.50 3,695 3,741 SURFA( CEMEN- REAM P Wash and ream from 3695' to 3741' MD at 500 gpm, 1200 psi, 65% flow, 70 rpm, 5-9K tq. 03:15 06:45 3.50 3,741 3,827 SURFA( CEMEN"DDRL P Drill out shoe track from 3741'- 3827' MD at 500 gpm, 1200 psi, 65% flow, 70 rpm, 4-9K tq. 06:45 07:00 0.25 3,827 3,847 SURFA( CEMEN' DDRL P Drill from 3827'- 3847' MD, 3295 TVD, 500 gpm, 1200 psi, 65% flow, up 130K, dwn 90K, rot 110K, 70 rpm, tq on/off 4-9/4-8, WOB 0-5K, ECD 10.22. 07:00 07:30 0.50 3,847 3,847 SURFA( CEMEN- CIRC P Circulate B/U with 500 gpm, 1200 psi, 65% flow, 70 rpm, tq 4-8K. 07:30 08:30 1.00 3,847 3,847 SURFA( CEMEN- FIT P Rig up and preform FIT 3847' MD, 3295' TVD, 9.5 ppg MW to a 14.7 _ ppg EMW_. Rig down & blow down all lines. X � `` dime logs Date From To Dur S. De th E. De th Phase Code `' Subcode T Comment 08:30 10:00 1.50 3,847 3,847 INTRM1 DRILL CIRC P Dispalce spud mud to Kla-sheild 9.5 ppg mud at 5.5-7 bpm,400-500 psi, 46-50% flow, 80 rpm, 6-91K tq. New SPR's. 10:00 10:15 0.25 3,847 3,847 INTRM1 DRILL CIRC P Increase in cuttings with new mud, continue cirulating till cuttings decreased. 10:15 12:00 1.75 3,847 3,969 INTRM1 DRILL DDRL P Drill from 3847'- 3969' MD, 3376' TVD, 675 gpm, 1700 psi, 71% flow, up 132K, dwn 132K, rot 110K, 130 rpm, tq on/off 5-8/5-8, WOB 10K, ECD 10.37. ART .76, ADT .76, Jars 89.04, Bit .96 12:00 18:00 6.00 3,969 4,562 INTRM1 DRILL DDRL P Drill from 3969'- 4562' MD, 3791' TVD, 690 gpm, 1800 psi, 72% flow, up 131K, dwn 102K, rot 115K, 150 rpm, tq on/off 6-7/4, WOB 10-15K, ECD 10.42. ART 4.82, ADT 4.82, Jars 93.86, Bit 4.82 18:00 00:00 6.00 4,562 5,082 INTRMI DRILL DDRL P Drill from 4562'- 5082' MD, 4125' TVD, 690 gpm, 1825 psi, 74% flow, up 145K, dwn 106K, rot 120K, 150 rpm, tq on/off 7-8/6, WOB 18-23K, ECD 10.42. ART 3.87, ADT 3.87, Jars 97.73, Bit 9.65 1/13/2014 Replace brake bands on drawworks. Drill ahead from 5082' to 6298' MD as per SLB. 00:00 01:00 1.00 5,082 5,082 INTRMI DRILL CIRC T Circulate BU 2X @ 690 gpm, 1825 psi, 74% flow, 130 rpm, 6k tq. 01:00 01:30 0.50 5,082 5,082 INTRM1 DRILL OWFF T I Monitor the well. Static. 01:30 02:00 0.50 5,082 3,788 INTRM1 DRILL TRIP T POOH from 5082'- 3788' MD, 130k up, 95k dwn 02:00 02:30 0.50 3,788 3,788 INTRM1 DRILL OWFF T Monitor the well at the shoe. Clean rig floor and prep for changing brakes. 02:30 05:45 3.25 3,788 3,788 INTRMI DRILL RGRP T Change out brake bands. 05:45 06:45 1.00 3,788 3,788 INTRM1 DRILL SLPC P Slip and cut drill line, 6 wraps, 37'. 06:45 07:00 0.25 3,788 3,788 INTRM1 DRILL SFTY T PJSM trip in the hole. 07:00 07:45 0.75 3,788 4,992 INTRM1 DRILL TRIP T RIH form 3788'- 4992' MD, 130k up, 95k dwn. 07:45 08:00 0.25 4,992 5,082 INTRMI DRILL REAM T Wash & ream from 4992'- 5082' MD, @ 690 gpm, 1825 psi, 74% flow, 130 rpm, 6k tq. 08:00 12:00 4.00 5,082 5,359 INTRM1 DRILL DDRL P Drill from 5082'- 5359' MD, 4310' TVD, 690 gpm, 1975 psi, 75% flow, up 141 K, dwn 113K, rot 126K, 150 rpm, tq on/off 7/7, WOB 20-25K, ECD 10.52. ADT 2.69, Jars 100.42, Bit 12.43 12:00 18:00 6.00 5,359 5,822 INTRM1 DRILL DDRL P Drill from 5359'- 5822' MD, 4659' TVD, 701 gpm, 2100 psi, 77% flow, up 160K, dwn 115K, rot 135K, 140 rpm, tq on/off 8-9/7, WOB 20-25K, ECD 10.46. ADT 5.17, Jars 105.59, Bit 17.51 o. G.M„? Pti orPVii' ) 116; From To Dur! .pie i "� ii itase Codes Subcode � ai�ent �n, °I1-1 ` - 18:00 00:00 6.00 5,822 6,298 INTRM1 DRILL DDRL P Drill from 5822'- 6298' MD, 5016' TVD, 740 gpm, 2300 psi, 77% flow, up 170K, dwn 121 K, rot 139K, 150 rpm, tq on/off 10/7, WOB 10-15K, ECD 10.42. ADT 4.42, Jars 110.01, Bit 21.93 )1/14/2014 Drill to core point 7425' MD. Circulate B/U 3X. Back ream to 5820' MD and circulate B/U 2X to clean up hole. POOH on elevators to 4855', pull 30K over. RIH to 5085' and circulate B/U 2X. 00:00 06:00 6.00 6,298 6,728 INTRM1 DRILL DDRL P Drill from 6298'- 6728' MD, 5432' TVD, 725 gpm, 2500 psi, 80% flow, up 190K, dwn 132K, rot 154K, 150 rpm, tq on/off 12/9, WOB 10-15K, ECD 10.65. ADT 4.59, Jars 114.60, Bit 26.52 06:00 12:00 6.00 6,728 7,290 INTRM1 DRILL DDRL P Drill from 6728'- 7290' MD, 5987' TVD, 725 gpm, 2550 psi, 76% flow, up 210K, dwn 140K, rot 162K, 150 rpm, tq on/off 12/11, WOB 15-25K, ECD 11.05. ADT 4.46, Jars 119.06, Bit 30.98 12:00 14:30 2.50 7,290 7,425 INTRM1 DRILL DDRL P Drill from 7290'- 7425' MD, 6120' TVD, 725 gpm, 2650 psi, 76% flow, up 215K, dwn 138K, rot 165K, 150 rpm, tq on/off 13/12, WOB 3-7K, ECD 11.17. ADT 1.93, Jars 120.99, Bit 32.91 14:30 16:45 2.25 7,425 7,425 INTRM1 DRILL CIRC P Circulate B/U 3X @ 715 gpm, 2600 psi. Weight up from 10.2 to 10.5 ppg. 16:45 17:15 0.50 7,425 7,425 INTRM1 DRILL OWFF P Monitor well. Static 17:15 20:30 3.25 7,425 5,820 INTRMI DRILL REAM P BROOH form 7425'- 5820' MD, 715 gpm, 2600 psi, 150 rpm, 6-71K tq. 20:30 21:30 1.00 5,820 5,733 INTRM1 DRILL CIRC P Circulate B/U 2X for hole to clean up, from 5820'- 5733' MD @ 715 gpm, 2450 psi, 150 rpm, 6-7K tq. Rack back stand on B/U. 21:30 22:00 0.50 5,733 5,733 INTRM1 DRILL OWFF P Monitor well. Static 22:00 23:00 1.00 5,733 4,855 INTRM1 DRILL CIRC P POOH from 5733'- 4855' MD, 145K up, 98K dwn. Pull 30K over at 4855', wipe 2X with no progress. 23:00 00:00 1.00 4,855 5,085 INTRM1 DRILL CIRC P RIH 4856- 5085', Circulate B/U 2X @ 730 gpm, 2450 psi, 150 rpm, 6K tq, 145K up, 98K dwn. Rack back one stand at B/U. DI/15/2014 CBU @ 4992'. POOH on elevators 2 stands. Pull tight. Pump out to shoe. CBU inside casing. Monitor well. Static. TIH to bottom. Ream last stand. CBU 3 x's, until shakers cleaned up. Displace well to 11 ppg core fluid from 10.7 ppg WBM (Klashield). Add tracer to system. Circulate surface to surface 3 x's. POOH and lay down BHA #3. 00:00 00:30 0.50 5,085 4,992 INTRM1 DRILL CIRC P Continue to circulate the hole clean, 730 gpm, 2250 psi, flow 80%, 150 rpm, Tq 6.5k. Swab blew on MP#2. Finish circulating @ 440 gpm, 1000 psi, 69% flow, 150 rpm. Page 10 0 r-4 Time Logs Date From To Dur'S. De th E De th Phase Code Subcode T Comment 00:30 01:00 0.50 4,992 4,745 INTRM1 DRILL TRIP P Pull 2 stands on elevators. Pulled tight, 30k over. Work string with no relief. Begin back reaming out with one pump. 01:00 03:00 2.00 4,745 3,788 INTRMI DRILL REAM P Back ream into casing. 435 gpm, 950 psi, 150 rpm, 5 to 9k Tq. 69% flow. 03:00 03:45 0.75 3,788 3,788 INTRM1 DRILL CIRC P CBU inside the 10%" surface casing. 435 gpm, 900 psi, 69% flow, 70 rpm. Blow down top drive. 03:45 04:30 0.75 3,788 3,788 INTRMI DRILL OWFF P Observe the wellbore. Static. Service rig. 04:30 05:15 0.75 3,788 5,208 INTRMI DRILL TRIP P Trip in the hole from 3788' to 5208'. Tagged up on a tight spot @ 5208'. took 20k down weight twice. 05:15 05:30 0.25 5,208 5,270 INTRM1 DRILL REAM P Ream from 5178' to 5270'. 600 gpm, 1800 psi, 120 rpm, 7k Tq. 74% flow. 05:30 06:30 1.00 5,270 7,379 INTRM1 DRILL TRIP P Trip in the hole on elevators. 5270 to 7379' MD. Encountered a tight spot.Actual displacement 24 bbls, calculated displacement 30 bbls. 06:30 06:45 0.25 7,379 7,425 INTRM1 DRILL REAM P Ream to bottom @ 7425' MD. 500 gpm, 1500 psi, 120 rpm, 12k torque. 06:45 08:45 2.00 7,425 7,425 INTRM1 DRILL CIRC P Circulate the hole clean. The shakers cleaned up after 3 BU strokes. 600 gpm, 2100 psi, 150 rpm, 12 k tq, 77% flow. 08:45 09:00 0.25 7,425 7,425 INTRMI DRILL SFTY P PJSM. Displacing the Klashield 10.7 ppg to Core fluid 11 ppg. 09:00 12:15 3.25 7,425 7,425 INTRMI DRILL CIRC P Displace out 10.7 ppg Klashield drilling fluid to 11 ppg Coring fluid. 4 bpm, 450 psi, 49% flow, 120 rpm, 12k tq, FCP=610 psi. 12:15 12:45 0.50 7,425 7,425 INTRM1 DRILL CIRC P Circulate core fluid 11 ppg back to pits. Take on another 100 bbls of core fluid 11 ppg to pits. Increase pump rate to 500 gpm at 2100 psi. 12:45 16:15 3.50 7,425 7,120 INTRMI DRILL CIRC P Add tracer fluid to active system, CBU 3X @ 500 gpm, 2100 psi, 120 rpm, 11-13K tq, 155K up, 159K dwn, 161 K rot. Rack back one stand at each surface to surface stks. 16:15 16:45 0.50 7,120 7,120 INTRMI DRILL OWFF P Monitor well before tripping. (Static) 16:45 19:30 2.75 7,120 3,776 INTRM1 DRILL TRIP P POOH on elevators from 7120' - 3776' M D. 19:30 20:00 0.50 3,776 3,776 INTRMI DRILL OWFF P Monitor well at the shoe. (Static) 20:00 21:15 1.25 3,776 764 INTRM1 DRILL TRIP P POOH on elevators form 3776'- 764' MD. 21:15 21:30 0.25 764 764 INTRMI DRILL OWFF P Monitor well at the HWDP. (Static) 21:30 22:15 0.75 764 82 INTRM1 DRILL TRIP P Stand back HWDP and NMFC. 22:15 23:00 0.75 82 82 INTRMI DRILL PULD P PJSM and lay down sources. 23:00 00:00 1.00 82 46 INTRMI DRILL PULD P Continue to lay down BHA Displacement for the trip calculated 67.85, actual 79.15. A �t --- Time Logs Date From To Dur < S. De th E. Depth Phase Code - Subcode T Comment 1/16/2014 24 hr summary Lay down drilling BHA#3. All tools in good shape. Pick up Core BHA#4. TIH filling pipe every 20 stands to bottom. CBU. When starting to core, encountered losses up to 90 BPH. Pulled off bottom and reduced pump rate to manage losses, while making more coring fluid. Start coring with 200 bbls of core mud in pits and 290 in route from MI plant. Core from 7425' to 7430' MD. Losses decreased to 6 BPH at 24:00. 00:00 00:15 0.25 46 46 INTRM1 DRILL PULD P Continue to lay down SLB drilling BHA#3 as per DD. 00:15 00:45 0.50 46 46 INTRM1 DRILL PULD P I Check seals on Power Drive 00:45 01:15 0.50 46 0 INTRM1 DRILL PULD P Finish laying down BHA #3 as per DD. 01:15 02:15 1.00 0 0 INTRM1 DRILL PULD P I Clear and clean rig floor. 02:15 02:30 0.25 0 0 INTRM1 DRILL SFTY P PJSM for picking up coring BHA. 02:30 02:45 0.25 0 0 INTRM1 DRILL PULD P Pick up coring tools to rig floor. 02:45 04:45 2.00 0 104 INTRMI DRILL PULD P Pick up coring assembly as per Baker Rep. 04:45 05:45 1.00 104 756 INTRM1 DRILL TRIP P RIH from 104'- 756' MD, with NMFC's and HWDP. 05:45 09:30 3.75 756 7,239 INTRM1 DRILL TRIP P RIH from 756'- 7239' MD, 165k up, 115k dwn, fill every 20 stands. Displacement calculated 70.51, actual 67.2 bbl. 09:30 10:15 0.75 7,239 7,425 INTRM1 DRILL REAM P Wash & ream from 7239'- 7425' MD, 290-300 gpm, 1000-1050 psi, 64-65% flow, 20 rpm, 10k tq. 10:15 10:30 0.25 7,425 7,425 INTRMI DRILL CIRC P Drop the ball and pump down @ 200 gpm, 700 psi, 56% flow, 210k up, 130k dwn, 158k rot, xx rpm, 14k tq. SPR's @ 7425' MD) 10:30 12:00 1.50 7,425 7,425 INTRMI DRILL CIRC P CBU @ 300 gpm, 1350 psi, 65% flow, 20 rpm, 15k tq. 12:00 12:15 0.25 7,425 7,425 INTRM1 DRILL PULD P Lay down single and make up next stand 12:15 14:15 2.00 7,425 7,431 INTRM1 DRILL CORE P Coring from 7425'- 7431' MD, 200 gpm, 1025 psi, 20k WOB, 70 rpm, 11-14k tq. Parameters prior to coring 210k up, 130k dwn, 130k rot, 50 rpm, 11-14k tq. 14:15 15:00 0.75 7,431 7,428 INTRM1 DRILL CIRC P Losses down hole 200 gpm @ 90 BPH, reduced rate to 100 gpm @ 6 BPH. Pick up off bottom, took 35k over pull to break core off, and rack back the stand. 15:00 16:00 1.00 7,428 7,428 INTRMI DRILL CIRC P Circulate at 42 gpm, 250 psi, losses @ 4 BPH. 16:00 22:15 6.25 7,428 7,374 INTRM1 DRILL CIRC P Rack back a stand 7428'- 7374' MD, 42 gpm, 300 psi, 15 rpm, 11-14k tq, losses @ 2 bph. Clean pit 3 & build 2 - 80 bbl batches of core mud, MI building 290 bbl to truck to location. 22:15 22:30 0.25 7,374 7,428 INTRMI DRILL WASH P Wash from 7374'- 7428' MD, 160 gpm, 700 psi, 40 rpm, 12-15k tq, 180k up, 143k dwn. Page 12 of 44 Time Logs Date From To Dur" S. De th E. De th'Phase Code Subcode TComment 22:30 00:00 1.50 7,431 7,432 INTRM1 DRILL CORE P Coring from 7431'- 7432' MD, 180 gpm, 900 psi, 80 rpm, 11-15k tq, 20k WOB. 6 BPH losses @ 24:00. 68bbls lost last 12 hrs. 1/17/2014 Continue coring. From 7430' to 7510' MD. 220 gpm, 1080 psi, 20k wob, 80 rpm, 54% flow. 00:00 12:00 12.00 7,432 7,475 INTRM1 DRILL CORE P Coring from 7432'- 7475' MD,Using varying flow rates from 180 to 220 gpm, 900 psi to 1100 psi, 80 rpm, 11-15k tq, 20k WOB.3 BPH losses @ 12:00. 37 bbls lost last 12 hrs. 12:00 00:00 12.00 7,475 7,510 INTRM1 DRILL CORE P Coring from 7475'- 7510' MD, 200 gpm, 1200 psi, 80 rpm, 8-12k tq, 20-22k WOB 84.25 Bbls losses for 12 hrs. 121.25 Bbls losses for 24 hrs. Dl/18/2014 Finish coring 90 feet. Core from 7510' to 7515'. Stand back one stand. Phase 3 conditions called. Monitor the well. Wellbore breathing. Monitor 2.5 hrs. 1 st hr gain 6.4 bbls. 2nd hr gain 2.1 bbls. last half hr gained .4 bbl. Circulate @ 1.5 bpm, wait on weather. Lay down three singles in pipe shed. Pump @ 1.5 bpm. 00:00 01:45 1.75 7,510 7,515 INTRM1 DRILL CORE P Coring from 7510'- 7515' MD, 200 gpm, 1200 psi, 80 rpm, 8-12k tq, 20-22k WOB. 01:45 04:00 2.25 7,515 7,515 INTRM1 DRILL CIRC P Shut down rotary. Break off core with 15k over pull. CBU W/ 200 gpm, 1000 psi, P/U wt= 215k, S/O = 130k, Max gas units=45. 04:00 04:30 0.50 7,515 7,515 INTRM1 DRILL OWFF P Phase 3 conditions called @ 03:00 Hrs. Break off pup joint, and blow down TD. Monitor well, slight flow. 04:30 05:00 0.50 7,515 7,415 INTRM1 DRILL TRIP T Pump out 1 stand from 7515' to 7415' MD, 200 gpm, 950 psi, 215k up, 130k dwn. Blow down top drive. 05:00 07:45 2.75 7,415 7,415 INTRM1 DRILL OWFF T Observe wellbore. Bit depth 7515'. Inside the 9 7/8" hole. Establish wellbore breathing, taking readings every 5 mins. Synopsis: 6.4 bbl gain 1st hr./ 2.1 bbl gain 2nd hr./.4 bbl gain last half hour. 07:45 12:00 4.25 7,415 7,415 INTRM1 DRILL CIRC T Break circulation @ 2 BPM. 600 psi, Rot 20 rpm, TQ 11-14k, reciprocate, rotate every half hour. Slow pump to 1.5 bpm. Total losses for tour=10.3 bbls. 12:00 12:15 0.25 7,415 7,330 INTRM1 DRILL PULD T Lay down 3 joints of DP from 7415'- 7330' MD 12:15 17:30 5.25 7,330 7,330 INTRM1 DRILL CIRC T Circulate at 64 gpm, 500 psi, 215k up, 125k dwn. Add 3 BPH H2O to reduce mud weight to 11. 1, working the string every 30 minutes due to weather conditions Page 13 of 44 ... Time Logs Date From To Dur S. De th E. De th'Phase Code Subcode TComment 17:30 00:00 6.50 7,330 7,330 INTRM1 DRILL CIRC T Circulate at 64 gpm, 500 psi, 215k up, 125k dwn. Working the string every 30 minutes due to weather conditions. SPR @ 7318'M D, 6120 TVD, 11.1 MD, 23:30 Hrs. #1 20 spm = 660 psi, 30 spm = 850 psi #2 20 spm = 670 psi, 30 spm = 830 Psi Dl/19/2014 Pumped out of the hole to the HWDP, due to hole swabbing. Followed pull rate schedule as per well plan.Pulled HWDP on elevator with correct displacement. 00:00 01:00 1.00 7,330 7,330 INTRM1 DRILL CIRC T PJSM. Continue to circulate, reciprocate pipe. 1.5 bpm, 500 psi. Wait on weather. 01:00 02:30 1.50 7,330 7,330 INTRM1 DRILL CIRC T Increase flow rate to 180 gpm to CBU. 1000 psi. At 2950 strokes started losing fluid @ 40 bph. Slow pump down to 1.5 bpm, 500 psi, flow rate still dropping. Shut down pump. 02:30 03:30 1.00 7,330 7,330 INTRM1 DRILL OWFF T Observe well, dropping. Place well on trip tank. Establish loss rate @ 3 bph. 03:30 04:00 0.50 7,330 7,330 INTRM1 DRILL OWFF P Phase 3 conditions lifted. Road opened to Kuparuk.Perform slow pump rartes.7320' MD. 6045' TVD. MW=10.9 ppg.Time 03:30 hrs. 1) 20-600, 30-780. 2) 20-640, 30-790. Monitor wel,l dropping. 04:00 05:45 1.75 7,330 6,868 INTRM1 DRILL TRIP P PJSM. POOH on elevators. P/U 215k, S/O 130k, Hole started swabbbing. Gained one barrel. Monitor the well. Dropping in 15 mins. 05:45 07:30 1.75 6,868 6,313 INTRM1 DRILL TRIP P PJSM. Pump out of the hole. 2 bpm. 800'/hr. Lost 21 bbls. 07:30 08:15 0.75 6,313 6,313 INTRM1 DRILL OWFF P Blow down top drive, Monitor well. Went static in 30 mins. Pull on elevators 20 feet. Swabbing. Line up to continue to pump out. 08:15 13:45 5.50 6,313 3,813 INTRM1 DRILL TRIP P Pump OOH. From 6313' to 3812' MD. 1 bpm, 900'/hr. 13:45 14:45 1.00 3,813 3,807 INTRM1 DRILL OWFF P Monitor well at shoe 3807' MD, slight flow f/15 min, flow stopped, monitored for 45 min. 117k up, 90k dwn. 14:45 21:15 6.50 3,807 837 INTRM1 DRILL TRIP P Pump OOH from 3807'- 837' MD, pulling speed as per well plan, 50 gpm, 300 psi. 21:15 21:30 0.25 837 837 INTRM1 DRILL OWFF P Monitor well at the HWDP. (Static) 21:30 00:00 2.50 500 TRIP P POOH on elevators from 837' - 500' 1837 1 JINTRM11DRILL MD, pulling speed as per well plan. ilV1 r� him Bate From To f DurS. Depth E. Depth Phase Code' Subcode T Comment"����11.. 1/20/2014 24 hr Summary POOH on elevators from 208' to 95'. Lay down core and core assembly, process, & ship to Anch. Pick up BHA #5 & RIH to shoe. Service rig & make repairs to inertia brake. RIH to 7364' MD filling pipe every 20 stands. CBU trying to minimize losses. 00:00 01:15 1.25 500 95 INTRM1 DRILL TRIP P PJSM. POOH on elevators from 500' to 95'. Calc fill=9.9 bbls, Actual fill=11.1 bbls 01:15 05:00 3.75 95 0 INTRM1 DRILL PULD P PJSM. Set up and gamma ray inner core barrel. Lay down core, lay down outer core barrel. BHA#4 05:00 08:30 3.50 0 0 INTRM1 DRILL RURD P Clear and clean rig floor. Lay down coring tools, SIMOPS: Cut and prep core for shipment, add mud to active system from rock washer. Load core into heated van. Organize and de -construct coring station in pipe shed. Remove coring equipment from shed. Prepare SLB tools for BHA#5. Repair iron roughneck. 08:30 10:00 1.50 0 106 INTRM2 DRILL PULD P PJSM. Pick up BHA#5 to 106'. 10:00 10:30 0.50 106 106 INTRM2 DRILL SFTY P PJSM. Load nuclear sources. 10:30 12:00 1.50 106 796 INTRM2 DRILL PULD P Continue to pick up BHA#5 to 796' MD. Calc fill= 19.3 bbls, Actual fill=20.2 bbls. 12:00 12:15 0.25 796 1,250 INTRM2 DRILL TRIP P RIH from 796'- 1250' MD, 12:15 12:30 0.25 1,250 1,250 INTRM2 DRILL CIRC P Shallow hole test MWD at 1250' MD, 400 gpm, 1000 psi, blow down TD. 12:30 14:45 2.25 1,250 3,750 INTRM2 DRILL TRIP P RIH on elevator from 1250' - 3750', (shoe) 86k dwn 14:45 15:45 1.00 3,750 3,750 INTRM2 DRILL SVRG P Service TD & lubricate rig. Monitor well breathing 1hr. 15:45 16:15 0.50 3,750 3,750 INTRM2 DRILL SFTY P Safety stand down, discuss incident at SDU. 16:15 17:45 1.50 3,750 3,750 INTRM2 DRILL RGRP T Repair drawworks inertia brake. C/O contacts on SCRS) 17:45 18:15 0.50 3,750 4,215 INTRM2 DRILL TRIP P RIH from 3750'- 4215' MD, 18:15 18:30 0.25 4,215 4,215 INTRM2 DRILL CIRC P Test power drive circulating at 450 gpm, 1700 psi. Blow down TD. 18:30 19:30 1.00 4,215 6,075 INTRM2 DRILL TRIP P RIH from 4215'- 6075' MD, 96k dwn. Fill pipe every 20 stands. 19:30 20:15 0.75 6,075 6,075 INTRM2 DRILL CIRC P Fill pipe @ 5 bpm, 850 psi. Monitor well, observed breathing, flow tapering off. 20:15 21:00 0.75 6,075 7,279 INTRM2 DRILL TRIP P RIH from 6075' - 7279' MD, 120k dwn. 21:00 00:00 3.00 7,279 7,369 INTRM2 DRILL CIRC P Circulate from 7279'-7369' MD, 1.5 - 2 bpm, 400 -525 psi, 210k up, 120k dwn, 170k rot, 15 rpm, 11-13k tq. Adjusted pump rate up and back down to minimize losses. 57 bbls loss for 12hrs. 1 /21 /2014 CBU with core fluid @ 7372' MD. 1.5 bpm, 400 psi, 30 bph losses. Pump LCM pill and spot on bottom. Displace to 10.7 Klashield, losses >35 bph during displacement @ 2 bpm. Reduce mud wt to 10.5 ppg, losses reduced to <10 bph. Wash down and ream core section to 9-7/8" to 7504' MD MN h 1 44 Time Logs Date From To Dur'' S. De th E. De th Phase Code Subcode T Comment 00:00 02:30 2.50 7,369 7,369 INTRM2 DRILL CIRC P Continue to CBU @ 1.5 bpm, 400 psi, Loss rate 30 bph. Lost 46 bbls. 02:30 03:00 0.50 7,369 7,369 INTRM2 DRILL OWFF P Blow down top drive. Monitor well, I breathing, decreasing flow. 03:00 04:00 1.00 7,369 7,369 INTRM2 DRILL CIRC P PJSM. Pump LCM pill 50#'s/bbl. 2 bpm, 475 psi stage pump up to 3 bpm, 575 psi. 1100 strokes slow pump down to 2.5 bpm. 100 gpm thru the MWD system. 04:00 05:00 1.00 7,369 6,908 INTRM2 DRILL CIRC P Pump out of hole laying pill behind. 4 stands. 1 bpm, 300 psi. 7369 to 6908'. 05:00 12:00 7.00 6,908 6,908 INTRM2 DRILL CIRC P PJSM. Displace well over to 10.7 ppg Kla-Shield mud from 11 ppg core fluid. 3 bpm, 480 psi, 30 rpm. See 45 to 50 bbl/hr losses, slow down to 2 bpm, 50 rpm, 350 psi, losses @ 30 bph. Fill rock washer, and all return pits. Slow down to .5 bph to allow the rock washer to get caught up. Low mud volume also required the slowing down of the pump. Begin staging the pump back up after emptying 50 bbls out of the rock washer. 1 bpm, 20 rpm, 250 psi. 6400 strokes began to see some Kla-Shield as crew changed. 12:00 19:00 7.00 6,908 6,999 INTRM2 DRILL CIRC P PJSM, Continue displacing 1 bpm @ 250 psi, 20 rpm, 11k Tq, P/U=156k, S/0=1 50k. Total losses previous tour 313 bbl. Continue pumping, lowering mud weight from 10.8 ppg ro 10.5 ppg, stage pumps up to drilling rate as losses allowed. ICP=325 psi @ 84 gpm, 20 rpm, Tq=9k, FCP 1425 psi @ 475 gpm, 100 rpm, Tq=11 k. P/U=160k, S/O=158k, ROT=159k. Losses reduced to <10 bph. 19:00 20:30 1.50 6,999 6,999 INTRM2 DRILL OWFF P Shut down pumps and observe well for flow. Breathing/exhaling, reducing from 1.2 bbl/5 min to .17 bbl/5min over 1.5 hours. Total mud exhaled 7.2 bbl. 20:30 21:15 0.75 6,999 7,425 INTRM2 DRILL WASH P PJSM, wash in hole from 6999' MD to 7425' MD at drilling rates, 475 gpm, 1500 psi, 100 rpm, TQ=10-12k. No recordable losses. 21:15 00:00 2.75 7,425 7,515 INTRM2 DRILL REAM P Start reaming through cored section, opening to 9-7/8" at 50 fph, 475 gpm, 1500 psi, 100 rpm, TQ=11-14k, WOB=5k. Losses not recordable. Total mud to formation today=367 bbl Cumulative mud to formation this interval=837 bbl 1 /22/2014 Drill 9 7/8" hole frm 7515' to 7900'. CBU 3 x's. MAD Pass while back reaming from TD to 6300'. Pulling 4007hr. RIH, CBU, pull up to target sand and begin Stethoscope pore pressure readings in Kuparuk sands. K?4,4: Time Los k „w .„ FromON` 11 + __.. }.. :- S. De th E. De th ''Phase Code Subcode T Comment' 00:00 07:00 7.00 7,515 7,850 INTRM2 DRILL DDRL P Drill from 7515' to 7850' MD. TVD=6501'. ADT=6.00. Total jar hrs=155.34. Bit hrs=39. P/U=215k, S/O=145k, Rot=175k, TQ on=13k, off=10k, ECD=11.41. MW=10.5ppg, Flow=74%, Rpm=145, Gpm=650, PSI=2600 SPR's: 7511 MD. 6206 TVD. MW 10.4+ ppg_ 1)20=260,30=320.2)20=250, 30=330. 07:00 08:00 1.00 7,850 7,900 INTRM2 DRILL DDRL X Drill from 7850' to 7900' MD. TVD=6595'. ADT=.B. Total jar hrs=156.53. Bit hrs=39.19 P/U=215k, S/O=145k, Rot=177k, TQ on=13k, off=10k, ECD=11.41. MW=10.5ppg, Flow=74%, Rpm=145, Gpm=650, PSI=2600 08:00 09:30 1.50 7,900 7,900 INTRM2 DRILL CIRC P CBU 2x's. 650 Gpm, 2600 Psi, No losses. Rot= 100 rpm 09:30 10:00 0.50 7,900 7,900 INTRM2 EVALFN OWFF P Observe well. Breathing, slowed to a trickle. SPR's. 10:00 12:00 2.00 7,900 7,558 INTRM2 EVALFN SRVY P Down link. Begin back reaming. MAD Pass from 7900 to 7558'. 4007hr. 500 Gpm, 80 Rpm, 1900 Psi. 10 to 13k TQ. SPR's: 7900' MD. 6595' TVD. 10.5 ppg- 1) 20=260, 30=320. 2) 20=250, 30=330 12:00 17:00 5.00 7,558 6,300 INTRM2 EVALFN SRVY P PJSM, continue MAD pass from 7558' MD to 6300' MD @ 400 fph, 500 gpm @ 1500 psi. 80 rpm, TQ=10k. 17:00 17:30 0.50 6,300 6,300 INTRM2 EVALFN OWFF P Blow down top drive, monitor well for 20 minutes, slight flow to trickle. 17:30 18:30 1.00 6,300 7,285 INTRM2 EVALFNTRIP P PJSM, RIH on elevators from 6300' MD to 7285' MD, tight spot at 7828' MD, stacked 20k. P/U 10'. Decision to wash and ream to bottom. 18:30 19:45 1.25 7,285 7,900 INTRM2 EVALFN WASH P Wash and ream from 7285' to 7900' MD pumping 500 gpm @ 1600 psi, 80 rpm, TQ=10k, P/U=166k, S/0=160k, ROT=161k. Encounterfill from 7895'-7900'. 19:45 20:45 1.00 7,900 7,900 INTRM2 EVALFN CIRC P CBU @ 500 gpm, 1600 psi reciprocate and rotate 80 rpm. Moderate splintered shale at bottoms up. SPR's at 7900', 20:45, 10.5+ppg. #1 30 spm=290 psi, 40 spm=360 psi #2 30 spm=290 psi, 40 spm=360 psi 20:45 21:15 0.50 7,900 7,590 INTRM2 EVALFNTRIP P PJSM, POOH from 7900'to 7590' MD with pump @ 2.5 bpm, 300 psi, no rotation. t �* 114et x F_ -I Time Logs Date From To Dur S. De th E De th' Phase Code Subcode T < Comment 21:15 22:15 1.00 7,590 7,564 INTRM2 EVALFN SRVY P Perform correlation log from 7590' MD to 7564' MD at 100 fph. 22:15 23:00 0.75 7,564 7,564 INTRM2 EVALFN OTHR P Perform 3 differential stick tests per SLB, parked for 5 minute, 10 minute and 12 minutes and checked P/U and S/O, 140k/225k each test. 23:00 00:00 1.00 7,564 7,562 INTRM2 EVALFN SRVY P Run first pressure test @ 7596' MD, test 2 @ 7562' MD. Pump 500 gpm, no rotation Total losses to formation today= 39 bbl Cumulative to formation this interval=876 Dl/23/2014 Obtain 14 Stethoscope readings. Determine pore pressure to be 10.1 ppg. TIH to bottom. CBU 2x's. Pump out to A5 sand. Perform 2 more readings. Pore pressure verified @ 10.1 ppg. Observe well static. Pump out to 6167' MD. Phase II conditions called at 09:30 hrs. POOH on elevators to BHA, good hole fill, no losses. 00:00 01:45 1.75 7,562 7,536 INTRM2 EVALFN CIRC P PJSM. Continue to obtain Stethoscope readings @ 7538.6', 7537.6', 7536.6'. 01:45 02:00 0.25 7,536 7,525 INTRM2 EVALFN CIRC P Perform MWD correlation logs. 02:00 05:30 3.50 7,525 7,525 INTRM2 EVALFN CIRC P Continue to obtain pore pressure readings with Stethoscope @ 7529.6',7526.6', 7527.1, 7522.6', 7520.6', 7510.6', 7504.1, 7491.6', 7472.6', 7470.01'. 05:30 06:15 0.75 7,525 7,836 INTRM2 EVALFN OWFF P Blow down top drive. Observe well. Static. RIH from 7525' to 7836'. 06:15 06:30 0.25 7,836 7,900 INTRM2 EVALFN CIRC P Break circ. @ 7836' MD. Wash and ream to bottom @ 7900' MD. 585 Gpm, 100 Rpm, 2150 Psi, 06:30 08:15 1.75 7,900 7,900 INTRM2 EVALFN CIRC P CBU 2x's. @ 7900' MD. 630 Gpm, 2400 Psi, 100 Rpm, 10k TQ. Some splintered shale on first bottoms up, cleaned up the 2nd BU. 08:15 08:45 0.50 7,900 7,490 INTRM2 EVALFN CIRC P Pump out 4 stands and perform correlation logs for Stethoscope readings from 7460 to 7480' sensor depths. 08:45 09:45 1.00 7,490 7,490 INTRM2 EVALFN CIRC P Obtain 2 pore pressure readings with Stethoscope tool. Pumps on and off. Verify 3215 psi BHP. 10.1 ppg EMW. 09:45 10:00 0.25 7,490 7,490 INTRM2 EVALFN SFTY P Safety meeting. Tripping OOH in Phase 2 conditions. 10:00 11:30 1.50 7,490 7,490 INTRM2 EVALFN OWFF P Observe well. Breathing slowly. Diminishing returns. Gained 1 bbl in an hour and went static. Observe static for 30 mins. 11:30 12:00 0.50 7,490 7,558 INTRM2 EVALFN CIRC P Obtain SPR's and pulling parameters. P/Ut=220k, S/O= 137k, Rot=170k. Crew change. SPR @ 7558' MD, 6240' TVD, 10.5 ppg #1 20 spm -290 psi, 30 spm -380 psi #2 20 spm -300 psi, 30 spm -360 psi Page 18,of 44 Time Logs Date From To Dur S. De th E De thPhase - Code Subcode T Comment 12:00 15:30 3.50 7,558 6,167 INTRM2 EVALFNTRIP P PJSM, Pump out from 7558' MD to 6167' MD, P/U=220, S/O=139, pull at 900 fph, pump 3 bpm @ 300 psi. 15:30 18:45 3.25 6,167 3,750 INTRM2 EVALFNTRIP P I POOH on elevators from 6167' MD to 3750' MD. 18:45 19:00 0.25 3,750 3,750 INTRM2 EVALFN SFTY P IHRW. PJSM on cut and slip drilling line 19:00 20:30 1.50 3,750 3,750 INTRM2 EVALFN SLPC P I Slip and cut 97' drilling line. 20:30 21:00 0.50 3,750 3,750 INTRM2 EVALFN SVRG P Service crown, blocks and top drive. 21:00 22:15 1.25 3,750 820 INTRM2 EVALFN TRIP P Continue POOH on elevators from 3750 to 820' MD. 22:15 22:30 0.25 820 820 INTRM2 EVALFN OWFF P Monitor well for flow at HWDP. (Static) 22:30 23:15 0.75 820 245 INTRM2 EVALFN TRIP P Rack back HWDP and flex collars. 23:15 00:00 0.75 245 151 INTRM2 EVALFN PULD P L/D stabilizer, clean up rig floor to remove sources. Calc Disp=69.78 bbl, Actual Disp=72.64 bbl. D1/24/2014 Lay down BHA#5. Rig up E -Line truck. First run: log with XRMI, Wave Sonic, gamma ray, calipers. POOH after two passes. Log from 7800' to 6300' MD. M/U and begin second run: side wall core assembly. 00:00 00:15 0.25 151 132 INTRM2 EVALFN PULD P PJSM. Lay down BHA. Remove nukes. 00:15 01:45 1.50 132 0 INTRM2 EVALFN PULD P Continue to lay down BHA. From 137' to the bit. Remove second source. Complete BHA lay down. Bit graded 1 -1 -WT -A -X -1 -NO -TD 01:45 02:15 0.50 0 0 INTRM2 EVALFN RURD P Clear and clean rig floor. 02:15 02:30 0.25 0 0 INTRM2 EVALFN SFTY X PJSM. Rigging up wire line with Halliburton. 02:30 04:15 1.75 0 0 INTRM2 EVALFN RURD X Spot up wireline truck. Pick up tools to rig floor, prepare tools in pipe shed. 04:15 06:00 1.75 0 0 INTRM2 EVALFN PULD X Make up Electric Line logging tools Run #1. XMRI, Wave Sonic, Gamma Ray, Caliper Run. 06:00 13:00 7.00 0 0 INTRM2 EVALFN ELOG X RIH with E -Line. Log. Well bore static. Tight spots, 7200' to 7300' on the way in, 7800' to 7725' on the way out for the first pass. Tagged up at 7820' MD, hung up at 7800' MD, Jarred up to 7725' to pull free. Second pass, no ledges seen. Logged from 7800 to 6300' MD. POOH to pick up side wall core tools. 13:00 14:00 1.00 0 0 INTRM2 EVALFN PULD X Lay down first run logging string. 14:00 18:00 4.00 0 0 INTRM2 EVALFN PULD X Prep sidewall coring tools for run #2. 18:00 18:30 0.50 0 0 INTRM2 EVALFN PULD X PJSM, M/U jars, RDT/HRSC. Gamma, coring tool. 18:30 21:00 2.50 0 0 INTRM2 EVALFN PULD X Function test coring tool on surface, coring tool sfailed, L/D bad HRSC tool, P/U spare HRSC, function test on surface good. �' Page 19 flf' --------------- Time Logs W 14W Date From To Dur S. Depth E. Depth -Phase Code Subcode T Comment 21:00 00:00 3.00 0 1 0 INTRM2 EVALFN ELOG X RIH w/ E -Line coring tool assembly. 31/25/2014 E- line operations. Sidewall cores. Retrieved sixteen 2" plugs in Kalubik and HRZ formations. POOH and rig down E -line. Rig up and test BOPE. Bi -Weekly test. P/U 3-1/2" cement stinger and RIH on 5" DP to 5143' MD. 00:00 07:30 7.50 0 0 INTRM2 EVALFN ELOG X Conduct E -line operations. Side wall coers in the Kalubik, and HRZ formations. Targeted 23 cores. Retrieved 16 cores @ 7230, 7185', 7100', 7070', 7040', 7010', 6945', 6932', 6914', 6801', 6663', 6643', 6618', 6608', 6580', 6559'. All cores were secured for shipment. 07:30 08:30 1.00 0 0 INTRM2 EVALFN ELOG X POOH with E -Line Run #2 Core Run. 08:30 09:30 1.00 0 0 INTRM2 EVALFN ELOG X PJSM. Lay down logging tools. 09:30 10:15 0.75 0 0 INTRM2 DRILL RURD P Clean and clear rig floor. 10:15 12:00 1.75 0 0 INTRM2 DRILL RURD P PJSM. Rig up for Bi -Weekly BOPE test. Flood stack and fill kill line with water. 12:00 15:30 3.50 0 0 INTRM2 DRILL BOPE P PJSM, Test BOPE. #1 -Top pipe rams, Valve 1,12,13,14 and manual kill. #2- Upper IBOP, HCR Kill, Valves 9,11. #3- Lower IBOP, Valves 5,8 and 10. #4- Dart Valve, Valves 4,67. #5- Floor valve and valve 2. #6 - HCR choke, 4" Kill line Demco valve, #7- Manual choke valve, HCR Kill. #8- Annular preventer. #9- Lower pipe rams. #10- Blind rams, valve 3. 15:30 16:00 0.50 0 0 INTRM2 DRILL BOPE P Accumulator test, system pressure 2950 psi, pressure after closed 1800 psi, 200 psi attained=36 sec, Full pressure attained=167 sec, N2 bottle average 2000 psi. Isolate air and electric pumps and test to system pressure. Air=68 sec full recovery, Electric= 102 sec full recovery. All tests performed with 5" test joint 250 psi low/3500 psi high 5 min each. Tested gas alarms. AOGCC John Crisp waived witness of test. 16:00 17:45 1.75 0 0 INTRM2 DRILL RURD P PJSM, R/D test equipment, blow down choke / kill lines and manifold. Set wear ring, RI LDS. 17:45 19:15 1.50 0 0 INTRM2 DRILL RURD P PJSM, R/U tubular handling equipment. 19:15 20:45 1.50 0 972 INTRM2 DRILL TRIP P PJSM, RIH with 3-1/2" cement string per detail to 972' MD. 20:45 21:30 0.75 972 975 INTRM2 DRILL RURD P R/D tubing equipment, C/O handling tools, M/U XO's to 4-1/2" IF. 21:30 00:00 2.50 975 5,143 INTRM2 DRILL TRIP P RIH on 5" DP to 5143' MD. Fill/clear pipe every 20 stands. Calc Disp=32.35, Actual Disp=41.48, P/U=110, S/0=88k. v _ Pde) f Time Logs Date From To Dur' S. De th E. Depth Phase Code : Subcode T Comment D1/26/2014 24 hr summary TIH from 5143' to 7821'. CBU. Pump 85 bbl 15.8 ppg cement plug. PUH 10 stands and CBU clear pipe. Wait on cement 8 hrs. Pump plug #2 76.6 bbl 15.8 ppg at 7182' MD, PUH 10 stands and CBU clear pipe RIH to 6719' MD, CBU and begin setting #3 15.8 ppg balanced plug. 00:00 01:30 1.50 5,143 7,821 INTRM2 CEMEN'TRIP P PJSM, Continue to RIH F/ 5143'T/ 7821' and tag bottom. P/U 170K S/O 120K. 01:30 01:45 0.25 7,821 7,821 INTRM2 CEMEN' TRIP P Attempted to wash the pipe farther down. Tag 3X W/ 2-5k WOB, WOB would not drill off. Decision made to CBU. 01:45 03:45 2.00 7,821 7,826 INTRM2 CEMEN-CIRC P Circ. & Cond. mud @ 7821', 6 bpm, 600 psi, stage up to 10 bpm, 1500 psi. Wash to 7826' 03:45 05:15 1.50 7,826 7,826 INTRM2 CEMEN' CIRC P M/U pump in sub CMT lines, continue to Circ. & Cond. mud. Sim -Ops PJSM W/ Cementers, Truck Drivers, and Rig Crew 05:15 05:30 0.25 7,826 7,826 INTRM2 CEMEN- PRTS P PT CMT lines T/ 4000 psi, Observed leak in CMT line, shut down, bleed down, and make line repairs. 05:30 06:15 0.75 7,826 7,826 INTRM2 CEMEN PRTS P Break circulation W/ mud pumps @ 10 bpm, 1500 psi, shutdown, lineup T/ SLB cementers. Pumped 5 bbl H2O, PT CMT lines T/ 4000 psi. GOOD TEST. 06:15 07:30 1.25 7,826 7,826 INTRM2 CEMEN CMNT P Plug #1:Pump Cement per plan, 30 bbl 12.5 ppg MudPush II, Load mechanical wiper ball, pump 85 bbl 15.8 ppg class G tail CMT, 4.6 bbl 12.5 ppg MudPush II, shutdown and turn over to rig pumps, pump 112 bbl of 10.5 ppg mud. Shut down CIP@ 07:45 hrs. No gains or losses. 07:30 09:00 1.50 7,826 6,996 INTRM2 CEMEN TRIP P R/D Cement equipment. POOH 10 stands T/ 6996', P/U 175K, 09:00 12:00 3.00 6,996 6,996 INTRM2 CEMEN-CIRC P R/U, CBU 2X @ 6996', 10 bpm, 434 gpm, 780 psi. S/O 105K, P/U 145K. Estimated TOC 7263' 12:00 14:00 2.00 6,996 6,996 INTRM2 CEMEN WOC P WOC @ 6996' MD, circulate @ 443 gpm, 775 psi 61 % fow. 14:00 15:30 1.50 6,996 7,182 INTRM2 CEMEN WASH P PJSM, wash and ream at 200 gpm, 350 psi, 50% Flow out from 6996' MD to 7213' MD. Tag TOC @ 7213' MD, set down 5 k to confirm. P/U=155k, S/O=110k, Rack back 1 stand, make up top drive. 15:30 16:45 1.25 7,182 7,182 INTRM2 CEMEN-CIRC P Circulate and condition mud @ 7182' MD, 443 gpm @ 825 psi. (SIMOPS PJSM pumping cement job.) 16:45 17:00 0.25 7,182 7,182 INTRM2 CEMEN- RURD P Break top drive and blow down, R/U cement equipment with head pin. 17:00 17:30 0.50 7,182 7,182 INTRM2 CEMEN CIRC P Continue circulating @ 297 bpm, 775 psi 55% Flow out. Batch up 12.5 ppg Mudpush II. Page 2'1' IN Time Logs P� Date From To Dur S. De th E. Depth -Phase Code Subcode T Comment 17:30 19:00 1.50 7,182 7,182 INTRM2 CEMEN' CMNT P Pump balanced cement plug #2 per plan, SLB pumped 30 bbl 12.5 ppg MudPush II, load mechanical wiper ball, pump 76.6 bbl 15.8 ppg Class G Tail cement, under displaced by 7 bbl with 4.7 bbl 12.5 ppg MudPush II from SLB followed by 101 bbl 10.5 ppg mud with rig pumps. 19:00 20:00 1.00 7,182 6,348 INTRM2 CEMEN-TRIP P POOH from 7182' MD to 6348' MD, P/U=137k, S/O=100 k. Calc Fill=6.93 bbl, Actual Fill=5.44. 20:00 21:00 1.00 6,348 6,348 INTRM2 CEMEN- CIRC P CBU at 6348' MD to clear pipe, 10 bpm @ 800 psi, 63% Flow out, reciprocate 90'. 21:00 21:15 0.25 6,348 6,719 INTRM2 CEMEN-TRIP P RIH on elevators from 6348' MD to 6719' MD, Calc Disp=3.08 bbl, Actual Disp=5.95 bbl. 21:15 22:45 1.50 6,719 6,719 INTRM2 CEMEN- CIRC P Circulate @ 6719' MD, 2 BU. MudPush returns and little cement as seen by ph. Pumped 10 bpm @ 825 psi, 61% Flow Out, reciprocate 90'. 22:45 23:15 0.50 6,719 6,719 INTRM2 CEMEN- RURD P PJSM, cementing ops. Break top drive connection, blow down. R/U cement equipment with head pin. 23:15 00:00 0.75 6,719 6,719 INTRM2 CEMEN-CMNT P Plug #3: Pump cment job per program. Pump 5 bbl water through lines to cellar to warm, PT lines to 4000 psi 5 min. Bleed pressures, pump 30 bbl 12.5 ppg MudPush II, load mechanical wiper plug. Start batching 15.8 ppg class G tail cement. D1/27/2014 Place cement plug #3 in wellbore from 6719' to 6069' MD. Place kick off plug from 6069' to 5490'. Wash down to 5490' and C&C mud system, lower PH from 12 to 10.8. POOH. Pick up Drilling 9-7/8" bit/BHA #6, RIH to 5364' M D. 00:00 00:30 0.50 6,719 6,719 INTRM2 CEMEN CMNT P Continue to pump Plug# 3, 70 bbl 15.8 ppg Class G tail, 5.1 bbl 12.5 ppg MudPush II, Displace W/ 861 stk 10.5 ppg mud @ 8 bpm, 400 psi with rig pumps. 00:30 02:00 1.50 6,719 5,884 INTRM2 CEMEN'TRIP P POOH T/ 5884', 9 stands. P/U 145K, 02:00 02:45 0.75 5,884 5,884 INTRM2 CEMEN-CIRC P CBU @ 10 bpm, 700 psi, ph climbed to 11.7, mud weight 11.0 ppg, treated and circulate mud weight to 10.5+ ppg. 02:45 03:00 0.25 5,884 6,069 INTRM2 CEMEN- TRIPP RIH T/ 6069'. 03:00 04:30 1.50 6,069 6,069 INTRM2 CEMEN CIRC P CBU @ 6069', 10 bpm, 700 psi, Sim -Ops W/ cement crew, PJSM on Plug# 4. 04:30 05:00 0.50 6,069 6,069 INTRM2 CEMEN PULD P R/U cement equipment, break circ. @ 2.4 bpm, 450 psi, batch up cement. �n �v._ -777 7777 Page 22 of 44 �r Time Logs Date From To Dur S. =De th E. De th ''Phase Code Subcode T Comment 05:00 06:30 1.50 6,069 6,069 INTRM2 CEMEN' CMNT P Pumped 5 bbl H2O, Test cmt. line to 4000 psi 5 min, Pumped 30 bbl 12.5 ppg MudPush ll, shut done and installed wiper ball, Pumped 89 bbl 17 ppg cement, 4.55 bbl 12.5 ppg MudPush Il, Swap to rig pumps, displace W/ 78.78 bbl 10.5 ppg mud (780 stks) @ 9 bpm, 500 psi, Slow to 2 bpm, 200 psi, last 100 stks. 06:30 07:45 1.25 6,069 5,421 INTRM2 CEMEN" TRIP P POOH T/ 5421'. P/U=130K, Calc Fill= 5.3 bbl, Actual Fill= 4.2 bbl. 07:45 11:00 3.25 5,421 5,490 INTRM2 CEMEN- CIRC P Break circulation and wash down T/ 5490', 10 bpm, 750 psi, Stage pumps up to 510 gpm, 200 psi. Circulate & condition mud due to high pH (12.5). 11:00 12:00 1.00 5,490 5,421 INTRM2 CEMEN- CIRC P Rack back a stand T/ 5421' Continue to Circ. & cond. mud. reciprocate pipe. P/U 120K, S/O 95K. 12:00 12:30 0.50 5,421 5,421 INTRM2 CEMEN' CIRC P Continue to Circulate, Obtain SPR, PJSM on POOH. 12:30 13:00 0.50 5,421 5,421 INTRM2 CEMEN- CIRC P Flow check, Well static. 13:00 15:45 2.75 5,421 972 INTRM2 CEMEN TRIP P POOH W/ cmt string F/ 5421' T/ 3.5" tbg @ 972'. Monitored well @ shoe, Well static. 15:45 16:30 0.75 972 982 INTRM2 CEMEN- PULD P PJSM, C/O handling tools, R/U csg. tongs. 16:30 17:30 1.00 982 0 INTRM2 DRILL TRIP P L/D 3.5" tbg & mule shoe. Calc Fill=40.15 bbl, Actual Fill=41.82 bbl. 17:30 19:00 1.50 0 0 INTRM2 DRILL RURD P R/D casing equipment, clean and clear rig floor, mobilize BHA components to rig floor. Prep tools for M/U BHA. 19:00 20:30 1.50 0 175 INTRM3 DRILL PULD P PJSM, M/U Side Track assembly BHA #6 per SLB 20:30 21:30 1.00 175 1,660 INTRM3 DRILL TRIP P RIH w/ NM flex collars, HWDP and Jars, 10 stands 5" DP to 1660' MD. 21:30 22:00 0.50 1,660 1,660 INTRM3 DRILL CIRC P Shallow test MWD @ 400 gpm, 700 psi, 58% Flow out. Blow down top drive. 22:00 23:00 1.00 1,660 5,271 INTRM3 DRILL TRIP P Continue RIH from 1660' MD to 5271' MD, fill pipe every 10 stands. Calc Disp=53.04 bbl, Actual Disp=45.24 bbl, P/U=155k, S/0=105k. 23:00 00:00 1.00 5,271 5,364 INTRM3 DRILL WASH P Establish parameters, break in PowerDrive. Test drill link (good) wash from 5271' MD to 5364' MD @ 500 gpm, 1450 psi, 70 rpm, 7k TQ, 63% Flow out, P/U=124k, S/0=120k, ROT=122k. 1 /28/2014 Kick off cement plug at 5550' MD and drill 9-7/8" section to 7070' MD, 5439' TVD @ 150-225 fph. Time Logs Date From To Dur S. De th E. De th PhaseCode Subcode T Comment 00:00 00:15 0.25 5,364 5,487 INTRM3 DRILL WASH P PJSM, continue washing down from 5364' MD to 5487' MD @ 500 gpm, 1400 psi, 70 rpm, 8k ft/lbs TQ. Tag TOC @ 5487', reduce pump rate to 425 grm 1100 psi, 90 rpm. Obtain SPR,s @ 5487' MD, 4353' TVD, MW=10.5 ppg, 00:01 hrs. #1- 30 spm=190 psi, 40 spm=280 psi #2- 30 spm=190 psi, 40 spm=290 psi 00:15 01:15 1.00 5,487 5,547 INTRM3 DRILL DRLG P SPR's, Drill cement from 5487' to 5547' MD @ 432 gpm, 1100 psi, 90 rpm 8-10k ft/lbs TQ. 01:15 02:00 0.75 5,547 5,547 INTRM3 DRILL DDRL P Cut trough from 5519' to 5547' MD 4x @ 270°, 630 gpm, 2150 psi, 90 rpm, 9k TQ. 02:00 07:45 5.75 5,547 5,668 INTRM3 DRILL DDRL P Sidetrack well from 5550' to 5631' MD @ 20 fph, 40 fph to 5668' MD @ 630 gpm, 2150 psi, 5-8k WOB, 80 rpm, 9k TQ. 07:45 08:15 0.50 5,668 5,731 INTRM3 DRILL DDRL P Drill from 5668' MD to 5731' MD @ 630 gpm 2250 psi, 8-10 WOB, 10k TQ. 08:15 10:45 2.50 5,731 5,731 INTRM3 DRILL CIRC P Displaced well over to 9.5 ppg LSND mud, 230 gpm, 650 psi, 100 rpm, 9-10k TQ. 10:45 11:00 0.25 5,731 5,731 INTRM3 DRILL OWFF P Monitor Well. Well Static. Obtain SPR,s @ 5731' MD, 4547' TVD, MW=9.5 ppg, 11:00 hrs. #1- 30 spm=220 psi, 40 spm=290 psi #2- 30 spm=220 psi, 40 spm=270 psi 11:00 12:00 1.00 5,731 5,797 INTRM3 DRILL DDRL P Drill from 5731' MD to 5797' MD, 4646' TVD. ART=.38, ADT -.38, Jar hrs=133.38, Bit hrs=6.08, P/U=160k, S/O=110k, ROT= 130k, TQ on/off=10/8k, ECD=10.20 ppg EMW, 73 % Flow out, WOB= 10k, 655 gpm @ 1730 psi, 140 rpm. 12:00 18:00 6.00 5,797 6,472 INTRM3 DRILL DDRL P Drill from 5797' MD to 6472' MD, 5046' TVD. ART=.3.67, ADT -3.67, Jar hrs=137.05, Bit hrs=9.75, P/U=160k, S/0=120k, ROT=136k, TQ on/off= 1 1/8k, ECD=10.71 ppg EMW, 72 % Flow out, WOB= 10-18k, 658 gpm @ 2025 psi, 140 rpm. ,• r� -- E 77 40a Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 18:00 00:00 6.00 6,472 7,070 INTRM3 DRILL DDRL P Drill from 6472' MD to 7070' MD, 5439' TVD. ART=3.68, ADT-3.68, Jar hrs=140.73, Bit hrs=13.43, P/U=168k, S/O=124k, ROT=144k, TQ on/off=12/14k, ECD=10.82 ppg EMW, 71 % Flow out, WOB= 5-12k, 630 gpm @ 2025 psi, 150 rpm. SPR's @ 6658' MD, 5170' TVD, 9.6 ppg #1- 30 spm=300 psi, 40 spm=390 psi #2- 30 spm=300 psi, 40 spm=390 psi 31/29/2014 Directional drill 9-7/8" section from 7070' to 8418' MD, 6079' TVD @ 100-150 fph. Increase mud weight to 10.2 at HRZ. 00:00 06:00 6.00 7,070 7,494 INTRM3 DRILL DDRL P Drilling F/ 7070' MD T/ 7494' MD, 5762' TVD, ART= 4.47, Total Jar hr.=145.2, Bit hr.=17.9, P/U= 174K, S/0= 129K, Rot=148K, TQ on/off= 8/5k, ECD= 10.74, Flow out= 73%, WOB= 5-8, RPM= 130/150, GPM= 630, PSI= 2020. SPR's @ 00:01 hrs, 7121' MD, 5466' TVD, 9.6 ppg. #1- 30 spm=360 psi, 40 spm=410 psi. #2- 30 spm=310 psi, 40 spm=420 psi. 06:00 10:45 4.75 7,494 7,494 INTRM3 DRILL CIRC T Stop drilling ahead to condition mud to required properties before entering HRZ. Pump @ 625 gpm, 210 psi, 130 rpm. Had trouble offloading spike fluid from Vac truck due to the thickness and density of the fluid. 10:45 11:00 0.25 7,494 7,494 INTRM3 DRILL OWFF P OWFF and obtain SPR's @ 11:00 hours, 7494' MD TVD= 5620. 10.2 ppg MW #1- 30 spm=320 psi, 40 spm=400 psi #2- 30 spm=300 psi, 40 spm=420 psi 11:00 12:00 1.00 7,494 7,545 INTRM3 DRILL DDRL P Drilling F/ 7494' MD T/ 7545' MD, 5706' TVD, ART= .50, Total Jar hr.=145.70, Bit hr.= 18.4, P/U= 174K, S/0= 130K, Rot= 147K, TQ ON= 8-15K, OFF= 8K, ECD= 11.34, Flow out= 73%, WOB= 10, RPM= 130, GPM= 630, PSI= 2220. 12:00 18:00 6.00 7,545 7,987 INTRM3 DRILL DDRL P Drill from 7545' to 7987' MD, 5920' TVD, ADT=4.15, Bit hrs= 22.55 , Jar hrs= 149.85, P/U=185k, S/0=130k, Rot=152k, TQ on/off=1 1-1 3/7.5k, ECD=11.07, 72% Flow out, WOB=5k, 130 rpm, 650 gpm @ 2475 psi. Time Logs W MW Date From To Dur S. De th '! E. De th Phase Code ` Subcode TComment 18:00 00:00 6.00 7,987 8,418 INTRM3 DRILL DDRL P Drill from 7987' to 8418' MD, 6079' TVD, ADT= 4.28, Bit hrs= 26.83 , Jar hrs= 154.13, P/U=190k, S/O=129k, Rot=150k, TQ on/off= 12/8k, ECD=11.54, 70% Flow out, WOB=3-10k, 130 rpm, 650 gpm @ 2725 psi. SPR's @ 8409' MD, 5046' TVD, 10.15 ppg, 18:15 hrs. #1- 30 spm= 330 psi, 40 spm= 420 psi #2- 30 spm=330 psi, 40 spm= 430 psi Dl/30/2014 Drill 9-7/8" section to TD, 8842' MD, 6159' TVD. Condition hole and wiper trip to 5364' MD. RBIH, stop and circ 2 BU at 6014' due improper displacement, continue TIH on elevators to TD. Begin circulating to condition for POOH. 00:00 06:00 6.00 8,418 8,748 INTRM3 DRILL DDRL P Drill F/ 8418' MD T/ 8748' MD, TVD= 6154, ART= 4.41, Total jar hr= 158.54, Bit= 31.24, P/U 189k, S/O 120k, Rot 149k, TQ on/off 14/5k, ECD 11.64, Flow out%= 66%, WOB 5-10k, RPM 130, psi 2700 SPR's @ 8418' MD, 6983' TVD, 10.5 ppg, 00:01 hrs #1- 30 spm=380 psi, 40 spm=450 psi #2- 30 spm=380 psi, 40 spm=450 psi 06:00 09:30 3.50 8,748 8,842 INTRM3 DRILL DDRL P Drill F/ 8748' MD T/ 8842' MD, TVD= 6159, ART= 1.54, Total jar hr= 160.08, Bit= 32.78, P/U 189k, S/O 120k, Rot 149k, TQ on/off 14/5k, ECD 11.64, Flow out%= 66%, WOB 5-10k, RPM 130, psi 2825 09:30 12:00 2.50 8,842 8,842 INTRM3 CASING CIRC P SPR's, pump 30 bbl Hi Vis sweep, CBU x 4 @ 650 gpm, 2775 psi, 130 rpm, 13k TQ. Rack back stand in derrick each BU. SPR's @ 8842' MD, 6159' TDV, 10.6 ppg, 09:30 hrs #1- 30 spm=340 psi, 40 spm=450 psi #2- 30 spm=320 psi, 40 spm=450 psi 12:00 13:00 1.00 8,842 8,514 INTRM3 CASING CIRC P PJSM, continue CBU x 4, racking back stand from 8700' MD to 8514' MD circ @ 650 gpm, 2700 psi, 130 rpm, 12k TQ. 13:00 13:15 0.25 8,514 8,514 INTRM3 CASING RURD P Break connection, blow down top drive, rack back stand. 13:15 13:45 0.50 8,514 8,514 INTRM3 CASING OWFF P Monitor well, (static), SIMOPS PJSM on tripping out of hole on elevators. 13:45 15:30 1.75 8,514 7,404 INTRM3 CASING TRIP P POOH on elevators from 8514' MD to 7404' MD, 20-25k overpull. Backream and CBU. Calc Fill=9.24 bbl, Actual Fill=8.67 bbl i6 44 Ank Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T< Comment 15:30 16:45 1.25 7,404 7,217 INTRM3 CASING REAM P Back ream from 7404' MD to 7217' MD @ 630 gpm, 2400 psi, 130 rpm, 9k TQ. Noticable increase in cuttings on BU's. Blow down top drive and rack back stand. 16:45 17:00 0.25 7,217 7,217 INTRM3 CASING OWFF P Monitor well (static) 17:00 18:45 1.75 7,217 5,364 INTRM3 CASING TRIP P Continue POOH on elevators from 7217' MD to 5364' MD, Calc Fill=14.85 bbl, Actual Fill=14.3 bbl. 18:45 19:15 0.50 5,364 5,364 INTRM3 CASING CIRC P CBU @ 5364' MD 550 gpm, 1750 psi, 100 rpm, 7.5k TQ. P/U=155k, S/0=105k 19:15 19:30 0.25 5,364 5,364 INTRM3 CASING OWFF P Monitor well (static), Blow down top drive. 19:30 20:00 0.50 5,364 6,012 INTRM3 CASING TRIP P PJSM, RIH from 5364' MD to 6012' MD, hole not taking proper fill and 25-30k down weight. Observed and decide to CBU. 20:00 21:00 1.00 6,012 6,012 INTRM3 CASING CIRC P CBU x 2 @ 650 gpm, 2450 psi, 130 rpm, 8k TQ. Blow down top drive. Observed noticable increase in cuttings returns on shakers at BU and 1.5 BU. 3-5% splintered shale, 1 % cement, 1 % small clay balls, mostly mushy cuttings. 21:00 22:45 1.75 6,012 8,842 INTRM3 CASING TRIP P Continue RIH from 6012' MD to 8792' MD on elevators, wash to 8838' MD @ 350 gpm no rotation. Tag 4' fill, slowly wash to 8842' MD TD. Calc Disp=26.95 bbl, Actual Disp=22.97 bbl. 22:45 00:00 1.25 8,842 8,751 INTRM3 CASING CIRC P Circulate bottoms up @ 650 gpm, 2950 psi, 130 rpm, 11 k TQ. ECD=12.04. Reduce pumps to 500 gpm at 3/4-1 1/4 BU to keep mud on shakers, heavy cuttings load and 11.8 ppg mud. Mostly sand, clay, very little shale show. Shut down to rack back 1 stand and pump weighted sweep. D1/31/2014 POOH and L/D 9-7/8" BHA #6. Change upper rams to 7-5/8" and function test. Test upper rams and annular to 250/3500 psi 5 min ea charted. R/U to run 7-5/8" casing. 00:00 02:15 2.25 8,751 8,751 INTRM3 CASING CIRC P PJSM, CBU 3X @ 650 gpm, 2900 psi, 150 rpm, 13k TQ. Obtained SPR and OWFF 30 min. 02:15 07:00 4.75 8,751 3,790 INTRM3 CASING TRIP P POOH on elevators F/ 8700' MD T/ 3790' MD. No tight hole was observed while POOH. 07:00 07:45 0.75 3,790 3,790 INTRM3 CASING CIRC P CBU 2X @ 3790' MD, 650 gpm, 2100 psi, 40 rpm. Observed a moderate amount of cuttings on shakers. 07:45 08:15 0.50 3,790 3,790 INTRM3 CASING OWFF P OWFF, Static. 08:15 09:45 1.50 3,790 743 INTRM3 CASING TRIP P POOH F/ 3790' MD T/ 743' MD 09:45 10:00 0.25 743 743 INTRM3 CASING OWFF P OWFF, Static. Pno- 2 �f- 44 r Time Logs Date From To Dur S.;De th E.De th"Phase'Code - Subcode T€ Comment 10:00 12:00 2.00 743 0 INTRM3 CASING PULD P L/D HWDP, Jars, BHA, Bit. Cal= 87.96 bbl Act= 86.68 bbl Bit graded 1 -1 -WT-A-X-1-NO-TD 12:00 12:45 0.75 0 0 INTRM3 CASING RURD P PJSM, clean and clear rig floor 12:45 14:00 1.25 0 0 INTRM3 CASING RURD P PJSM, make up stack flusher, flush stack. Observed swivel packing leaking and inspect. C/O grease fitting and test to 3000 psi- good. 14:00 15:30 1.50 0 0 INTRM3 CASING RURD P PJSM, C/O upper rams to 7-5/8" 15:30 16:30 1.00 0 0 INTRM3 CASING BOPE P PJSM, function test lower rams, pull wear ring, set test plug, R/U to test upper 7-5/8" rams and annular preventer. 16:30 17:15 0.75 0 0 INTRM3 CASING BOPE P Test 7-5/8" upper rams and annular preventer to 250/3500 psi 5 min on chart. 17:15 18:00 0.75 0 0 INTRM3 CASING RURD P R/D test equipment, move Iron Roughneck track, remove elevators and bails. 18:00 20:30 2.50 0 0 INTRM3 CASING RURD P PJSM, R/U Tesco casing equipment and test OK. 20:30 21:30 1.00 0 0 INTRM3 CASING OTHR T ASRC Generator, rented for Tesco hydraulic powerpack died. Call for replacement and troubleshoot. Repaired belt, generator still shutting down due overheating. No replacement generator and mechanic will take 4-6 hours. Call engineer and decide to rig down Tesco and run casing with tongs. 21:30 23:15 1.75 0 0 INTRM3 CASING RURD T PJSM, rig down Tesco equipment, install top drive bell guide. Clear rig floor of Tesco equipment. 23:15 00:00 0.75 0 0 INTRM3 CASING KURD T PJSM, R/U Doyon casing equipment 2/01/2014 Run 7-5/8" casing to 3788' MD, CBU no losses. RIH to 5875' MD, work thru tight spot at 3944'. Attempt circulation at 5875' MD, 100% losses. POOH with casing to 3837' casing shoe, circ @ 75% losses. 00:00 01:30 1.50 0 0 INTRM3 CASING RNCS P PJSM, P/U and R/U casing equipment. Make dummy run with landing joint and hanger. 01:30 01:45 0.25 0 0 INTRM3 CASING SFTY P PJSM on running 7-5/8" casing 01:45 09:00 7.25 0 3,788 INTRM3 CASING RNCS P RIH with 7-5/8" casing to 3788' MD per tripping schedule. (total centrilizers run 32) 09:00 09:30 0.50 3,788 3,799 INTRM3 CASING CIRC P CBU starting @ 1.5 bpm, staging up to 5.5 bpm, 500 psi, 48% Flow. (No Losses) 09:30 12:00 2.50 3,799 4,693 INTRM3 CASING RNCS P RIH w/ 7-5/8" casing from 3799' to 4693' MD per schedule, tight spot at 3944' MD, pump 5 bpm, 500 psi, work thru several times, pipe worked through ledge, 5 bbl mud loss while pumping. Calc Disp=50.38 bbl, Actual Disp= 40.8 for 110 jts. P/U=138k, S/0=108k. m� _.__ _ .�a 777777-�� s .M, Time Logs Date From To Dur S. De th E. De th` Phase Code Subcode T Comment 12:00 13:30 1.50 4,693 5,875 INTRM3 CASING RNCS P PJSM, continue RIH with casing from 4693' to 5875' MD. P/U=169k, S/0=124k. Calc Disp=13.17 bbl, Actual Disp=-17 bbl. 13:30 14:15 0.75 5,875 5,875 INTRM3 CASING CIRC P Attempt to establish circulation @ 2 bpm, 500 psi. Observed mud losses during circulation approx 70%. 14:15 15:45 1.50 5,875 5,723 INTRM3 CASING PULL T PJSM, B/D top drive and R/U to pull casing. Pull casing from 5875' MD to 5723' MD. 15:45 16:15 0.50 5,723 5,723 INTRM3 CASING CIRC T Attempt to establish circulation at .5 bpm, observed 80% loss returns. 16:15 17:00 0.75 5,723 5,463 INTRM3 CASING PULD T POOH with casing from 5723' to 5463' MD, observing well breathing while POOH. 17:00 17:45 0.75 5,463 5,463 INTRM3 CASING CIRC T Attempt to establish circulation at 33 gpm, 400 psi, no returns 100% losses. 17:45 18:45 1.00 5,463 5,203 INTRM3 CASING PULD T POOH with casing from 5463' to 5203' MD, well breathing back on TOH. 18:45 19:00 0.25 5,203 5,203 INTRM3 CASING CIRC T Attempt to establish circulation at 1 bpm, 400 psi, no returns 100% losses. 19:00 20:00 1.00 5,203 4,908 INTRM3 CASING PULD T POOH with casing from 5203' to 4908' MD, well breathing back on TOH. P/U=162k 20:00 20:30 0.50 4,908 4,908 INTRM3 CASING CIRC T Attempt to establish circulation at .5 bpm, 400 psi, no returns 100% losses. 20:30 21:15 0.75 4,908 4,489 INTRM3 CASING PULD T POOH with casing from 4908' to 4489' MD, well breathing back on TOR P/U=153k 21:15 21:30 0.25 4,489 4,489 INTRM3 CASING CIRC T Attempt to establish circulation at .5 bpm, 400 psi, slight returns, 95% losses. 21:30 23:30 2.00 4,489 3,837 INTRM3 CASING PULD T POOH with casing from 4489' to 3837' MD, well breathing back on TOR P/U=138k, S/0=110k 23:30 00:00 0.50 3,837 3,837 INTRM3 CASING CIRC T Establish circulation @ .5 bpm 325 psi, srtage to 1.5 bpm, 350 psi. Slight returns, 90% losses. Total lost to formation today 87.5 bbl. 2/02/2014 Pull 7-5/8" casing to 2977' MD to establish circ. Condition and RBIH, staging in hole conditioning mud to 7060' MD, full circulation. 00:00 01:15 1.25 3,837 3,688 INTRM3 CASING PULL T PJSM POOH L/D 7-5/8" casing f/ 3837' to 3688'. Attempt to establish circulation @ 1.5 bpm=350 psi, 75% losses. 01:15 02:15 1.00 3,688 3,502 INTRM3 CASING PULL T POOH L/D 7-5/8" casing f/ 3688' to 3502'. Attempt to establish circulation @ 1.5 bpm=350 psi, 70% losses. OW+z :g7 N9 _, U1i� IPI G"ik `*��6piiii Ohl �� l From To Dur S. De th E. Depth Phas6 Code Subcode T Comment 02:15 04:00 1.75 3,502 2,977 INTRM3 CASING PULL T POOH L/D 7-5/8" casing f/ 3502' to 2977'. Establish circulation @ 1.0 bpm=350 psi, 50% losses. Actual displacement= 8.89 bbls, calculated displacement= 9.23 bbls. 04:00 05:15 1.25 2,977 2,977 INTRM3 CASING CIRC T Circulate and condition mud @ 1.5 bpm,= 350 psi, 13% flow, Stage pumps to 2.0 bpm=390 psi, 16% flow, 2.5 bpm= 350 psi, 31 % flow, 3.5 bpm= 300 psi, 49% flow. Circulate out thick mud ( 250 FV, 11.2 ppg ) full returns observed at surface after circulation. 05:15 06:45 1.50 2,977 3,799 INTRM3 CASING RNCS T RIH w/ 7-5/8" casing f/ 2977' to 3799'. 06:45 08:30 1.75 3,799 3,799 INTRM3 CASING CIRC T CBU, stage pumps up f/ 1.5 bpm to 5 bpm= 400 psi, 45% flow. Reduced mud weight on surface f/10.6 ppg to 10.3 ppg. No losses observed. 08:30 09:00 0.50 3,799 3,983 INTRM3 CASING RNCS T RIH w/ 5 joints of 7-5/8" casing to 3983'. 09:00 09:45 0.75 3,983 3,983 INTRM3 CASING CIRC T CBU, stage pumps up f/ 1.5 bpm to 5 bpm= 400 psi, 45% flow. Maintaining 10.3 ppg in suction pit, 5 bbls lost while CBU 09:45 10:15 0.50 3,983 4,167 INTRM3 CASING RNCS T RIH w/ 5 joints of 7-5/8" casing to 4167' MD. 10:15 10:30 0.25 4,167 4,167 INTRM3 CASING RNCS T Establish circualtion, stage pumps up to 4 bpm= 300 psi, 43% flow. Pump 60 bbls, no losses. 10:30 11:00 0.50 4,167 4,365 INTRM3 CASING RNCS T RIH w/ 5 joints of 7-5/8" casing to 4365'. Actual displacement= 10.2 bbls, calculated displacement= 15.37 bbls. 5.1 bbls loss while tripping f/ 2977' to 4365' MD. 11:00 12:00 1.00 4,365 4,365 INTRM3 CASING CIRC T CBU, stage pumps up f/ 1.5 bpm to 5 bpm=400 psi, 45% flow. P/U=140K, S/0=1 12K. Losses from 0:00 to 12:00= 29.3 bbls. 12:00 12:15 0.25 4,365 4,569 INTRM3 CASING RNCS T RIH w/ 5 joints of 7-5/8" casing to 4569' M D. 12:15 12:30 0.25 4,569 4,569 INTRM3 CASING CIRC T Establish circualtion, stage pumps up to 3.5 bpm, 300 psi, 40% flow. Pump 50 bbls, no losses. 12:30 13:00 0.50 4,569 4,779 INTRM3 CASING RNCS T RIH w/ 5 joints of 7-5/8" casing to 4779' MD. 13:00 14:15 1.25 4,779 4,779 INTRM3 CASING CIRC T CBU, stage pumps up f/ 1.5 bpm to 5 bpm= 400 psi, 45% flow. Maintaining 10.3 ppg in suction pit, no losses. 14:15 15:15 1.00 4,779 5,203 INTRM3 CASING RNCS T RIH 5 its F/4779' T/ 5203' MD 15:15 16:30 1.25 5,203 5,203 INTRM3 CASING CIRC T CBU, Stage pumps up F/ 1.5 bpm T/ 5 bpm, 300 psi T/ 420 psi, 45% F/0, No losses 16:30 17:15 0.75 5,203 1 5,636 INTRM3 CASING RNCS T RIH 10 its, F/ 5203'T/ 5636' MD �. -77 M �,e t4 Time Logs Date From To Dur S. De th E. De th Phase" Code Subcode TComment 17:15 18:30 1.25 5,636 5,636 INTRM3 CASING CIRC T CBU, Stage pumps up F/ 1.5 bpm T/ 5 bpm, 300 psi T/ 425 psi, 45% F/O, No losses. 18:30 19:15 0.75 5,636 6,050 INTRM3 CASING RNCS P RIH F/5636' to 6050' MD 19:15 19:45 0.50 6,050 6,050 INTRM3 CASING CIRC P Break circ. Stage up to 3.5 bpm, 425 psi, 43% F/0, 3 bbl loss, 61 bbl circulated. 19:45 20:30 0.75 6,050 6,461 INTRM3 CASING RNCS P RIH F/ 6050'T/ 6461' MD 20:30 21:00 0.50 6,461 6,461 INTRM3 CASING CIRC P Break circulation, stage up T/ 4 bpm, 475 psi, 40% F/0, minor loss observed bbl loss, 50 bbl circulated 3 bbl loss. 21:00 21:30 0.50 6,461 6,657 INTRM3 CASING RNCS P RIH F/ 6461, to 6657' MD 21:30 22:45 1.25 6,657 6,657 INTRM3 CASING CIRC P CBU @ 6657' MD, stage up from 1 bpm to 5 bpm, 475 psi, 47% Flow out, slight loss observed. 22:45 23:30 0.75 6,657 7,060 INTRM3 CASING RNCS P RIH 10 jts from 6657' to 7060' MD, P/U=210k, S/O=134k. Calc Disp=29.8 bbl, Actual Disp=26.78 bbl. 23:30 00:00 0.50 7,060 7,060 INTRM3 CASING CIRC P Establish circulation, 1.5 bpm 400 psi, 15% flow out. Total lost for tour=60.6 bbl Total lost for day=89.9 bbl Cumulative lost for section= 177.4 bbl 2/03/2014 Run 7-5/8" casing to bottom, circulate and condition. Land and cement casing, set and test packoff-good. 13.2 LOT and annular flush on 10-3/4" x 7-5/8". Rig up to FP. 00:00 00:45 0.75 7,060 7,493 INTRM3 CASING RNCS P RIH F/7060' MD T/7493' MD 00:45 02:15 1.50 7,493 7,493 INTRM3 CASING CIRC P CBU staging F/1.5 bpm T/5 bpm. 575 psi, 45% flow. slight losses. 02:15 04:45 2.50 7,493 8,559 INTRM3 CASING RNCS P RIH F/7493' MD T/8559' MD. Tight spot @8462' Break Circulation @ 1.5 bpm, 350 psi,40% flow, Worked through tight spot. 04:45 07:15 2.50 8,559 8,559 INTRM3 CASING CIRC P CBU 2X Stagging F/1.5 bpm T/5 bpm. 550 psi, 47% flow, S/O 135k, P/U 230k. 07:15 08:30 1.25 8,559 8,802 INTRM3 CASING RNCS P Wash down casing F/8559' T/8802' @ 2 bpm, 300-400 psi, 25% flow, P/U 248k, S/O 130k. No losses Act.= 16.78 Calc.= 19.75 08:30 09:15 0.75 8,802 8,831 INTRM3 CASING RNCS P PJSM, M/U and land hanger @ 8830.7' MD, R/D Franks fill tool, blow down top drive, M/U cement head. 09:15 11:15 2.00 8,831 8,831 INTRM3 CEMEN' CIRC P Circ. and Condition mud stagging F/2 bpm T/5 bpm, 550 psi, 46% flow. @ 6 bpm 600 psi, 48% flow, No losses 11:15 12:00 0.75 8,831 8,831 INTRM3 CEMEN- CMNT P Pump 10 bbl CW100 spacer, shut down and pressure test to 3000 psi. �_ 777 3 1 We Time Logs Date From To Dur S. De th E. De th' Phase Code ' Subcode T; Comment 12:00 14:30 2.50 8,831 0 INTRM3 CEMEN- CMNT P Pump 40Bbls. CW100 chem wash spacer, mix and pump 45.8Bbls. 12.5 ppg mud push. Shut down and 1, drop first plug, then chase w/ 118.3 Bbls of 15.8ppg Class G cement 2 ppb CemNET. Shut down drop second plug w/ 1013bls. of H2O. Displace cement with rig pumps w/ 10.3ppg mud @ 5 bpm, 120 psi, 45% flow. Reduce rate to 3 bpm to bump plug at 3.827 strokes. Pressure up to 1300 psi and hold for 5 min. Check floats (good). Full returns observed while cementing. 14:30 15:45 1.25 0 8,831 INTRM3 CEMEN- PULD P R/D cement equipment, clean and clear rig floor of casing equipment. 15:45 17:00 1.25 0 0 INTRM3 CEMEN WWSP P Drain and flush stack, set pack-off per FMC, test to 5000 psi for 10 min. witnessed (Good). 17:00 18:30 1.50 0 0 INTRM3 CEMEN RURD P Rig down long bails and elevators, R/U short bails and 5" elevators, send casing equipment down beaverslide. 18:30 20:30 2.00 0 0 INTRM3 CEMEN- SLPC P PJSM, cut and slip 186' drilling line. (Double cut) 20:30 21:15 0.75 0 0 INTRM3 CEMEN- SVRGP Service rig. 21:15 00:00 2.75 0 0 INTRM3 CEMEN PULD P PJSM, R/U and L/D 60 jts 5" Drill pipe from derrick. SIMOPS- Perform LOT on 10-3/4" x 7-5/8" annulus 13.2 ppg, flush annulus with 165 bbl fresh water. R/U LRS to freeze protect. 2/04/2014 Freeze protect annulus w/ 75Bbls. diesel. Laydown 5" DP from derrick and rack back 68 stands of 4" DP. C/O upper rams to 3.5" X 6"VBR. Test BOPE w/ 4" & 4.5" test joints, all tests 250 & 3500 psi. 00:00 08:00 8.00 0 0 INTRM3 CEMEN PULD P PJSM, L/D 5" drill pipe from derrick. SIMOPS- flush and freeze protect 10-3/4" by 7-5/8" annuals, pump 165 bbls of H2O and 75 bbls of diesel. ICP=500 psi, FCP= 1000 psi. 08:00 08:15 0.25 0 0 INTRM3 CEMEN PULD P Clean and clear rig floor, L/D mouse hole. 08:15 08:30 0.25 0 0 INTRM3 CEMEN SFTY P Hold PJSM on changing rams. 08:30 10:30 2.00 0 0 INTRM3 CEMEN' NUND P Hang SLR's in cellar and move double annulus valve to the top annulus on wellhead. C/O upper rams from 7-5/8" to 3-1/2" by 6" VBR. 10:30 11:15 0.75 0 0 INTRM3 CEMEN' RURD P Change over handling tools to 4" and P/U long mouse hole. 11:15 12:00 0.75 0 0 INTRM3 CEMEN- PULD P Strap 4" drill pipe in the shed. 12:00 18:15 6.25 0 0 INTRM3 CEMEN PULD P Make up and rack back 68 stands of 4" DP. 18:15 18:30 0.25 0 0 INTRM3 CEMEN' PULD P Clear rig floor. 18:30 19:30 1.00 0 0 1NTRM3 CEMEN- SEQP P Rig up to test BOPE Time Logs Date From To Dur S. De th E. De th Phase :' Code Subcode T Comment 19:30 00:00 4.50 0 0 INTRM3 CEMEN- BOPE P Tested BOPE with 4" & 4.5" test joints to 250 psi low and 3500 psi high. Test waived by Lou Grimaldi. #1 Top pipe rams; CV 1,12,13,14; & manual kill. #2 Upper IBOP; HCR kill; CV 9,11. #3 Lower IBOP; CV 5,8, 10. #4 Dart valve; CV 4,6,7. #5 FSV & CV 2. #6 HCR choke & kill line Demco valve. #7 Manual choke & kill HCR valves. #8 Annular #9 Lower rams #10 blind rams. Remaining tests with 4.5" test joint. #11 Annular #12 Upper VBR's 3.5" X 6". #13 Lower VBR's 2.875" X 5". Accumulator initial system 3000 psi. After closure 1800 psi. Attain 200psi = 52 sec. Attain full psi = 187 sec. N2 bottles average 2000psi. 2/05/2014 Finished picking up 4" DP with BHA 7. Tested 7-5/8" casing to 3500 psi for 30 min. Drill out shoe track and 20' of new hole. Perform LOT to a EMW of 15.3 ppg. Displaced well to 10.3 ppg Flo -Pro mud. 00:00 01:00 1.00 0 0 INTRM3 CEMEN- SEQP P Rig down test equipment, blow down all lines, & install 9.0625 wear bushing. 01:00 01:15 0.25 0 0 INTRM3 CEMEN SFTY P PJSM with SLB on picking up BHA 01:15 01:45 0.50 0 0 INTRM3 CEMEN- PULD P Stage SLB BHA on rig floor. 01:45 03:00 1.25 0 0 INTRM3 CEMEN' PULD P Pick up NMFC and HWDP to rack back in derrick. 03:00 04:45 1.75 0 141 INTRM3 CEMEN PULD P Pick up BHA #6 as per SLB. 04:45 05:30 0.75 141 511 INTRM3 CEMEN-TRIP P RIH from 140'- 511' MD, with NMFC & HWDP. 05:30 06:15 0.75 511 1,508 INTRM3 CEMEN-TRIP P Single in the hole from 511' - 1508' MD. 06:15 06:45 0.50 1,508 1,508 INTRM3 CEMEN-CIRC P Pulse test MWD, 200 gpm, 800 psi, 54% flow, 230 gpm, 1250 psi, 50% flow. Blow down TD. 06:45 13:15 6.50 1,508 8,650 INTRM3 CEMEN" TRIP P Single in the hole from 1508'- 8650' MD, 150k up, 85k down, calculated displacement 53.61 bbl, actual 52.67 bbls. Fill every 20 stands. 13:15 14:15 1.00 8,650 8,650 INTRM3 CEMEN-CIRC P CBU to condition mud, 260 gpm, 2200 psi, 30 rpm, 8.5k tq. Blow down TD. 14:15 15:45 1.50 8,650 8,650 INTRM3 CEMEN' PRTS P Rig up and test 7-5/8" casing, to 3500 psi, for 30 min. ow own all lines and rig down test equipment. 15:45 16:00 0.25 8,650 8,737 INTRM3 CEMEN WASH P Wash to tag cement from 8650' - 873T MD, 105 gpm, 600 psi. 16:00 20:00 4.00 8,737 8,842 INTRM3 CEMEN- DRLG P Drill cement, float collar, & shoe from 8737 - 8842' MD, 250 gpm, 2150 psi, 60 rpm, 8k tq, 125k up, 105k dwn, 110k rot, wash & ream through the shoe 3x to polish. Time Logs 'Date From To Dur; S. -De th E. De thPhase Code Subcode T Comment 20:00 20:30 0.50 8,842 8,863 INTRM3 DRILL DRLG P Drill from 8842'- 8863' MD, 6162' TVD, 125k, 105k dwn, 110k rot, 80 rpm, 11 k on, 8k off, 250 gpm, 2050 psi, 46% flow, 5-10k wob, 11.42 ecd. ADT .36, JARS .36, BIT .36 20:30 21:30 1.00 8,863 8,830 INTRM3 CEMEN- CIRC P C&C mud to 10.3, 250 gpm, 2100 psi, 46% flow, 30 rpm, 8k tq, Stand one back & lay down single. 21:30 22:30 1.00 8,830 8,830 INTRM3 CEMEN- LOT P LOT @ 8830' MD, 6160' TVD, 10.3 ppg mw, observe break over at 1600 psi, 15.3 E_M_W, bled back .7 bbl. Rig & blow down all lines. 22:30 00:00 1.50 8,830 8,863 PROD1 DRILL CIRC P Pick up single & displace to 10.3 Flo -Pro, 250 gpm, 2050 psi, 60 rpm, 10k tq, 46% flow. 2/06/2014 Directional drilled from 8863'- 10256' MD, 6181 TVD. Averaged ROP was 72 fph on bottom. 00:00 06:00 6.00 8,863 9,175 PROD1 DRILL DDRL P Drill from 8863- 9175' MD, 6163 TVD, ART 4.13, ADT 4.13, Jars 89.49, Bit 4.49, PU 155K, SO 90K, ROT 121 K, Tq on 10k, off 8k, ECD 11.41, flow 47%, WOB 15-17k, RPM 160K, GPM 250K, 2300 PSI 06:00 12:00 6.00 9,175 9,438 PROD1 DRILL DDRL P Drill from 9175'- 9438' MD, 6152' TVD, ART 3.24, ADT 3.24, Jars 92.73, Bit 7.73, PU 153K, SO 87K, ROT 117K, Tq on 9.5k, off 8k, ECD 11.38, flow 49%, WOB 5-15K, RPM 160, GPM 270, 2450 PSI SPR @ 9403' MD, 6153' TVD, MW 10.3ppg, 10:20AM #1 20 SPM = 520 PSI, 30 SPM = 760 PSI #2 20 SPM = 530 PSI, 30 SPM = 830 PSI 12:00 18:00 6.00 9,438 9,868 PROD1 DRILL DDRL P Drill from 9438'- 9868' MD, 6164' TVD, ART 5.29, ADT 5.29, Jars 98.02, Bit 13.02, PU 157K, SO 85K, ROT 115K, Tq on 10.5, off 8k, ECD 11.6, flow 48%, WOB 5-10K, RPM 140, GPM 265, 2500 PSI 18:00 00:00 6.00 9,868 10,256 PROD1 DRILL DDRL P Drill from 9868'- 10256' MD, 6181' TVD, ART 3.88, ADT 3.88, Jars 101.90, Bit 16.90, PU 162K, SO 79K, ROT 114K, Tq on 11, off 8.5k, ECD 11.67, flow 45%, WOB 10-25K, RPM 160, GPM 275, 2875 PSI SPR @ 9969' MD, 6165' TVD, MW 10.3+,19:40 #1 20 SPM = 570 PSI, 30 SPM = 850 PSI #2 20 SPM = 570 PSI, 30 SPM = 880 PSI 2/07/2014 Directional drilled from 10256'- 12220' MD, 6213' TVD. Averaged ROP was 134 fph on bottom. Page 34 of 44 Time Logs -Date From To Dur S. <De th E. De th Phase Code Subcode T Comment 00:00 06:00 6.00 10,256 10,824 PROD1 DRILL DDRL P Drill from 10256'- 10824' MD, 6205' TVD, ART 3.49, ADT 3.49, Jars 105.39, Bit 20.39, PU 165K, SO 83K, ROT 117K, Tq on 10.5, off 8.0k, ECD 11.69, flow 49%, WOB 5-10K, RPM 160, GPM 275, 2950 PSI 06:00 12:00 6.00 10,824 11,109 PROD1 DRILL DDRL P Drill from 10824'- 11109' MD, 6198' TVD, ART 3.91, ADT 3.91, Jars 109.30, Bit 24.30, PU 170K, SO 76K, ROT 118K, Tq on 11.5, off 10.0k, ECD 11.66, flow 46%, WOB 5-10K, RPM 160, GPM 265, 2870 PSI. Obtain SPR's @ 10920' MD TVD= 6210, 8:30 hours with 10.3 ppg MW. 12:00 18:00 6.00 11,109 11,660 PROD1 DRILL DDRL P Drill from 11109'- 11660' MD, 6204' TVD, ART 3.31, ADT 3.31, Jars 112.61, Bit 27.61, PU 170K, SO 77K, ROT 113K, Tq on 11, off 9.5k, ECD 11.79, flow 48%, WOB 5-10K, RPM 160, GPM 260, 2700 PSI. 18:00 00:00 6.00 11,660 12,220 PROD1 DRILL DDRL P Drill from 11660'- 12220' MD, 6213' TVD, ART 3.99, ADT 3.99, Jars 116.60, Bit 31.60, PU 180K, SO 72K, ROT 113K, Tq on 12, off 10k, ECD 12.02, flow 47%, WOB 7-10K, RPM 160, GPM 260, 2750 PSI. Obtain SPR's @ 11960' MD TVD= 6215, 21:30 hours with 10.4 ppg MW 2/08/2014 Directional drilled from 12220'- 13849' MD, 6239' TVD. Averaged ROP was 111 fph on bottom. 00:00 06:00 6.00 12,220 12,497 PROD1 DRILL DDRL P Drill from 12220'- 12497' MD, 6216' TVD, ART 4.50, ADT 4.50, Jars 121.10, Bit 36. 10, PU 190K, SO 57K, ROT 120K, Tq on 12, off 12k, ECD 11.87, flow 47%, WOB 5-15K, RPM 160, GPM 265, 2900 PSI. 06:00 12:00 6.00 12,497 12,948 PROD1 DRILL DDRL P Drill from 12497'- 12948' MD, 6234' TVD, ART 3.49, ADT 3.49, Jars 124.59, Bit 39.59, PU 183K, SO 62K, ROT 122K, Tq on 13.5, off 12k, ECD 12.11, flow 49%, WOB 10-12K, RPM 160, GPM 265, 2900 PSI. SPR taken at 12899' MD, 6237' TVD, with 10.5+ ppg MW, at 11:20. 12:00 18:00 6.00 12,948 13,376 PROD1 DRILL DDRL P Drill from 12948'- 13376' MD, 6240' TVD, ART 4, ADT 4, Jars 128.59, Bit 43.59, PU 200K, SO OK, ROT 113K, Tq on 14, off 11.5k, ECD 12.27, flow 47%, WOB 12-19K, RPM 160, GPM 262, 3100 PSI. MINNI Iia cif Time Logs Date From To Dur S.`De th E. De th Phase Code ' Subcode TComment 18:00 00:00 6.00 13,376 13,849 PROD1 DRILL DDRL P Drill from 13376'- 13849' MD, 6241' TVD, ART 3.91, ADT 3.91, Jars 132.50, Bit 47.50, PU 195K, SO OK, ROT 120K, Tq on 13, off 11.5k, ECD 12.18, flow 47%, WOB 5-10K, RPM 160, GPM 262, 3100 PSI. SPR taken at 13562' MD, 6241' TVD, with 10.5 ppg MW, at 20:45. 2/09/2014 Directional drilled 13849'- 14791' MD, 6258' TVD. Top drive, drawworks, mud pumps and centrifuge all shut down simultaneously. Able to restart all but the top drive. Trouble shot top drive while reciprocating and circulating. 00:00 06:00 6.00 13,849 14,319 PROD1 DRILL DDRL P Drill from 13849'- 14319' MD, 6248' TVD, ART 3.04, ADT 3.04, Jars 135.54, Bit 50.54, PU 185K, SO 57K, ROT 115K, Tq on 12.5, off 11.5k, ECD 12.19, flow 50%, WOB 7-10K, RPM 160, GPM 262, 3210 PSI. 06:00 10:00 4.00 14,319 14,791 PROD1 DRILL DDRL P Drill from 14319'- 14791' MD, 6255' TVD, ART 2.84, ADT 2.84, Jars 138.38, Bit 53.38, PU 185K, SO 75K, ROT 115K, Tq on 12K, off 9k, ECD 12.28, flow 49%, WOB 10K, RPM 160, GPM 260, 3200 PSI. 10:00 17:00 7.00 14,791 14,791 PROD1 DRILL RGRP T Troubleshoot electrical problems with Top Drive. Circulate 260 gpm at 3100 psi, PU 170K, SO 64K. 17:00 21:00 4.00 14,791 14,791 PROD1 DRILL RGRP T Troubleshoot electrical problems with Top Drive. Circulate 110 gpm at 750 psi, PU 160K, SO 85K. 21:00 00:00 3.00 14,791 14,791 PROD1 DRILL RGRP T Troubleshoot electrical problems with Top Drive. Circulate 260 gpm at 3100 psi, PU 160K, SO 85K. 2/10/2014 Finish troubleshooting top drive. Drill to TD 14791'- 14823' MD, 6258' TVD. CBU to BROOK Lose highline power and experience electrical issues with SCR and rig generators. CBU and repair rig gen. electrical. BROOH to shoe. Swivel packing for top drive was changed out. 00:00 01:00 1.00 14,791 14,791 PROD1 DRILL RGRP T Troubleshoot electrical problems with Top Drive. Circulate 260 gpm at 3100 psi, PU 160K, SO 85K. 01:00 02:30 1.50 14,791 14,791 PROD1 DRILL REAM P Pick up 2 jts DP and ream 14732' - 14791' MD, 235 gpm, 2790 psi, 49% flow, 160 rpm, 9-10k tq. 02:30 03:00 0.50 14,791 14,823 PROD1 DRILL DDRL P Drill from 14791'- 14823' MD, 6258' TVD, ART .28, ADT .28, Jars 138.66, Bit 53.38, PU 165K, SO 75K, ROT 115K, Tq on 12K, off 9k, ECD 12.28, flow 49%, WOB 5-71K, RPM 160, GPM 260, 3200 PSI. 03:00 03:45 0.75 14,823 14,793 PROD1 DRILL CIRC P CBU 14823'- 14793' MD, 261 GPM, 3225 PSI, 47% Flow, rack back a stand at BU. 03:45 04:45 1.00 14,793 14,793 PROD1 DRILL RGRP T Lose highline power while attaining SPR's. Start rig generators and blow fuses in radiator control boxes. Start remaining rig generator. „. F. �` '; Time Logs Date From To Dur S. iDe th E. De th': Phase Code Subcode T Comment 04:45 06:30 1.75 14,793 14,793 PROD1 DRILL CIRC T CBU with 190 GPM, 1900 PSI, 45% Flow, 160 RPM, 9.5 TQ, to clean up shakers. Trouble shoot electrical problems with rig. Decision made to POOH, blow down TD. Obtain SPR's @ 14793' MD, 6258' TVD, MW 10.5PPG, 03:45. 06:30 07:15 0.75 14,793 14,793 PROD1 DRILL OWFF P Monitor well, static. 07:15 08:00 0.75 14,793 14,417 PROD1 DRILL TRIP P POOH on elevators from 14793'- 14417' MD, fixed Gen. # 2, decision made to back ream out of hole. Actual displacement 3.06, calculated 3.78 bbls. 08:00 12:00 4.00 14,417 12,340 PROD1 DRILL REAM P Backream out of hole from 14417' -12340' MD, 230 GPM, 2500 PSI, 49% FLOW, 120 RPM, 6-71K TQ. Work tight spot at 13200' MD until cleaned up. Actual displacement 7.65, calculated 8.1 bbls. 12:00 14:00 2.00 12,340 11,400 PROD1 DRILL REAM P Backream out of hole from 12340' - 11400' MD, 230 GPM, 2500 PSI, 49% FLOW, 120 RPM, 6-7K TQ. Greased swivel packing several times to prevent leaking. 14:00 17:45 3.75 11,400 11,400 PROD1 DRILL RGRP T Change out swivel packing on top drive. 17:45 21:45 4.00 11,400 8,830 PROD1 DRILL REAM P Backream out of hole from 11400' - 8830' MD, 230 GPM, 2500 PSI, 49% FLOW, 120 RPM, 5-61K TQ. Actual displacement 53.6, calculated 24.93 bbls. 21:45 00:00 2.25 8,830 8,830 PROD1 DRILL CIRC P CBU 3X, 210 GPM, 1850 PSI, 60 RPM, 3.8K TQ, PU 115K, SO 114K. )2/11/2014 Circulate casing clean at the shoe. Change out Iron Roughneck spinners & drawworks blower motor. Trip out of hole and lay down BHA #7. Slip & cut drill line. Rig up and run 4.5" Lower Completion in the hole to 1774' MD. 00:00 01:00 1.00 8,830 8,830 PROD1 DRILL CIRC P CBU 210 GPM, 1850 PSI, 45% FLOW, 60 RPM, 3.81K TQ, 115K PU, 114 SO. 01:00 07:45 6.75 8,830 8,830 PROD1 DRILL RGRP T C/O iron roughneck spinners, blower motor and fan housing. Circulate 210 - 84 GPM, 1850 - 500 PSI, 45-17% FLOW 07:45 08:30 0.75 8,830 8,830 PROD1 DRILL CIRC P CBU 270 GPM, 2900 PSI, 49% FLOW, 120 RPM, 4K TQ, 140K PU, 100K SO. Blow down top drive. 08:30 09:00 0.50 8,830 8,830 PROD1 DRILL OWFF P Monitor well at shoe, static. 09:00 13:00 4.00 8,830 560 PROD1 DRILL TRIP P POOH from 8830'- 560' MD, actual displacement 33.83, calculated 33.0 13:00 13:30 0.50 560 560 PROD1 DRILL OWFF P Monitor well at HWDP, static. 13:30 15:30 2.00 560 140 PROD1 DRILL TRIP P Rack back 2 stands of HWDP, lay down jars & NMFC. 15:30 18:30 3.00 140 0 PROD1 DRILL TRIP P Pull sources and continue to lay down BHA. Actual displacement 30.98, calculated 24.99. Time Logs Date From To Dur S. DeiDth E. De th Phase Code Subcode T Comment 18:30 19:00 0.50 0 0 PROD1 DRILL TRIP P Clear and clean rig floor. 19:00 20:00 1.00 0 0 PROD1 DRILL SLPC P PJSM slip and cut 73' of drilling line. 20:00 20:30 0.50 0 0 PROD1 DRILL SVRG P Lubricate rig and function test BOPE's. 20:30 21:30 1.00 0 0 PROD1 RPCOM RURD P Rig up to run 4-1/2" lower completion. 21:30 00:00 2.50 0 1,774 PROD1 RPCOM RCST P PJSM, run in the hole from surface to 1774' MD with 4-1/2", 12.6#, L-80, Hydril 563 liner. Actual displacement 7.82, calculated 8.84bbl. 2/12/2014 Finish picking up 4.5" liner. Make up hanger/packer assembly and run in the hole with drill pipe. Pick up 36 jts. of HWDP and continue to RIH with DP to 13684'. Wash liner in the hole to 14460', working through several tight spots. 00:00 03:45 3.75 1,774 6,240 PROD1 RPCOM RCST P Run 4'/2' lower completion string. 145 joints of HYD 563, 12.6#, L-80. 03:45 05:00 1.25 6,240 6,240 PROD1 RPCOM RCST P Pick up Baker Seal Bore extension, Baker Flex Loc Hanger, ZXP Liner Top Packer. Mix and fill tie back with pal mix, let set up for 30 mins. 05:00 07:30 2.50 6,240 7,753 PROD1 RPCOM RUNL P RIH with lower completion with 4" DP. 07:30 08:45 1.25 7,753 8,826 PROD1 RPCOM RUNL P Pick up 2 stands of 4" 29.7# HWDP from derrick. Pick up 29 joints HWDP from pipe shed. Rabbit with 2.25" steel hollow rabbit. Actual disp= 19 bbls. Calculated 21 bbls. 08:45 11:30 2.75 8,826 8,826 PROD1 RPCOM RUNL P Circulate and condition mud system. 3 bpm, 650 psi. 5.5 bpm, 1250 psi. Circ. 2 BU strokes to achieve even mud weight in and out. 10.6 ppg. 11:30 12:00 0.50 8,826 8,856 PROD1 RPCOM RUNL P Pick up joint #30 of HWDP out of pipeshed. S/O =105k, P/U = 130k. 12:00 21:15 9.25 8,856 13,684 PROD1 RPCOM RUNL P RIH with 4.5" liner on DP from 8856' - 13684' MD, 165K PU, 75K SO. 21:15 22:00 0.75 13,684 13,935 PROD1 RPCOM RUNL P Tight spot at 13684' - 13935', stage pmps up to work through 1-2.5 bpm, 600-800 psi. 22:00 00:00 2.00 13,935 14,460 PROD1 RPCOM RUNL P Work tight spot at 13935', reduce pump rate to 1.5 bpm @ 700 psi, continue to wash to 14460'. 170k PU, 70K SO, actual displacement 29.53, calculated 29.7 bbls. 2/13/2014 Land and release lower completion, 4'/z' HYD 563. TOL=8584' MD. Displace to 10.2 brine. Weight up to 10.4 ppg brine. Observe well. Static. POOH with Baker running tool. Lay down 36 jts HWDP & 120 joints 4" DP for control line spool spacing on rig floor. Rig up and test BOPE W/ 3%" test joint. 00:00 00:30 0.50 14,460 14,823 PROD1 RPCOM RUNL P PJSM. Wash down from 14,460' to I 14,823' MD. 1.5 bpm, 700 psi. 00:30 00:45 0.25 14,823 14,816 PROD1 RPCOM RUNL P Tag bottom @ 14,823'. Pick up until berak oveer and 7 more feet. Set orange peel shoe @ 14,816' MD, TOL=8584'. 00:45 02:00 1.25 14,816 14,816 PROD1 RPCOM RUNL P Keep liner hanger on depth @ 8584'. CBU 2x's @ 2 bpm, 800 psi. 4 bpm, 1290 psi. 77777, � ` Time Logs Date From To Dur S. De th E. De th Phase '`Code Subcode TComment 02:00 03:00 1.00 14,816 14,816 PROD1 RPCOM RUNL P Slack off to obtain up/down weights. String took weight, slack off to 50k. Slips were set already. Pick up to 30k over, indicating hanger was set. Drop 29/32" ball. Pump 3 bpm, 900 psi. Slow down to 1.5 bpm, 480 psi. Ball on seat with 714 strokes. Pressure up to 1000 psi, continue up to 2500 psi. Hold. Slack of to TD weight, 35k, set 40k on hanger. Continue to pressure up to 3500 psi. Shear HRDE running tool. Hold for 5 min's. Bleed off pressure to zero. Pick up and broke over @ 110k Pick up 6 feet exposing dog sub. Slack off to 60k, setting 50k on ZXP liner top packer. Observe shear at surface. Pick up to 6 foot mark, and slack of to 50k down. Blow down TD. 03:00 03:30 0.50 14,816 8,584 PROD1 RPCOM PRTS P Rip and test liner top packer to 1500 psi, for 15 mins. Charted. Good. Blow down kill line. 03:30 04:15 0.75 8,584 8,484 PROD1 RPCOM PRTS P Lay down working single from pipe shed. Attempt to shear ball with 4100 psi with rig pump. Shut down and pressure up with test pump. Pressure up to 3500 W/ rig pump, Shear @ 4300 psi with test pump. Pick up to release the RS seal assembly. Observe weight drop off to 110k, indicating release from liner. Rack back one stand. 04:15 06:00 1.75 8,484 8,484 PROD1 RPCOM SVRG P Service rig. SIMOPS: observe bell nipple boot starting to leak. Stop operations, drain stack, change out rubber boot. 06:00 08:15 2.25 8,484 8,484 PROD1 RPCOM CIRC P PJSM. Displace well to 10.2 ppg brine from 10.6 ppg LSND. 6 bpm, 1375 psi ICP, FCP=875 psi. Obtain SPR's. Blow down top drive. SPR's: 2) 20=120 psi, 30=250 psi. 08:15 09:45 1.50 8,484 8,484 PROD1 RPCOM OWFF P Observe well for flow. Flow observed. Trickle. .3 bph for 15 mins, .28 bph for 15 mins. .26 bph for 15 mins. .15 bph for 15 mins, .1 bph for 15 mins. Went static in 90 mins. Decide to weight up to 10.4 ppg. 09:45 10:45 1.00 8,484 8,484 PROD1 RPCOM OWFF P Observe well. Static. Clean shakers, prepare to weight up to 10.4 ppg, place new product in pits, weight up pit 5 to 10.4 ppg. 10:45 12:00 1.25 8,484 8,484 PROD1 RPCOM CIRC P Circ. and condition mud system. Weight up from 10.2 ppg to 10.4 ppg. 6 bpm, 800 psi. 12:00 12:15 0.25 8,484 8,484 PROD1 RPCOM CIRC P Obttain SPR w/ pump #2 & blow down top drive. 12:15 12:45 0.50 8,484 1 8,484 PROD1 RPCOM OWFF I P I Monitor well, static. Amk Time Logs Date From To Dur S. De th E. De thPhase Code Subcode T' Comment 12:45 13:30 0.75 8,484 6,877 PROD1 RPCOM TRIP P Pull out of hole from 8484'- 6877' MD. Brine was out of balance and u -tubing. 13:30 14:15 0.75 6,877 6,877 PROD1 RPCOM CIRC P Circulate drill pipe volume at 5 bpm, with 500 psi. Monitor for 10 min. static. 14:15 15:00 0.75 6,877 5,930 PROD1 RPCOM TRIP P Continue POOH from 6877'- 5930' MD, on elevators, standing back in derrick. 15:00 21:00 6.00 5,930 0 PROD1 RPCOM PULD P Lay down drill pipe from 5930' to surface. Actual displacement 56, calculated 53.2 bbls. 21:00 21:15 0.25 0 0 PROD1 RPCOM PULD P Lay down running tool as per Baker I Rep. 21:15 21:45 0.50 0 0 PROD1 RPCOM RURD P Clear and clean rig floor. 21:45 22:30 0.75 0 0 PROD1 RPCOM SEQP P Remove wear bushing and install test plug. 22:30 00:00 1.50 0 0 PROD1 RPCOM BOPE P Rig up 3-1/2" test joint and test Annular, VBR 3-1/2 X 6, & VBR 2-7/8 X 5. All tests 250 psi and 3500 psi for 5 minutes, charted. 2/14/2014 Complete BOPE test with 3'/2' TJ. Rig up and run upper completion, 3'/2' EUE-m, L-80, 9.2#. SLB gauge, 5 GLM'S, .35" 1 wire, 270 jts, to tubing hanger. Space out. Circulate surface to surface plus a BU to ensure 10.3 ppg in and out. 00:00 00:15 0.25 0 0 PROD1 RPCOM BOPE P I Rig down BOPE test equipment. 00:15 03:00 2.75 0 0 PROD1 RPCOM RCST P PJSM. Rig up tubing running equipment, control line, mobilize control line tools to rig floor. 03:00 03:15 0.25 0 62 PROD1 RPCOM RCST P PJSM. Pick up seal assembly, 1st joint of 3'/2' EUE-m tubing. 03:15 03:30 0.25 62 62 PROD1 RPCOM RCST P Hook up control line to SLB gauge carrier. 03:30 12:00 8.50 62 4,339 PROD1 RPCOM RCST RIH with 3'/2' EUE-m production tubing from 62' to 4339'. Cannon FP clamp on each joint. (3500-A-07) 12:00 20:00 8.00 4,339 8,562 PROD1 RPCOM RCST Continue RIH from 4339'- 8562' MD, testing control line every 30 jts. TOL 90K PU, 70K SO. Actual displacement 26.96, calculated 28.62 bbls. 20:00 21:00 1.00 8,562 8,619 PROD1 RPCOM HOSO P Wash down from 8562'- 8619' MD, 1.5 bpm, 150 psi. Saw pressure increase to 350 psi, indicating seal entered SBE, pump off and bled off. Pick up 4' to circulate. 21:00 00:00 3.00 8,619 8,619 PROD1 RPCOM CIRC P Ciruclate surface to surface, plus BU to ensure a 10.3 ppg. 4 bpm at 525 psi 91 K PU, 69K SO. 2/15/2014 Space out upper completion. Terminate I wire. Test annulus, 1000 psi, charted, good. Drop 1 5/16" ball and rod. Attempt to get 4000 psi test on tubing. Leaking. Rig up Halliburton slick line and attempt to seat ball and rod. Psi test failed. Retrieve ball/rod and RHC plug.Set CA -2 plug without pressure as a proof of positive plug seat. 44 Time Logs Date From To Dur S. De th E. De th' Phase Code Subcode T Comment 00:00 02:30 2.50 8,619 8,619 PROD1 RPCOM RCST P PJSM. Space out. Lay down 3 jts of 3'/2' EUE, make up two space out pups, 10.17', 8.19', XO from 3%2 to 4'/z, 1jt 4% IBT, tubing hanger and pup, 28 foot landing joint. (Ran a total of 275- 3'/z cannon clamps, 11- 3% half clamps, 1 full and 2 half 4 cannon clamps.) 02:30 03:15 0.75 8,619 8,619 PROD1 RPCOM RCST P Terminate I wire. Test fitting to 5000 psi. Good. 03:15 04:45 1.50 8,619 8,619 PROD1 RPCOM CRIH P PJSM. Spot 40 bbls 10.35 ppg inhibited brine, chased by 71 bbls of 10.35 un-inhibited brine @ 3 bpm, 300 psi. Slow pump to 1 bpm 70 psi. Lower seals in seal bore. Shut down pump. Land hanger. 04:45 05:00 0.25 8,619 8,632 PROD1 RPCOM RURD P RILDS. (Run in lock down scerws). 05:00 05:30 0.50 8,632 8,632 PROM RPCOM PRTS P Test annulus to 1000 ps, 10 mins. Charted. Good. 05:30 06:00 0.50 8,632 8,632 PROM RPCOM PRTS P Drop 1 5/16" ball and rod. 06:00 10:00 4.00 8,632 8,632 PROD1 RPCOM PRTS T Test tubing to 4000 psi. Unable to hold 4000 for 30 mins. Test surface equipment. Good. Change out sensors. Retest 6 times. Call out slick line unit that was on standby as contingency. 10:00 12:00 2.00 8,632 8,632 PROM RPCOM SLKL T Hold PJSM with slick line crew. Rig up and stage tools to rig floor. 12:00 13:15 1.25 8,632 8,632 PROD1 RPCOM SLKL T Continue to rig up slick line as per HES. 13:15 15:00 1.75 8,632 8,632 PROD1 RPCOM SLKL T RIH with bell guide lid, hammer down on ball & rod several times, POOH & lay down wire line. 15:00 16:00 1.00 8,632 8,632 PROM RPCOM SLKL T Rig up and test tubing to 4000 psi on chart, leaked 450 psi in 15 min. 16:00 16:30 0.50 8,632 8,632 PROM RPCOM SLKL T Rig down test equipment. 16:30 17:00 0.50 8,632 8,632 PROD1 RPCOM SLKL T Locate cross over for for HES wire line BOP. 17:00 18:00 1.00 8,632 8,632 PROD1 RPCOM SLKL T Rig up HES wire line with BOP. 18:00 18:45 0.75 8,632 8,632 PROM RPCOM SLKL T Rig up and body test HES wire line BOPE. 18:45 19:45 1.00 8,632 8,632 PROM RPCOM SLKL T RIH with 2" SB pulling tool and retrieve ball and rod. 19:45 20:00 0.25 8,632 8,632 PROM RPCOM SLKL T Change from 2" to 3" SB pulling tool. 20:00 21:00 1.00 8,632 8,632 PROM RPCOM SLKL T RIH with 3" SB tool and retrieve RHC plug. 21:00 21:15 0.25 8,632 8,632 PROM RPCOM SLKL T Lay down RHC plug and pick up CA-2 solid body 2 part plug, length 28", max OD 2.84", packing OD 2.81. 21:15 22:30 1.25 8,632 8,632 PROM RPCOM SLKL T RIH with CA-2 plug to DS nipple. ® 7777 P Time Logs Date From To ` Dur S. De th E. De th`Phase - Code Subcode T Comment 22:30 23:15 0.75 8,632 8,632 PROD1 RPCOM SLKL T Attempt to pressure up on tubing to 1500 psi to verify setting the CA -2 plug. Pressured up to 900 psi and packing seal failed on HES line stripper. Released from CA -2 plug. 23:15 00:00 0.75 8,632 8,632 PROD1 RPCOM SLKL T POOH with plug setting tool. 2/16/2014 Finish fishing out slick line CA -2 plug, running tool and wire. Set CAT standing valve with good verification psi test. Test tubing to 4000 psi for 30 min. Test annulus to 3500 psi for 30 min. Shear out DCR-1 valve. Rig down HES slick line. 00:00 01:00 1.00 8,632 0 PROD1 RPCOM SLKL T PJSM. Rig down slick line. Line parted. Fish in the hole. Run #3. 01:00 02:00 1.00 0 0 PROD1 RPCOM SLKL T Rig up cement line, head pin. Test equipment. Pressure tubing up to 1000 psi. Shut in, lost 200 psi in 10 mins. Bleed off. 02:00 02:30 0.50 0 0 PROD1 RPCOM SLKL T Rig down test equipment. 02:30 03:15 0.75 0 0 PROD1 RPCOM SLKL T Rebuild slick line pack off, rig up slick line. 03:15 05:00 1.75 0 0 PROD1 RPCOM SLKL T Slick line run #4. Impression block. RIH, Land on depth @ DS nipple 7844'. Contact top of fish, set down to make impression. POOH to surface. 05:00 06:45 1.75 0 0 PROD1 RPCOM SLKL T Inspect impression block. See impression of wire profile. Slick line run #5 make up split skirt tool, RIH to 7850'. POOH. 06:45 07:15 0.50 0 0 PROD1 RPCOM SLKL T Lay down fish, solid body CA2 plug with running tool, did not set.(2.84" OD No Go.) 07:15 08:15 1.00 0 0 PROD1 RPCOM SLKL T Make up tools. CAT standing valve. (2.85" OD No Go). 08:15 10:00 1.75 0 0 PROD1 RPCOM SLKL T Slick line run #6 RIH with "DS" CAT Standing valve. Stopped @ 7350' MD. Pick up attempt to assist with pump. 200 psi. No luck. POOH. 10:00 11:30 1.50 0 0 PROD1 RPCOM SLKL T POOH with CAT Standing valve. L/D tools. Bring magnet, knuckle joint, two wire brushes to rig floor. 11:30 12:30 1.00 0 0 PROD1 RPCOM SLKL T Makeup magnet, knuckle joint, two brushes. Crew change. PJSM with new Slickline crew, and new Doyon crew. 12:30 14:30 2.00 0 0 PROD1 RPCOM SLKL T Slick line run #7. Magnet, brushes. RIH to 7860'. Past DS profile. POOH slowly. No resistance seen @ 7350'. Retrieved 5' of wire tangled on brushes. 14:30 15:45 1.25 0 0 PROD1 RPCOM SLKL T Rebuild burshes for next run. 15:45 17:30 1.75 0 0 PROD1 RPCOM SLKL T Slick line run #8 rerun magnet, brushes and 2.83 gauge ring. POOH with a 4" long piece of wire. 17:30 19:15 1.75 0 0 PROD1 RPCOM SLKL T Slick line run #9 clean brushes and rerun same assembly. POOH with no debris. �_ r Time Logs Date From To Dur S.'De th E. De th Phase Code Subcode TComment 19:15 19:30 0.25 0 0 PROD1 RPCOM SLKL T Change slick line assembly to run CAT standing valve. 19:30 21:30 2.00 0 0 PROM RPCOM SLKL T Slick line run #10 with CAT standing valve. Set valve and test to 1500 psi for 10 minutes, with slick line in the hole. Test good and slick line POOH. 21:30 21:45 0.25 0 0 PROM RPCOM SLKL T Rig down slick line and set off to the side. 21:45 23:15 1.50 0 0 PROD1 RPCOM DHEQ P Rig up and test tubing to 4000 psi for 30 minutes, charted. Bleed tubing to 2000 psi and shut in. Pressure test inner annulus to 3500 psi for 30 minutes, charted. Bleed off tubing and shear out DCR-1 valve. 23:15 00:00 0.75 0 0 PROD1 RPCOM RURD T Rig down and lay down HES slick line tools. 2!17/2014 Nipple down BOPE. Terminate 1 -wire. Nipple up adaptor flange and tree. Test. 5000 psi for 15 mins. Pull 2 way check. Freeze protect with 91.5 bbls diesel. Let U-tube while laying down drill pipe. Prepare for rig move. 00:00 01:00 1.00 0 0 PROM RPCOM PRTS P PJSM. Rig down test equipment, lay down landing joint, set two way check, test from below to 2500 psi. Record on chart for 10 mins. 01:00 01:30 0.50 0 0 PROD1 RPCOM OWFF P Observe wll for 30 mins.Static. 01:30 02:30 1.00 0 0 PROM RPCOM NUND P PJSM Nipple down BOPE. 02:30 04:15 1.75 0 0 PROM RPCOM THGR P Dress tubing hanger, tie in I wire, and test. 04:15 05:30 1.25 0 0 PROD1 RPCOM NUND P Nipple up adaptor flange and tree. 05:30 06:00 0.50 0 0 PROM RPCOM PRTS P Test adaptpr flange and seals to 5000 psi for 15 mins. 06:00 07:30 1.50 0 0 PROM RPCOM PRTS P Fill tree with diesel, rig up test equipment, test tree to 250 psi, low for 5 mins, 5000 psi high for 10 mins. Good test. Rig down test equipment. 07:30 08:00 0.50 0 0 PROM RPCOM RURD P Rig up and pull two way check. 08:00 09:00 1.00 0 0 PROM RPCOM RURD P PJSM. Rig up to allow well to U-tube, and circulate freeze protection. 09:00 10:30 1.50 0 0 PROM RPCOM FRZP P PJSM with Little Red. Pressure test lines to 2500 psi. Pump 91.5 bbls diesel LEPD down IA, taking returns up tubing and into the rock washer. ICP=450 psi, FCP=950 psi. 10:30 11:00 0.50 0 0 PROD1 RPCOM RURD P Rig down Little Red hot oil truck, Blow down lines, line up to U -Tube @ 10:40 hrs. 350 psi tubing pressure. 11:00 12:00 1.00 0 0 PROM RPCOM PULD P PJSM. Lay down drill pipe, pick up thread protectors, set mouse hole, change out elevators, clear rig floor. 12:00 15:30 3.50 0 0 PROM RPCOM PULD P Lay down DP from derrick. 15:30 17:30 2.00 0 0 PROD1 RPCOM MPSP P Rig up and test lubricator to 1500 psi, set BPV with lubricator. 17:30 20:15 2.75 0 0 PROM RPCOM PULD P Continue laying down DP from derrick, total of 306 joints. _Y m 4 : v , t Page 43 of 4-1 Schwherger / Slot: UWI / API#: Survey Name: Survey Date: Tort / AHD I DDI I ERD Ratio: Coordinate Reference System: Location Let I Long: Location Grid WE Y/X: CRS Grid Convergence Angle: (Grid Scale Factor: Version / Patch: ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit2 Kuparuk 2E Pad / 2E-04 2E-04 2E-04 10350556 / 50-029-23505-00 2E-04 Final February 12, 2014 240.860 ° / 11548.718 ft / 6.819 /1.845 NAD27 Alaska State Plane, Zone 04, US Feet N 70° 15'31.23428", W 149° 45' 27.90435" N 5944222.370 RUS, E 529971.590 HUS 0.2280 ° 0.99990102 2.7.1043.0 2E-04 Final Survey Report (Def Survey) Survey I OLS Computation: Vertical Section Azimuth: Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Seabed / Ground Elevation: Magnetic Declination: Total Gravity Field Strength: Gravity Model: Total Magnetic Field Strength: Magnetic Dip Angle: Declination Date: Magnetic Declination Model: North Reference: Grid Convergence Used: 180.000 " (True North) 0.000 It, 0.000 fl RKB 132.520 ft above Mean Sea Level 105.1 ft above Mean Sea Level 19.524 ° 1001.9572mgn (9.80665 Based) GARM 57605.129 nT 80.861 ° January 10, 2014 BGGM 2013 True North 0.0000 ° Total Corr Mag NorthaTrue North: 19.5239 ° MD Incl Azim True TVDSS TVD VSEC AHD Closure NS EW DLS Northing Easting Latitude Longitude Comments (ft) (°I (9 (ftl (ft) (ft) (ft) (ft) Ift) (ft) (°/100ft) (ftUS) (ftUSI (1 (°I _ Tie -In 0.00 0.00 0.00 -132.52 0.00 0.00 0.00 0.00 0.00 0.00 NIA 5944222.37 529971.59 70.25867619 -149.75775121 Ground Level 27.42 0.00 0.00 -105.10 27.42 0.00 0.00 0.00 0.00 0.00 0.00 5944222.37 529971.59 70.25867619 -149.75775121 - 108.00 0.06 36.51 -24.52 108.00 -0.03 0.04 0.04 0.03 0.03 0.07 5944222.40 529971.61 70.25867628 -149.75775101 185.00 0.23 84.01 52.48 185.00 -0.08 0.23 0.22 0.08 0.20 0.25 5944222.45 529971.79 70.25867641 -149.75774957 277.00 0.24 99.28 144.48 277.00 -0.07 0.60 0.58 0.07 0.58 0.07 5944222.44 529972.17 70.25867638 -149.75774655 368.00 0.81 250.29 235.48 368.00 0.18 1.18 0.24 -0.18 0.16 1.13 5944222.19 529971.75 70.25867570 -149.75774992 462.00 1.81 254.70 329.45 461.97 0.79 3.33 2.06 -0.79 -1.90 1.07 5944221.57 529969.70 70.25867402 -149.75776655 555.00 2.60 261.79 422.38 554.90 1.48 6.90 5.60 -1.48 -5.40 0.90 5944220.87 529966.19 70.25867214 -149.75779487 649.00 3.29 262.89 516.26 648.78 2.12 11.73 10.41 -2.12 -10.19 0.74 5944220.21 529961.41 70.25867040 -149.75783356 742.00 4.29 267.82 609.05 741.57 2.58 17.87 16.52 -2.58 -16.31 1.13 5944219.72 529955.29 70.25866913 -149.75788305 768.37 4.26 268.70 635.35 767.87 2.64 19.84 18.47 -2.64 -18.28 0.27 5944219.66 529953.32 70.25866897 -149.75789893 861.02 5.00 270.12 727.70 860.22 2.71 27.32 25.90 -2.71 -25.76 0.81 5944219.56 529945.85 70.25866878 -149.75795937 952.98 6.03 267.11 819.23 951.75 2.95 36.15 34.71 -2.95 -34.59 1.16 5944219.29 529937.02 70.25866814 -149.75803074 1045.63 8.48 262.05 911.13 1043.65 4.14 47.85 46.40 -4.14 -46.22 2.73 5944218.05 529925.40 70.25866488 -149.75812471 1138.37 9.82 261.31 1002.69 1135.21 6.28 62.59 61.13 -6.28 -60.81 1.45 5944215.85 529910.82 70.25865904 -149.75824263 1231.19 12.83 259.70 1093.69 1226.21 9.32 80.82 79.32 -9.32 -78.77 3.26 5944212.74 529892.86 70.25865073 -149.75838785 1323.55 14.43 258.91 1183.45 1315.97 13.36 102.58 101.05 -13.36 -100.16 1.74 5944208.61 529871.50 70.25863967 -149.75856067 1416.11 15.28 255.48 1272.92 1405.44 18.64 126.30 124.69 -18.64 -123.28 1.32 5944203.24 529848.39 70.25862526 -149.75874756 1508.96 15.96 254.26 1362.34 1494.86 25.17 151.30 149.55 -25.17 -147.41 0.81 5944196.61 529824.29 70.25860742 -149.75894258 1601.36 15.69 250.03 1451.24 1583.76 32.89 176.49 174.51 -32.89 -171.39 1.28 5944188.81 529800.35 70.25858634 -149.75913630 1693.55 16.64 243.99 1539.79 1672.31 42.93 202.13 199.64 -42.93 -194.97 2.09 5944178.67 529776.82 70.25855889 -149.75932688 1787.15 18.73 233.93 1628.98 1761.50 57.66 230.50 226.62 -57.66 -219.17 3.95 5944163.84 529752.68 70.25851865 -149.75952245 1877.58 20.18 229.76 1714.25 1846.77 76.29 260.61 254.51 -76.29 -242.81 2.22 5944145.12 529729.11 70.25846776 -149.75971353 1972.34 26.22 223.02 1801.32 1933.84 102.18 297.88 288.31 -102.18 -269.60 6.95 5944119.13 529702.43 70.25839703 -149.75993002 2064.63 29.71 221.85 1882.82 2015.34 134.13 341.15 327.50 -134.13 -298.78 3.83 5944087.06 529673.38 70.25830973 -149.76016581 2157.53 30.38 219.72 1963.24 2095.76 169.35 387.66 370.16 -169.35 -329.15 1.36 5944051.73 529643.15 70.25821351 -149.76041125 2247.55 35.09 216.01 2038.95 2171.47 207.81 436.32 414.75 -207.81 -358.93 5.68 5944013.15 529613.53 70.25810843 -149.76065189 2342.42 37.42 214.14 2115.45 2247.97 253.74 492.41 466.23 -253.74 -391.14 2.72 5943967.10 529581.50 70.25798297 -149.76091221 2435.19 40.13 212.75 2187.77 2320.29 302.22 550.50 519.98 -302.22 -423.14 3.07 5943918.50 529549.70 70.25785051 -149.76117078 2527.56 40.78 210.33 2258.06 2390.58 353.30 610.43 575.65 -353.30 -454.48 1.84 5943867.30 529518.57 70.25771097 -149.76142402 2619.23 41.71 207.23 2326.99 2459.51 406.26 670.86 631.56 -406.26 -483.55 2.45 5943814.23 529489.71 70.25756627 -149.76165897 2712.35 41.84 206.99 2396.44 2528.96 461.40 732.90 689.15 -461.48 -511.82 0.22 5943758.90 529461.66 70.25741540 -149.76188740 2804.38 47.20 205.24 2462.03 2594.55 519.42 797.40 749.39 -519.42 -540.17 5.97 5943700.86 529433.54 70.25725712 -149.76211646 2898.39 48.02 205.84 2525.41 2657.93 582.06 866.83 814.75 -582.06 -570.11 0.99 5943638.10 529403.86 70.25708597 -149.76235835 2991.00 46.70 205.51 2588.15 2720.67 643.46 934.96 879.54 -643.46 -599.63 1.45 5943576.59 529374.59 70.25691823 -149.76259685 3082.87 47.22 205.95 2650.85 2783.37 703.95 1002.10 943.88 -703.95 -628.78 0.67 5943516.00 529345.68 70.25675298 -149.76283238 3176.58 47.55 206.32 2714.30 2846.82 765.86 1071.06 1010.46 -765.86 -659.16 0.46 5943453.97 529315.55 70.25658383 -149.76307782 3269.24 47.60 204.57 2776.81 2909.33 827.62 1139.46 1076.59 -827.62 -688.54 1.40 5943392.10 529286.42 70.25641510 -149.76331522 3362.37 47.50 203.83 2839.67 2972.19 890.30 1208.18 1142.93 -890.30 -716.71 0.60 5943329.32 529258.50 70.25624386 -149.76354280 Drilling Office 2.7.1043.0 Kuparuk River Unit2\Kuparuk 2E Pad\2E-04\2E-04\2E-04 Final 3/10/2014 1:33 PM Page 1 of 4 MD Incl Azim True TVDSS TVD: VSEC AHD Closure NS EW DLS Northing Easting Latitude Longitude Comments (1111 (1 (°I (ft) (f!1 (ft) (ft) (110 (ft) (ft) f*1100ft) MUS) MUS) M CI 3454.33 47.52 205.02 2901.78 3034.30 952.04 1275.99 1208.73 -952.04 -744.75 0.95 5943267.47 529230.71 70.25607519 -149.76376933 3547.63 47.66 205.02 2964.71 3097.23 1014.46 1344.87 1275.94 -1014.46 -773.88 0.15 5943204.94 529201.83 70.25590464 -149.76400471 3638.87 48.02 204.92 3025.95 .3158.47 1075.77 1412.51 1342.08 -1075.77 -802.43 0.40 5943143.52 : 529173.52 70.25573714 -149.76423537 3732.23 47.86 205.68 3088.49 3221.01 1138.44 1481.82 1410.09 -1138.44 -832.05 0.63 5943080.75 529144.16 70.25556593 -149.76447467 3755.85 48.04 205.59 3104.31 3236.83 1154.25 1499.36 1427.34 -1154.25 -839.64 0.81 5943064.91 529136.63 70.25552273 -149.76453597 10-3/4" Surface 3816.30 48.64 20526: 3144.49 3277.01 1195.04: 1544.52 1471.75 -1195.04 -859.03 1.07 5943024.05 529117.41 70.2554.1129 -149.76469259 Casing 3853.96 49.01 205.05 3169.29 3301.81 1220.70 1572.87 7499.62 -7220.70 -871.08 1.07 5942998.34 529105.46 70.25534119 -149.76476992 3908.96 48.61 205.60 3205.51 3338.03 1258.11 1614.26 1540.38 -1258.11 -886.78 1.05 5942960.86 529087.91 70.25523898 -149.76493294 4000.85 48.40 ..:206.92 3266.39 3398.91 : 1319.83 1683.08 1608.39 -1319.83 -919.23 1.10 5942899.03 529057.71 70.25507035 -149.76517892 4094.79 47.86 207.34 3329.09 3461.61 1382.08 1753.03 1677.74 : -1382.08 -951.13 0.66 5942836.65 529026.06 70.25490026 -149.76543661 4187.26 47.78 206.46 3391.18 3523.70 1443.19 1821.56 1745.68 -1443.19 -982.13 0.71 5942775.43 528995.31 70.25473330 -149.76568705 4280.26 47.87 206.59 3453.62 3586.14 1504.86 1890.48 1814.00 -1504.86 -1012.91 0.14 5942713.64 528964.78 70.25456482 -149.76593569 4373.12 47.73 207.26 3516.00 3648.52 1566.19 1959.27 1882.29 -1566.19 -1044.06 0.56 5942652.19 528933.87 70.25439725 -149.76618732 4465.14 47.60 208.15 3577.97 3710.49 1626.42 2027.29 1949.96 -1626.42 -1075.69 0.73 5942591.85 528902.49 70.25423271 -149.76644277 4556.94 47.83 209.29 3639.74 3772.26 1685.97 2095.21 2017.64 -1685.97 -1108.32 0.95 5942532.17 528870.10 70.25408999 -149.76670639 4649.38 47.64 209.73 3701.91 3834.43 1745.51 2163.62 2085.91 -1745.51 -1142.02 0.41 5942472.51 528836.64 70.25390733 -149.76697858 4742.11 47.77 209.72 3764.31 3896.83 1805.07 2232.21 2154.38 -1805.07 -1176.03 0.14 5942412.81 528802.87 70.25374459 -149.76725331 4834.39 47.75 210.04 3826.35 3958.87 1864.31 2300.53 2222.59 -1864.31 -1210.06 0.26 5942353.45 528769.08 70.25358274 -149.76752823 4926.71 47.69 209.68 3888.46 4020.98 1923.55 2368.83 2290.80 -1923.55 -1244.07 0.30 5942294.08 528735.31 70.25342090 -149.76780292 5020.11 47.58 208.49 3951.39 4083.91 1983.85 2437.84 2359.66 -1983.85 -1277.61 0.95 5942233.65 528702.01 7025325613 -149.768073811 5113.35 47.76 206.94 4014.18 4146.70 2044.87 2506.77 2428.32 -2044.87 -1309.67 1.24 5942172.51 528670.20 70.25308941 -149.76833278 ..5206.14 48.09 206.06 4076.36 4208.88 2106.51 2575.64 2496.81 -2106.51 -1340.40 0.79 5942110.76 528639.72 70.25292101 -149.76858098 5298.54 48.19 205.73 4138.02 4270.54 2168.42 2644.46 2565.19 -2168.42 -1370.45 0.29 5942048.73 528609.91 70.25275187 -149.76882371 5390.24 48.33 206.59 4199.07 4331.59 2229.83 2712.88 2633.23 -2229.83 -1400.62 0.72 5941987.21 528580.00 70.25258407 -149.76906735 Tie-In 5483.34 48.28 205.93 4261.00 4393.52 2292.17 2782.40 2702.39 -2292.17 -1431.38 0.53 5941924.75 528549.49 70.25241374 -149.76931575 5576.27 48.90 202.98 4322.48 4455.00: 2355.61 2852.09: 2771.48 -2355.61 -1460.22 2.47 5941861.21 528520.91 70.25224043 -149.76954866 5667.77 48.81 194.85 4382.74 4515.26 2420.69 2920.94 2838.59 -2420.69 -1482.52 6.69 5941796.05 528498.86 70.25206262 -149.76972875 5761.81 49.12 193.95 4444.48 4577.00 2489.39 2991.88 2906.47 -2489.39 -1500.16 0.79 5941727.28 528481.50 70.25187491 -149.76987115 5854.75 49.20 195.97 4505.26 4637.78 2557.32 3062.19 2974.08 -2557.32 -1518.31 1.65 5941659.29 528463.62 70.25168934 -149.77001768 5947.13 49.17 198.25 4565.65 4698.17 2624.13 31.32.10 3042.07 -2624.13 -1538.88 1.87 5941592.40 528443.32 70.25150680 -149.77018373 6039.77 48.96 200.30 4626.35 4758.87 2690.19 3202.08 3110.77 -2690.19 -1561.98 1.69 5941526.26 528420.49 70.25132633 -149.77037023 6133.38 49.05 202.23 4687.76 4820.28 2756.02 3272.73 3180.59 -2756.02 -1587.60 1.56 5941460.33 528395.13 70.25114645 -149.77057712 6225.72 48.82 204.38 4748.42 4880.94 2819.96 3342.35 3249.74 -2819.96 -1615.14 1.77 5941396.29 528367.85 70.25097177 -149.77079949 6318.11 48.64 207.21 4809.37 4941.89 2882.47 3411.78 3319.00 -2882.47 -1645.35 2.31 5941333.67 528337.89 70.25080097 -149.77104344 6410.63 47.81 209.00 4871.01 5003.53 2943.33 3480.78 3387.97 -2943.33 -1677.84 1.70 5941272.68 528305.64 70.25063469 -149.77130585 6504.37 47.65 209.48 4934.06 5066.58 3003.86 3550.14 3457.33 -3003.86 -1711.72 0.42 5941212.03 528272.00 70.25046931 -149.77157946 6596.95 47.44 209.88 4996.55 5129.07 3063.20 3618.45 3525.64 -3063.20 -1745.55 0.39 5941152.56 528238.42 70.25030716 -149.77185258 6689.39 47.40 209.44 5059.10 5191.62 3122.35 3686.52 3593.71 -3122.35 -1779.23 0.35 5941093.28 528204.98 70.26014555 -149.77212457 6781.58 48.20 208.51 5121.03 5253.55 3182.10 3754.81 3661.99 -3182.10 -1812.31 1.15 5941033.41 528172.14 70.24998231 -149.77239169 6873.58 49.74 208.13 5181.42 5313.94 3243.19 3824.21 3731.37 -3243.19 -1845.23 1.70 5940972.19 528139.47 70.24981538 -149.77265751 6966.91 51.57 207.39 5240.59 5373.11 3307.06 3896.38 3803.51 -3307.06 -1878.84 2.05 5940908.20 528106.11 70.24964087 -149.77292890 7058.53 52.92 207.18 5296.68 5429.20 3371.44 3968.82 3875.89 -3371.44 -1912.04: 1.48 5940843.69 528073.17 70.24946497 -149.77319700 7151.63 53.87 206.57 5352.20 5484.72 3438.10 4043.56 3950.54 -3438.10 -1945.83 1.15 5940776.90 528039.66 70.24928282 -149.77346976 7244.88 54.97 205.89 5406.45 5538.97 3506.13 4119.39 4026.26 -3506.13 -1979.34 1.32 5940708.74 528006.41 70.24909694 -149.77374036 7337.93 56.03 205.37 5459.16 5591.68 3575.27 4196.08 4102.77 -3575.27 -2012.51 1.23 5940639.48 527973.52 70.24890804 -149.77400814 7430.28. 57.26 204.19 5509.93 5642.45 : 3645.31 4273.21 : 4179.67 -3645.31 -2044.84 1.71 5940569.32 527941.48 70.24871668 -149.77426910 7524.94 59.12 203.27 5559.83 5692.35 3718.94 4353.65 4259.73 -3718.94 -2077.20 2.13 5940495.56 527909.41 70.24851548 -149.77453037 7616.18 59.66 202.76 5606.29 5738.81 3791.22 4432.18 4337.81 -3791.22 -2107.90 0.76 5940423.18 527879.01 70.24831800 -149.77477820 7708.31 60.07 203.00 5652.54 5785.06 3864.63 4511.86 4417.03 -3864.63 -2138.88 0.50 5940349.65 527848.32 70.24811743 -149.77502827 7801.59 60.60 201.99 5698.71 5831.23 3939.51 4592.91 4497.58 -3939.51 -2169.89 1.10 5940274.65 527817.61 70.24791282 -149.77527858 7893.92 61.68 201.68 5743.27 5875.79 4014.58 4673.77 4577.84 -4014.58 -2199.96 1.21 5940199.48 527787.84 70.24770774 -149.77552133 7986.37 63.24 200.09 5786.02 5918.54 4091.16 4755.74 4659:06. -4091.16 -2229.18 2.27 5940122.76 527758.94 70.24749849 -149.77575711 8079.85 65.32. 198.61 5826.59 5959.11 4170.62 : 4839.95 4742.20 -4170.62 -2257.07 2.64 5940043.23 5277$1.36 70.24728139 -149.77598223 8172.17 67.40 197.11 5863.61 5996.13. 4251.11 4924.52 4825.35 -4251.11 -2283.00 2.70 5939962.64 527705.76 70.24706147 -149.77619145 8265.30 69.11 195.78 5898.11 6030.63 4334.07 5011.02 4910.05 -4334.07 -2307.48 2.27 5939879.59 527681.61 70.24683481 -149.77638898 8355.28 71.02 194.91 5928.79 6061.31 4415.64 5095.61 4992.61 -4415.64 -2329.86 2.31 5939797.94 527659.56 70.24661195 -149.77656954 8445.97 73.26 193.61 5956.60 6089.12 4499.29 5181.92 5076.55 -4499.29 -2351.11 2.82 5939714.21 527638.64 70.24638339 -149.77674101 8540.58 76.37 191.17 : 5981.38 6113.90 4588.46 5273.21 5164.70 -4588.46 -2370.68 4.12 5939624.98 527619.42 70.24613978 -149.77689887 8633.90 79.38 189.60 6000.98 6133.50 4678.19 5364.44 5252.03 4678.19 -2387.12 3.62 5939535.19. 527603.34 70.24589463 -149.77703140 8726.91 81.62 188.96 6016.33 6148.85 4768.72 5456.17 5339.46 4768.72 -2401.91 2.50 5939444.61 527588.91 70.24564730 -149.77715063 8771.51. 82,96. 189.19 6022.32 6154.84 4812.36 5500.37 5381.59 4812.36 -2408.88 3.05 5939400.95 527582.12 70.24552806 -149.77720682 7-58" Casino 8630.70. 85.76: 188.63 6028.13 6160.65. 4870.55.: 5559.26 : 5437.74 .4670.55 : -2418.01 4.83 5939342.73 527573.23 70.24536909 -149.77728035 - 8869.53 87.60 188.27 6030.38 6162.90 4908.89 5598.03 5474.63 4908.89 -2423.70 4.83 5939304.37 527567.68 70.24526434 -149.77732626 8963.92 88.95 :187.84 6033.22 6165.74 5002.30 5692.37 5564.32 -5002.30 -2436.92 1.50 5939210.91 527554.84 70.24500913 -149.77743279 9058.17 91.38 187.19 6032.95 6165.47 5095.74 5786.61 5653.79 -5095.74 -2449.25 2.67 5939117.44 527542.88 70.24475386 -149.77753209 9152.95 :. 92.94 : .1.87.67 : 6029.38 6161.90 5189.65 5881.32 5743.82 -5189.65 -2461.50.. 1.72 5939023.49 527531.01 70.24449728 -149.77763075 9248.11 92.35 189.95 6024.98 6157.50 5283.58 5976.38 5834.99 -5283.58 -2476.05 2.47 5938929.51 527516.83 70.24424066 -149.77774808 9342.20 91.21 190.32 6022.06 6154.58 5376.16 6070.43 5925.89 -5376.16 -2492.60 1.27 5938836.88 527500.65 70.24398773 -149.77788148 9437.01 89.01: 189.68 6021.88 6154.40 5469.52 6165.23 6017.56 -5469.52 : -2509.07 2.42 5938743.46 527484.56 70.24373266 -149.77801418 Drilling Office 2.7.1043.0 Kuparuk River Unit2\Kuparuk 2E Pad\2E-04\2E-04\2E-04 Final 3/10/2014 1:33 PM Page 2 of 4 Survey Type: Survey Error Model: Survey Program: Drilling Office 2.7.1043.0 Def Survey ISCWSA Rev 0'"' 3-D 95.000% Confidence 2.7955 sigma Kuparuk River Unit2\Kuparuk 2E Pad\2E-04\2E-04\2E-04 Final 3/10/2014 1:33 PM Page 3 of 4 MD Incl Azim True TVDSS TVD VSEC AHD Closure NS EW DLS Northing Easting Latitude Longitude Comments (ft) (°I (% (ft) (ft) (ftl (ft) (ft) (ft) (ft) (9100ft) (ftUS) (ftUS) r) r 9532.73 88.13 190.66 6024.27 6156.79 5563.70 6260.92 6110.26 -5563.70 -2525.96 1.38 5938649.22 527468.04 70.24347533 -149.77815037 9626.93 88.47 190.90 6027.06 6159.58 5656.20 6355.08 6201.80 -5656.20 -2543.57 0.44 5938556.66 527450.80 70.24322262 -149.77829234 9721.72 89.05 1.90.97 6029.11 6161.63 5749.25 6449.84 6294.07 -5749.25 -2561.55 0.62 5938463.56 527433.20 70.24296841 -149.77843727 9816.03 89.22 191.51 6030.54 6163.06 5841.74 6544.14 6386.07 -5841.74 -2579.93 0.60 5938371.00 527415.19 70.24271571 -149.77858544 9911.18 89.34 192.91 6031.73 6164.25 5934.73 6639.29 6479.29 -5934.73 -2600.05 1.48 5938277.95 527395.44 70.24246166 -149.77874768 10005.70 87.64 195.24 6034.31 6166.83 6026.36 6733.77 6572.47 -6026.36 -2623.03 3.11 5938186.23 527372.83 70.24221128 -149.77893295 10100.95 86.37 195.29 6039.37 6171.89 6118.12 6828.88 6666.61 -6118.12 -2648.07 ` 1.23 5938094.38 527348.16 70.24196058 -149.77913491 10195.60 85.91 196.09 6045.74 6178.26 6209.04 6923.32 6760.20 -6209.04 -2673.61 0.97 5938003.37 527322.98 70.24171218 -149.77934087 10290.96 87.44 194.88 6051.27 6183.79 6300.78 7018.51 6854.52 -6300.78 -2699.02 2.04 5937911.54 527297.93 70.24146153 -149.77954584 10385.80 87.92 194.39 6055.11 6187.63 6392.46 7113.27 6948.25 -6392.46 -2722.96 0.72 5937819.77 527274.36 70.24121102 -149.77973891 10480.23 87.68 194.02 6058.73. 6191.25 6483.94 7207.63 7041.49 -6483.94 -2746.12 0.47 5937728.21 527251.57 70.24096109 -149.77992561 10575.91 87.58 194.24 6062.69 6195.21 6576.64 7303.23 7135.98 -6576.64 -2769.46 0.25 5937635.42 527228.60 70.24070780 -149.78011379 10670.75 87.75 194.25 6066.55 6199.07 6668.49 7397.99 7229.69 -6668.49 -2792.77 0.18 5937543.49 527205.65 70.24045686 -149.78030179 10764.80 87.44 193.64 6070.50 6203.02 6759.69 7491.96 7322.57 -6759.69 -2815.42 0.73 5937452.21 527183.38 70.24020769 -149.78048437 10859.30 91.38 .191.23 6071.47 6203.99 6851.94 7586.44 7415.57 -6851.94 -2835.76 4.89 5937359.89 527163.40 70.23995564 -149.78064834 10954.26 91.56 190.03 6069.04 6201.56 6945.24 7681.37 7508.50 -6945.24 -2853.27 1.28 5937266.53 527146.27 70.23970074 -149.78078944 11047.66 91.66 189.16 6066.41 6198.93 7037.30 7774.73 7599.59 -7037.30 -2868.83 0.94 5937174.42 527131.07 70.23944923 -149.78091481 11142.29 91.69 187.47 6063.65 6196.17 7130.89 7869.32 7691.45 -7130.89 -2882.51 1.79 5937080.79 527117.77 70.23919353 -149.78102497 11237.64 91.14 185.69 6061.29 6193.81 7225.58 7964.64 7783.38 -7225.58 -2893.43 1.95 5936986.07 527107.22 70.23893483 -149.78111286 11332.37 90.68 184.01 6059.79 6192.31 7319.95 8059.36 7874.01 -7319.95 -2901.44 1.84 5936891.67 527099.59 70.23867699 -149.78117722 11426.56 87.86 184.10 6060.99 6193.51 7413.89 8153.53 7963.84 -7413.89 -2908.10 -3.00 5936797.72 527093.31 70.23842036 -149.78123070 • 11520.66 88.64 185.38 6063.86 6196.38 7507.62 8247.59 8053.99 -7507.62 -2915.87 1..59 5936703.96 527085.91 70.23816428 -149.78129315 .11615.66 85.51 ..184.41 6068.71 6201.23 7602.14 8342.45 8145.07 -7602.14 -2923.97. 3.45 5936609.42 527078.19 70.23790605 -149.78135822 11709.38 87.83 - 182.30 6074.15 6206.67 7695.53 8436.01 8234.25 - -7695.53 -2929.44 3.34 5936516.02 527073.09 70.23765091 -149.78140211 11802.58 88.16 180.73 6077.41 6209.93 7788.64 8529.15 8322.19 -7788.64 -2931.90 1.72 5936422.92 527071.00 70.23739655 -149.78142170 11898.53 88.54 180.40 6080.18 6212.70 7884.54 8625.06 8412.35 -7884.54 -2932.85 0.52 5936327.02 527070.43 70.23713454 -149.78142903 11993.76 89.88 179.60 6081.49 6214.01 7979.76 8720.28 8501.66 -7979.76 -2932.85 1.64 5936231.81 527070.81 70.23687441 -149.78142873 12088.80 90.46 179.42 6081.21 6213.73 8074.79 8815.32 8590.64 -8074.79 -2932.04 0.64 5936136.79 52707200 70.23661478 -149.78142187 12181.82 89.94 179.63 6080.88 6213.40 8167.81 8908.34 8677.87 -8167.81 -2931.27 0.60 5936043.78 527073.14 70.23636066 -149.78141535 12274.46 90.18 179.01 6080.79 6213.31 8260.44 9000.98 8764.75 -8260.44 -2930.17 0.72 5935951.17 527074.61 70.23610760 -149.78140619 12369.15 88.91 180.40 6081.54 6214.06 8355.13 9095.66 8853.88 -8355.13 -2929.68 1.99 5935856.50 527075.48 70.23584893 -149.78140195 12462.92 87.37 181.39 6084.58 6217.10 8448.83 9189.38 8942.84 -8448.83 -2931.14 1.95 5935762.80 527074.39 70.23559293 -149.78141347 12552.25 86.71 182.43 6089.20 6221.72 8537.99 9278.59 9028.08 -8537.99 -2934.12 1.38 5935673.63 527071.77 70.23534935 -149.78143719 12646.99 87.37 182.82 6094.09 6226.61 8632.50 9373.20 9118.91 -8632.50 -2938.45 0.81 5935579.11 527067.81 70.23509114 -149.78147188 12744.06 87.57 181..83. 6098.37.. 6230.89 8729.40 9470.18 9211.95 -8729.40 -2942.38 1.04 5935482.21 527064.26 70.23482643 -149.78150333 12839.47 89.15 179.69 6101.10 6233.62 8824.75 9565.54 9302.76 -8824.75 -2943.65 2.79 5935386.87 527063.38 70.23456592 -149.78151323 12932.08 90.42 179.79 6101.45 6233.97 8917.36 9658.15 9390.52 -8917.36 -2943.23 1.38 5935294.27 527064.17 70.23431293 -149.78150955 13021.75 87.94 181.38 6102.73 6235.25 9007.00 9747.81 9475.98 -9007.00 -2944.14 3.29 5935204.63 527063.61 70.23406802 -149.78151665 13116.73 86.92 181.73 6106.99 6239.51 9101.85 9842.69 9566.97 -9101.85 -2946.72 1.14 5935109.78 527061.41 70.23380890 -149.78153714 13216.46 90.57 183.21 6109.18 6241.70 9201.45 9942.38 9663.08 -9201.45 -2951.01 3.95 5935010.18 527057.51 70.23353681 -149.78157151 13315.58 89.20 179.80 6109.38 6241.90 9300.52 10041.50 9758.25 -9300.52 -2953.62 3.71 5934911.11 527055.30 70.23326615 -149.78159220 13409.32. 90.47 177.19. 6109.65 6242.17 9394.21 10135.23 9846.85 -9394.21 -2951.15 3.10 5934817.44 527058.14 70.23301018 -149.78157204 13503.37 90.08 .178.99 6109.19 6241.71 9488.20 10229.28 9935.64 -9488.20 -2948.02 1.96 5934723.47 527061.65 70.23275340 -149.78154644. 13597.37 90.08 180.64 6109.06 6241.58 9582.20 10323.28 10025.35 -9582.20 -2947.72 1.76 5934629.48 527062.32 70.23249661 -149.78154369 13692.84 90.68 181.61 6108.43 6240.95 9677.65 10418.75 10117.16 -9677.65 -2949.59 1.19 5934534.04 527060.83 70.23223585 -149.78155852 13787.81 89.43 183.07 6108.34 6240.86 9772.54 10513.72 10209.09 -9772.54 -2953.47 2.02 5934439.15 527057.33 70.23197662 -149.78158951 13880.05 89.36 184.29 609.31 6241.83 9864.58 10605.95. 10298.93 -9864.58 -2959.39 1.32 5934347.09 527051.78 70.23172516 -149.78163700 13975.53 89.50 183.66 6110.26 6242.78 9959.82 10701.43 10392.08 -9959.82 -2966.01 0.68 5934251.83 527045.54 70.23146495 -149.78169012 14069.63 89.26 183.09 6111.28 6243.80 10053.75 10795.52 10483.70 -10053.75 -2971.55 0.66 5934157.89 527040.37 70.23120833 -149.78173453 14160.86 88.74 180.54 6112.87 6245.39 10144.92 10886.74 10571.97 -10144.92 -2974.44 2.85 5934066.72 527037.85 70.23095927 -149.78175755 14258.86 89.09 180.19 6114.73 6247.25 10242.90 10984.72 10666.20 -10242.90 -2975.06 0.51 5933968.75 527037.61 70.23069160 -149.78176228 14354.10 88.98 181.56 6116.33 6248.85 10338.11 11079.95 10758.07 -10338.11 -2976.51 1.44 5933873.54 527036.54 70.23043148 -149.78177371 14447.77 88.98 181.24 6118.00 6250.52 10431.74 11173.60 10848.70. -10431.74 -2978.80 0.34 5933779.92 527034.62 70.23017569 -149.78179188 14540.01 89.19 182.55 6119.47 6251.99 10523.91 11265.83 10938.20 -10523.91 -2981.85 1.44 5933687.74 527031.94 70.22992387 -149.78181620 14630.45 88.30 184.47. 6121.45 6253.97 10614.16 11356.25 11026.55 -10614.16 -2987.39 2.34 5933597.48 527026.76 70.22967732 -149.78186058 14704.68 88.26 184.86 6123.68 6256.20 10688.11 11430.44 11099.38 -10688.11 -2993.42 0.53 5933523.52 527021.02 70.22947529 -149.78190904 14731.31 88.43 185.50 6124.45 6256.97 10714.62 11457.06 11125.56 -10714.62 -2995.82 2.49 5933497.00 527018.73 70.22940286 -149.78192835 4-12"Liner f4816.00 88.42 185.26 6126.78 6259.30 10798.90 11541.72 11208.87 -10798.90 -3003.76 0.28 5933412.69 527011.13 70.22917259 -149.78199214 Proi to TD 14823.00 88.42 185.24 6126.97 6259.49 10805.87 11548.72 11215.76 -10805.87 -3004.40 0.28 5933405.72 527010.51. 70.22915355 -149.78199729 Survey Type: Survey Error Model: Survey Program: Drilling Office 2.7.1043.0 Def Survey ISCWSA Rev 0'"' 3-D 95.000% Confidence 2.7955 sigma Kuparuk River Unit2\Kuparuk 2E Pad\2E-04\2E-04\2E-04 Final 3/10/2014 1:33 PM Page 3 of 4 MD Incl Azim True TVDSS TVD VSEC AHD Closure NS EW DLS Northing Easting Latitude Longitude Comments (ft) ("1 M (ft) (ft) (ftl (ftl (ft) (ft) (ftl (°/100ft) MUS) MUS) M C MD From Description Part MD To EOU Freq Hole Size Casing Diameter Survey Tool Type Y YP Borehole I Survey Y (ft) (ft) (ft) (in) (in) 1 33.520 742.000 Act Stns 13.500 10.750 GYD-GC-SS 2E-04PB1/2E-04PB1 Final 1 742.000 3816.300 Act Stns 13.500 10.750 MWD+IFR-AK-CAZ-SC 2E-04PB1 /2E-04PS1 Final 1 3816.300 5483.340 Act Stns 9.875 7.000 MWD+IFR-AK-CAZ-SC 2E-04PB1/2E-04PB1 Final 1 5483.340 14731.310 Act Stns 6.500 4.500 MWD+IFR-AK-CAZ-SC 2E -04/2E-04 Final 1 14731.310 14823.000 Act Stns 6.500 4.500 BLIND 2E -0412E-04 Final Legal Description: Northing (Y) Easting (X) Surface: 579.4 FSL 5120.2 FEL S36 T11 N R9E UM 5944222.370 529971.590 BHL: 333 FSL 2852 FEL 11 TION R9EUM 5933405.720 527010.510 • Drilling Office 2.7.1043.0 Kuparuk River Unit2\Kuparuk 2E Pad\2E-04\2E-04\2E-04 Final 3/10/2014 1:33 PM Page 4 of 4 Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. 0 Yes ❑ No 1 have checked to the best of my ability that the following data is correct: Surface Coordinates Q Declination & Convergence O GRS Survey Corrections p Survey Tool Codes SLB DE: Client Representative: Date: • Drilling Office 2.7.1043.0 Kuparuk River Unit2\Kuparuk 2E Pad\2E-04\2E-04\2E-04 Final 3/10/2014 1:33 PM Page 4 of 4 Scmumbepgep 2E-04PB1 Final Survey Report (Def Survey) Client: ConocoPhillips (Alaska) Inc. -Kup2 Vertical Section Azimuth: 205.000 ° (True North) Field: Kuparuk River Unit2 Vertical Section Origin: 0.000 ft, 0.000 it Structure / Slot: Kuparuk 2E Pad / 2E-04 TVD Reference Datum: Rotary Table Well: 2E-04 TVD Reference Elevation: 132.520 ft above Mean Sea Level Borehole: 2E-04PB1 Seabed / Ground Elevation: 105.100 ft above Mean Sea Level UWI / API#: 10350556 / 50-029-23505-00-00 Magnetic Declination: 19.524 " Survey Name: 2E-04PB1 Final Total Gravity Field Strength: 1001.9572mgn (9.80665 Based) Survey Date: January 24, 2014 Gravity Model: GARM Tort / AHD / DDI / ERD Ratio: 132.592 ° / 3473.540 ft / 5.742 / 0.527 Total Magnetic Field Strength: 57605.129 nT Coordinate Reference System: NAD27 Alaska State Plane, Zone 04, US Feet Magnetic Dip Angle: 80.861, Location Lat I Long: N 700 15' 31.23428", W 149° 45' 27.90435" Declination Date: January 10, 2014 Location Grid WE Y/X: N 5944222.370 ftUS, E 529971.590 ftUS Magnetic Declination Model: BGGM 2013 CRS Grid Convergence Angle: 0.2280 ° North Reference: True North Grid Scale Factor: 0.99990102 Grid Convergence Used: 0.0000 ° Version / Patch: 2.7.1043.0 Total Corr Mag North ->True 19.5239 , 5944222.37 529971.59 North: -149.75775121 ConocoPhillips • Drilling Office 2.7.1043.0 Kuparuk River Unit2ftparuk 2E Pad\2E-04\2E-04PB1\2E-04PB1 Final 3/10/2014 1:34 PM Page 1 of 3 MD Incl Azim True TVDSS TVD VSEC AHD Closure NS EW DLS Northing Easting Latitude Longitude Comments (ft) M M (ft) (ft) (ft) Ift) (ft) Ift) (ft) V/100ft) (ftUS) (ftUS) 1°1 1°I Tie -In 0.00 0.00 0.00 -132.52 0.00 0.00 0.00 0.00 0.00 0.00 N/A 5944222.37 529971.59 70.25867619 -149.75775121 Ground Level 27.42 0.00 0.00 -105.10 27.42 0.00 0.00 0.00 0.00 0.00 0.00 5944222.37 529971.59 70.25867619 -149.75775121 108.00 0.06 36.51 -24.52 108.00 -0.04 0.04 0.04 0.03 0.03 0.07 5944222.40 529971.61 70.25667628 -149.75775101 185.00 0.23 84.01 52.48 185.00 -0.16 0.23 0.22 0.08 0.20 0.25 5944222.45 529971.79 70.25867641 -149.75774957 277.00 0.24 99.28 144.48 277.00 -0.31 0.60 0.58 0.07 0.58 0.07 5944222.44 529972.17 70.25867638 -149.75774655 368.00 0.81 250.29 235.48 368.00 0.09 1.18 0.24 -0.18 0.16 1.13 5944222.19 529971.75 70.25867570 -149.75774992 462.00 1.81 254.70 329.45 461.97 1.52 3.33 2.06 -0.79 -1.90 1.07 5944221.57 529969.70 70.25867402 -149.75776655 555.00 2.60 261.79 422.38 554.90 3.63 6.90 5.60 -1.48 -5.40 0.90 5944220.67 529966.19 70.25867214 -149.75779487 649.00 3.29 262.69 516.26 648.78 6.23 11.73 10.41 -2.12 -10.19 0.74 5944220.21 529961.41 70.25867040 -149.75783356 742.00 4.29 267.82 609.05 741.57 9.24 17.87 16.52 -2.58 -16.31 1.13 5944219.72 529955.29 70.25866913 -149.75788305 768.37 4.26 268.70 635.35 767.87 10.12 19.84 18.47 -2.64 -18.28 0.27 5944219.66 529953.32 70.25866897 -149.75789893 861.02 5.00 270.12 727.70 860.22 13.34 27.32 25.90 -2.71 -25.76 0.81 5944219.56 529945.85 70.25866878 -149.75795937 952.98 6.03 267.11 819.23 951.75 17.29 36.15 34.71 -2.95 -34.59 1.16 5944219.29 529937.02 70.25866814 -149.75803074 1045.63 8.48 262.05 911.13 1043.65 23.28 47.85 46.40 -4.14 -46.22 2.73 5944218.05 529925.40 70.25866488 -149.75812471 1138.37 9.82 261.31 1002.69 1135.21 31.39 62.59 51.13 -6.26 -60.81 1.45 5944215.85 529910.82 70.25865904 -149.75824263 1231.19 12.83 259.70 1093.69 1226.21 41.74 80.82 79.32 -9.32 -78.77 3.26 5944212.74 529892.86 70.25865073 -149.75838785 1323.55 14.43 256.91 1183.45 1315.97 54.44 102.58 101.05 -13.36 -100.16 1.74 5944208.61 529871.50 70.25863967 -149.75856067 1416.11 15.28 255.48 1272.92 1405.44 69.00 126.30 124.69 -18.64 -123.28 1.32 5944203.24 529648.39 70.25862526 -149.758747jft 1508.96 15.96 254.26 1362.34 1494.86 85.11 151.30 149.55 -25.17 -147.41 0.81 5944196.61 529824.29 70.25860742 -149.75894 1601.36 15.69 250.03 1451.24 1583.76 102.23 176.49 174.51 -32.89 -171.39 1.28 5944188.81 529800.35 70.25858634 -149.759136 1693.55 16.64 243.99 1539.79 1672.31 f21.31 202.13 199.64 -42.93 -194.97 2.09 5944178.67 529776.82 70.25855889 -149.75932688 1787.15 18.73 233.93 1628.98 1761.50 144.68 230.50 226.62 -57.66 -219.17 3.95 5944163.84 529752.68 70.25851865 -149.75952245 1877.58 20.18 229.76 1714.25 1846.77 171.76 260.61 254.51 -76.29 -242.81 2.22 5944145.12 529729.11 70.25846776 -149.75971353 1972.34 26.22 223.02 1801.32 1933.84 206.54 297.88 268.31 -102.18 -269.60 6.95 5944119.13 529702.43 70.25839703 -149.75993002 2064.63 29.71 221.85 1882.82 2015.34 247.83 341.15 327.50 -134.13 -298.78 3.83 5944087.06 529673.38 70.25830973 -149.76016581 2157.53 30.38 219.72 1963.24 2095.76 292.59 387.66 370.16 -169.35 -329.15 1.36 5944051.73 529643.15 70.25821351 -149.76041125 2247.55 35.09 216.01 2038.95 2171.47 340.03 436.32 414.75 -207.61 -358.93 5.68 5944013.15 529613.53 70.25810843 -149.76065189 2342.42 37.42 214.14 2115.45 2247.97 395.27 492.41 466.23 -253.74 -391.14 2.72 5943967.10 529581.50 70.25798297 -149.76091221 2435.19 40.13 212.75 2187.77 2320.29 452.73 550.50 519.96 -302.22 -423.14 3.07 5943918.50 529549.70 70.25785051 -149.76117078 2527.56 40.78 210.33 2258.06 2390.58 512.27 610.43 575.65 -353.30 -454.48 1.84 5943867.30 529518.57 70.25771097 -149.76142402 2619.23 41.71 207.23 2326.99 2459.51 572.56 670.86 631.56 -406.26 -483.55 2.45 5943814.23 529489.71 70.25756627 -149.76165897 2712.35 41.84 206.99 2396.44 2528.96 634,55 732.90 689.15 -461.48 -511.82 0.22 5943758.90 529461.66 70.25741540 -149.76188740 2804.38 47.20 205.24 2462.03 2594.55 699.04 797.40 749.39 -519.42 -540.17 5.97 5943700.86 529433.54 70.25725712 -149.76211646 2898.39 48.02 205.84 2525.41 2657.93 768.47 866.83 814.75 -582.06 -570.11 0.99 5943636.10 529403.86 70.25706597 -149.76235835 2991.00 46.70 205.51 2568.15 2720.67 836.59 934.96 879.54 -643.46 -599.63 1.45 5943576.59 529374.59 70.25691823 -149.76259685 3082.87 47.22 205.95 2650.85 2783.37 903.73 1002.10 943.88 -703.95 -628.78 0.67 5943516.00 529345.68 70.25675298 -149.76283238 Drilling Office 2.7.1043.0 Kuparuk River Unit2ftparuk 2E Pad\2E-04\2E-04PB1\2E-04PB1 Final 3/10/2014 1:34 PM Page 1 of 3 Survey Type: Survey Error Model: Survey Program: Drilling Office 2.7.1043.0 Def Survey ISCWSA Rev 0 *** 3-D 95.000% Confidence 2.7955 sigma Kuparuk River Unit2\Kuparuk 2E Pad\2E-04\2E-04PB1\2E-04PB1 Final 3/10/2014 1:34 PM Page 2 of 3 MD Incl Azim True TVDSS TVD VSEC AHD Closure NS EW DLS Northing Easting Latitude Longitude Comments (ft) (I (I (ft) (ft) (ft) (ft) (ft) (ft) (ft) M100ft) MUS) (ftUS) (% (1 3176.58 - 47.55 206.32 2714.30 2846.82 972.68 1071.06 1010.46 -765.86 -659.16 0.46 5943453.97 529315.55 70.25658383 -149.76307782 3269.24 47.60 204.57 2776.81 2909.33 1041.07 1139.46 1076.59 -827.62 -688.54 1.40 5943392.10 529286.42 70.25641510 -149.76331522 3362.37 47.50 203.83 2839.67 2972.19 1109.78 1208..18 1142.93 -890.30 -716.71 0.60 5943329.32 529258.50 70.25624386 -149.76354280 3454.33 47.52 205.02 2901.78 3034.30 1177.58 1275.99 1208.73 -952.04 -744.75 0.95 5943267.47 529230.71 70.25607519 -149.76376933 3547.63 47.66 205.02 2964.71 3097.23 1246.47 1344.87 1275.94 -1014.46 -773.88 0.15 5943204.94 529201.83 70.25590464 -149.76400471 3638.87 48.02 204.92 3025.95 3158.47 1314.10 1412.51 1342.08 . -1075.77 -802.43 0.40 5943143.52 529173.52 70.25573714 -149.76423537 3732.23 47.86 205.68 3088.49 3221.01 1383.41 .1481.82 1410.09 -1138.44 -832.05 0.63 5943080.75 529144.16 70.25556593 -149.76447467 3755.85 48.04 205.59 3104.31 3236.83 1400.95 1499.36 1427.34 -1154.25 -839.64 0.81 5943064.91 529136.63 70.25552273 -149.76453597 10-314" Surface 3816.30 48.64 205.26 3144.49 - 3277.01 1446.11 1544.52 1471.75 -1195.04 -859.03 1.07 5943024.05 529117.41 70.25541129 -149.76469259 Casing - 3853.96 49.01 205.05 3169.29. 3301.81 1474.46 1572.87 1499.62 -1220.70 -871.08 1.07 5942998.34 529105.48 70.25534119 -149.76478992 3908.96 46.61 205.60 3205.51 3338.03 1515.85 1614.26 1540.38 -1258.11 -888.78 1.05 5942960.86 529087.91 70.25523898 -149.76493294 4000.85 46.40 206.92... 3266.39 3398.91 1584.65 1683.08 1608.39 -1319.83 -919.23 1.10 5942899.03 529057.71 70.25507035 -149.76517892 4094.79 47.86 207.34 3329.09 3461.61 1654.56 1753.03 1677.74 -1382.08 -951.13 0.66 5942836.65 529026.06 70.25490026 -149.76543561 4187.26 47.78 206.46 3391.18 3523.70 1723.04 1821.56 1745.68 -1443.19 -982.13 0.71 5942775.43 528995.31 70.25473330 -149.76568705 4280.26 47.87 208.59 3453.62 3586.14 1791.94 1890.48 .1814.00 -1504.86 -1012.91 0.14 5942713.64 528964.78 70.25456482 -149.76593569 4373.12 47.73 207.26 3516.00 3648.52 1860.69 1959.27 1882.29 -1566.19 -1044.06 0.56 5942652.19 528933.87 70.25439725 -149.76618732 4465.14 47.60 208.15 3577.97 3710.49 1928.64 2027.29 1949.96 -1626.42 -1075.69 0.73 5942591.85 528902.49 70.25423271 -149.76644277 4556.94 47.83 209.29 3639.74 3772.26 1996.41 2095.21 2017.64 -1685.97 -1108.32 0.95 5942532.17 528870.10 70.25406999 -149.76(5706Aft 4649.38 47.64 209.73 3701.91 3834.43 2064.61 2163.62 2085.91 -1745.51 -1142.02 0.41 5942472.51 528836.64 70.25390733 -149.76697 4742.11 47.77 209.72 3764.31 3896.83 2132.96 2232.21 2154.38 -1605.07 -1176.03 0.14 5942412.81 528802.87 70.25374459 -149.767253 4834.39 47.75 210.04 3826.35 3958.87 .2201.03 2300.53 2222.59 -1864.31 -1210.06 0.26 5942353.45 528769.08 70.25358274 -149.76752823 4926.71 47.69 209.68 3888.46 4020.98 2269.09 2368.83 2290.80 -1923.55 -1244.07 0.30 5942294.08 528735.31 70.25342090 -149.76780292 5020.11 47.58 208.49 3951.39 4083.91 2337.92 2437.84 2359.66 -1983.85 -1277.61 0.95 5942233.65 528702.01 70.25325613 -149.76807388 5113.35 47.76 206.94 4014.18 4146.70 2406.77 2506.77 2428.32 -2044.87 -1309.67 1.24 5942172.51 528670.20 70.25308941 -149.76833278 5206.14 48.09 206.06 4076.36 4208.88 2475.62 2575.64 2496.81 -2106.51 -1340.40 0.79 5942110.78 528639.72 70.25292101 -149.76858098 5298.54 48.19 205.73 4138.02 4270.54 2544.43 2644.46 2565.19 -2168.42 -1370.45 0.29 5942048.73 528609.91 70.25275187 -149.76882371 5390.24 48.33 206.59 4199.07 4331.59 2612.84 2712.88 2633.23 -2229.83 -1400.62 0.72 5941987.21 528580.00 70.25258407 -149.76906735 5483.34 48.28 205.93 4261.00 4393.52 2682.34 2782.40 2702.39 -2292.17 -1431.38 0.53 5941924.75 528549.49 70.25241374 -149.76931575 5576.88 48.34 205.98 4323.21 4455.73 2752.18 2852.25 2771.86 -2354.98 -1461.95 0.08 5941861.83 528519.17 70.25224214 -149.76956265 5669.20 48.28 206.31 4384.62 4517.14 2821.11 2921.19 2840.47 -2416.87 -1492.33 0.27 5941799.83 528489.04 70.25207306 -149.78980799 5760.91 46.43 206.51 4446.74 4579.26 2888.55 2988.65 2907.65 -2477.28 -1522.33 2.02 5941739.30 528459.28 70.25190799 -149.77005028 5854.46 42.72 207.82 4513.37 4645.89 2954.14 3054.29 2973.10 -2535.70 -1552.28 4.09 5941680.77 528429.57 70.25174839 -149.77029213 5946.35 38.95 .209.33 4582.88 4715.40 3014.10 3114.36 3033.09 -2588.46 -1580.98 4.24 5941627.90 528401.08 70.25160421 -149.77052396 6039.80 34.66 208.81 4657.69 4790.21 3069.93 3170.34 3089.02 -2637.38 -1608.19 4.60 5941578.88 528374.07 70.25147056 -149.77074368 6132.30 30.57 206.32 4735.59 4868.11 3119.71 3220.18 3138.75 -2681.53 -1631.31 4.65 5941534.64 528351.13 70.25134993 -149.77093035 6225.73 26.18 201.28 4817.79 4950.31 3164.06 3264.54 3182.75 -2722.06 -1649.33 5.35 5941494.05 528333.27 70.25123920 -149.77107591.. 6317.71 22.82 194.91 4901.49 5034.01 3201.88 3302.65 3219.88 -2758.22 -1661.29 4.64 5941457.84 528321.46 70.25114041 -149.77117246 6410.27 18.94 191.35 - 4987.96 5120.48 3234.17 3335.62 3251.29 -2790.30 -1668.87 4.41 5941425.73 528314.01 70.25105275 -149.77123362 6502.53 15.54 191.00 5076.06 5208.58 3260.72 3362.96 3277.05. -2817.12. -1674.17 3.69 5941398.89 528308.81 70.25097948 -149.77127644 6596.18 - 13.99 187.39 5166.62 5299.14 3283.68 3386.82 3299.26 -2840.67 -1678.02 1.92 5941375.34 528305.05 70.25091516 -149.77130750 6688.21 13.54 177.73 5256.02 5388.54 3303.86 3408.67 3318.56 -2862.46 -1679.03 2.54 5941353.54 528304.13 70.25085560 -149.77131557 6780.17 11.15 170.08 5345.85 5478.37 3320.72 3428.30 3334.43 -2881.98 -1677.07 3.14 5941334.03 528306.17 70.25080228 -149.77129972 .6873.32 8.96 166.92 5437.56 5570.08 3333.82 3444.58 3346.61 -2897.92 -1673.88 2.42 5941318.10 528309.43 70.25075873 -149.77127389 6965.24 7.33 163.62 5528.55 5661.07 3343.88 3457.58 3355.90 -2910.52 -1670.60 1.84 5941305.52 528312.75 70.25072432 -149.77124742 7058.39 4.47 166.21 5621.20 5753.72 3351.15 3467.15 3362.64. -2919.75 -1668.06 3.08 5941296.30 528315.33 70.25069911 -149.77122687 7151.77 0.55 141.64 5714.47 5846.99 3354.18. 3471.21 3365.45 -2923.64 -1688.91 4.26 5941292.42 528316.49 70.25068849 -149.77121760 7245.46 0.34 - 308.36 5808.16 5940.68 3354.32 3471.61 3365.58 -2923.82 -1666.85 0.94 5941292.24 .528316.55 70.25068800 -149.77121 7336.97 0.25 182.01 5899.67 6032.19 3354.44 3471.93 3365.71 -2923.85 -1667.07 0.58 5941292.21 528316.33 70.25068791 -149.77121 7363.95 '0.21 188.18 5926.65 6059.17 .3364.54 3472.03 3365.81 -2923.96 -1667.08 0.17 5941292.10 528316.33 70.25068762 -149.771218 7400.64 -0.05 204.05 5963.34 6095.86 3354.62 3472.12 3365.89 -2924.04 -1667.10 0.44.. 5941292.02 : 528316.31 70.25068740..-149.77121908 7493.88 0.34 127.03 6056.58 6189.10 3354.72 3472.41 3365.96 -2924.24 -1666.89 0.36. 5941291.81 528316.51 70.25068684 -149.77121743 7586.14 0.19 40.85 6148.84 6281.36 3354.63 3472.77 3365.85 -2924.29 -1666.57 0.41 5941291.77 526316.83 70.25068671 -149.77121485 7677.86 0.18 85.90 6240.56 6373.08 3354.42 3473.05 3365.62 -2924.16 -1666.33 0.15 5941291.89 528317.08 70.25068705 -149.77121289 7770.78 0.23 335.35 6333.48 6466.00 3354.22 3473.29 3365.43 -2923.98 -1666.26 .0.36 5941292.07 528317.14 70.25068754 -149.77121234 7839.14 0.12 142.12 6401.84 6534.36 3354.17 3473.41 3365.38 -2923.92 -1666.28 0.51 5941292.14 528317.13 70.25068773 -149.77121245 Project to Bit 7900.00 0.12 142.12 6462.70 6595.22 3354.23 3473.54 3365.43 -2924.02 -1666.20 0.00 5941292.04 528317.21 70.25068745 -149.77121182 Survey Type: Survey Error Model: Survey Program: Drilling Office 2.7.1043.0 Def Survey ISCWSA Rev 0 *** 3-D 95.000% Confidence 2.7955 sigma Kuparuk River Unit2\Kuparuk 2E Pad\2E-04\2E-04PB1\2E-04PB1 Final 3/10/2014 1:34 PM Page 2 of 3 Comments MD Incl Azim True TVDSS TVD VSEC AHD Closure NS EW DLS Northing Easting Latitude Longitude (ft) (°) M (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°I10oft) (HUS) MUS) M 1") Description Part MD From MD To EOU Freq Hole Size Casing Diameter Survey Tool Type Y YP Borehole I Survey Y I have checked to the best of my ability that the following data is correct: (ft) (ft) (ft) (in) (in) ❑+ GRS Survey Corrections 1 33.520 742.000 Act Stns 13.500 10.750 GYD-GC-SS 2E-04PB1 / 2E-04PB1 Final 1 742.000 3816.300 Act Stns 13.500 10.750 MWD+IFR-AK-CAZ-SC 2E-04PB1 / 2E-04PB1 Final 1 3816.300 7839.140 Act Stns 9.875 7.000 MWD+IFR-AK-CAZ-SC 2E-04PB1 / 2E-04PB1 Final 1 7839.140 7900.000 Act Stns 9.875 7.000 BLIND 2E-04PB1 / 2E-04PB1 Final Legal Description: Surface: 579.4 FSL 5120.2 FEL S36 T11 N R9E UM BHL: 2935 FSL 1508 FEL 2 TION R9EUM Northing (Y) Easting (X) 5944222.370 529971.590 5941292.040 528317.210 • Drilling Office 2.7.1043.0 Kuparuk River Unit2ftparuk 2E Pad\2E-04\2E-04P61\2E-04P131 Final 3/10/2014 1:34 PM Page 3 of 3 Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. I] Yes ❑ No I have checked to the best of my ability that the following data is correct: 10 Surface Coordinates Declination & Convergence ❑+ GRS Survey Corrections Survey Tool Codes SLB DE: Client Representative: Date: • Drilling Office 2.7.1043.0 Kuparuk River Unit2ftparuk 2E Pad\2E-04\2E-04P61\2E-04P131 Final 3/10/2014 1:34 PM Page 3 of 3 Lit-nreFs vetn�,e-.; rn uavaoei� 0 • ill 011491" 0 **@1 w• • ZIA 01/20/14 Ku aruk River Units rt�i 1tii# 7425' SID hrYI Pi °_ 50-029-23505-00-00[t� 6,107 Kuparuk A Sands HT30 a,i,Nrt wL Mike Buckley Eri hl and 7515 _1 00 6,1971 4" Zach Beekman 90' = 89 � ,_. €►— d' °aUZ 99% I Lithology Color Cement Matrix Structures Grain Size Sorting Porosity Odor Staining Fluorescent Cut Fluor? Comments Depth 7,425' Siltstone 80% and sandstone Gray None Matrix supported Interbedded SS upper fine - moderate poor moderate moderate, dull orange yellow transluscent bright visible free oil on bedding / lam observed & SLTSN lower medium visible oil white surfaces 20% Interbedded None Thinly upper very fine moderate, transluscent bright visible free oil on 7,428' siltstone and fine Gray observed Matrix supported interbedded upper fine moderate poor moderate visible oil dull orange yellow white bedding /lam sandstone surfaces 7,431' Siltstone 50% and Sandstone Brownish None Matrix supported Thinly upper very fine moderate poor- poor- moderate, dull orange yellow transparent dull white scattsub-vertical Gray observed interbedded lower medium moderate moderate visible oil fractures in sltsn 50% 7,434' Sandy Siltstone Brownish None Matrix supported Ripple upper very fine moderate moerae moderate moderate, dull orange yellow transluscent bright Gray observed laminated lower medium moderate visible oil white 7,437' Siltstone 80% and sandstone Grayish None Matrix supported Ripple upper very fine moderate poor faint poor no visible sample no cut fluorescence Brown observed laminated upper fine fluorescence 20% 7,440' Sandstone Dark Brownish None Matrix supported Massive upper very fine upperfine well moderate strong moderate no visible sample fluorescence opaquebrightwhite Gray observed 7,443' Silty Sandstone Grayish None Matrix supported Ripple upper very fine well poor- moderate - moderate no visible sample transluscent bright Brown observed laminated upper fine moderate strong fluorescence white 7,446' Silty Sandstone Grayish None Matrix supported Ripple upper very fine we poor strong moderate no visible sample transluscent bright abundant free oil on Brown observed laminated upperfine fluorescence white bedding planes 7,449' Silty Sandstone Grayish None Matrix supported Ripple lower very fine - well poor- moderate - moderate trace dull orange transluscent bright Brown observed laminated lower fine moderate strong fluorescence white 7,452' Silty Sandstone Grayish None Matrix supported Cross stratified lower very fine - well poor moderate poor- trace dull orange transluscent bright Brown observed lowerfine moderate fluorescence white streaming 7,455' Siltstone Medium Gray Noneno NA Thinly laminated NA NA poor moderate poor visible sample transluscent bright visible free oil exuding from observed fluorescence white streaming lamination planes very faint dull very weak pale 7,458' Sandy Siltstone Brownish None NA Ripple lower very fine NA poor poor -faint poor orange / pale yellow to no cut I Gray observed laminated yellow fluourescence 7,461' Siltstone Brownish None NA thinly laminated/ lower very fine NA poor poor -faint poor very faint straw yellow sample milky white bright cut Gray observed cross stratified fluorescence fluorescence Thinly very faint straw milky white bright cut 7,464' Siltstone Brownish None NA laminated/ cross lower very fine NA poor poor -faint poor yellow sample fluorescence, slow Gray observed stratified fluorescence streamers Brownish None Thinly no visible sample light yellow to straw 7,467' Siltstone Gray observed NA laminated/ cross lower very fine NA poor poor -faint poor fluorescence yellow, weak stratified streaming 0 • 0 0 Brownish None Thinly very faint dull milky white bright cut 7,470' Siltstone NA laminated/cross lower veryfine NA poor poor -faint poor fluorescence, slow Gray observed stratified orange streamers milky white bright cut 7,473' Siltstone Brownish None NA Ripple lower very fine NA poor poor -faint poor no visible sample fluorescence, slow Gray observed laminated fluorescence streamers 7,476' Siltstone Brownish None NA Ripple lower very fine NA poor poor -faint poor very faint pale faint translucent Gray observed laminated yellow bright white diffuse Dark translucent 7,479' Sandstone Yellowish None Matrix supported Interbedded SS lower very fine -faint moderate poor poor poor faint straw gold bright white, slow Brown observed & SLTSN lower fine streamers 7,482' Siltstone Brownish None NA Massive NA NA very poor- poor poor no visible sample very faint white, Black observed poor fluorescence translucent 7,485' Silty Sandstone Brownish None Matrix supported Massive, thinly lower veryfine - moderate -well poor moderate faint no visible sample transparent bright Gray observed laminated lower fine fluorescence white visible free oil on 7,488' Silty Sandstone Brownish None Matrix supported Interbedded lower very fine -no moderate - well poor moderate moderate visible sample transparent bright bedding / lam Black observed upper fine fluorescence white surfaces visible free oil on 7,491' Silty Sandstone Brownish None Matrix supported Interbedded with lower very fine - well poor faint - moderate no visible sample transparent dull white bedding / lam Black observed ripple lamination upper fine moderate fluorescence surfaces 7,494' Silty Sandstone Brownish None Matrix supported Massive with thin laminated lower very fine - well poor faint - poor- no visible sample transparent dull white Black observed upper fine moderate moderate fluorescence beds 7,497' Silty Sandstone Brownish None Matrix supported Trace sub - vertical micro lower very fine - well poor faint - poor no visible sample trace faint yellow Black observed fractures lower fine moderate fluorescence visible free oil on 7,500' Silty Sandstone Brownish None Matrix supported Massive lower very fine - moderate moderate moderate moderate no visible sample translucent bright bedding / lam Black observed lower medium fluorescence white surfaces Dark Interbedded with transparent bright visible free oil on 7,503' Silty Sandstone Yellowish None Matrix supported scattered sub- lower very fine - moderate - well poor- moderate moderate no visible sample white w/ milky white bedding / lam Brown observed vertical micro upper fine moderate fluorescence streamers surfaces fractures Interbedded with 7,506' Silty Sandstone Dark Yellowish None Matrix supported scattered sub- lower very fine -poor- moderate - well moderate moderate no visible sample transparent dull white observed vertical micro upper fine moderate fluorescence Brown fractures Dark None lower very fine - poor- no visible sample translucent bright 7,509' Sandstone Yellowish observed Matrix supported Massive upperfine moderate poor moderate poor fluorescence white Brown Dark None lower very fine - moderate - no visible sample translucent bright 7,511' Sandstone Yellowish observed Matrix supported Massive upperfine moderate poor strong moderate fluorescence white Brown .. ._...,_w,. . h. mss. .._..._ �"" p ``;. - s. 1 Chip samples were collected from the bottom of each 3' core section as the core was processed. _ 0 0 0 9 - - _ • C18t 01/25/14PI'N0: 50-029-2 505-00-001 Tarn, Meltwater, HRZ, Kalubik Fuld Ku aruk�''lllo�dh� Cores ahem' tetls 23 A� Mike Buckley Cores successful: 16 Geologists: Zach BeekmanRecdvered-j 16 1: Core Re Q!11 100%Total Depth Recovered Lithology Color Matrix Structures Grain Size Sorting Porosity Odor Staining Fluorescence Cut Fluor Comments 6,559' 1.75" Sandstone gray - light gray scattered siliceous unconsolidated - u of - I m poor -mod good faint poor pale straw very weak solid, competent cement firm friable sorted transparent white core 6,580' 1.68" Sandstone gray - light gray scatteredo siliceous unconsolidated u of - I m Poor -mod good faint poor 90 /° bright weak diffuse transluscent dull soba, competent cement firm friable sorted yellow white core 6,608' 1.72" Sandstone gray - light gray scattered siliceous unconsolidated - u of - I m poor -mod good faint poor 90% bright slow streaming solid, competent cement firm friable sorted yellow milky white core grain siliceous Supported / poor -mod o 85 /o bright slow diffuse solid, competent 6,618' 1.59" Sandstone gray - light gray cement mod u of - I m sorted good faint none yellow transluscent milky core intergranular bright white cement grain Siliceous supported/ poor -mod 25% spotty weak translucent solid, competent 6,643' 1.75" Sandstone gray - light gray cement mod u of - I m sorted good faint none yellow gold bright white core intergranular cement grain siliceous supported/ Poor -mod solid, competent 6,663' 1.71" Sandstone gray - light gray cement mod u of - I m sorted good none none none none core intergranular cement gray - grayish thinly solid, competent 6,801' 0.40" Siltstone/Shale interbedded, no VIS none none none none core brown laminated dark gray - laminated, solid, competent 6,914' 1.80" Siltstone no vis none none none none core grayish brown massive I 6,932' 1.77" Siltstone/Sandsto brown - grayish interbedded, I of well sorted no vis none none none none solid core, fracture ne brown - gray laminated along bedding gray - grayish laminated, solid core, 1 planar 6,945' 1.70" Siltstone of no vis none none none none fracture to bedding brown -light gray massive plane 7,010' 2.07" Shale light gray - gray thinly lam, trace no vis none none none none solid competent core carb laminations 7,040' 0.20" Siltstone/Shaleno grayish brown - poor retained vis none none none none .2" recovery, splintered and gray structure fractured med gray - very thinly solid, competent 7,070' 1.92" Shale grayish brown laminated no vis none none none none core med gray - poor retained fractured and 7,100' 0.50" Siltstone/Shale grayish brown structure no vis none none none none splintered core 0 9 7,185' 2.10" Shale med dk gray - thinly _ no vis none none none none solid competent core grayish brown laminated med dk gray - poor retained fractured and 7,230' 1.50" Siltstone/Shale gray structure _ _ no vis none none none none splintered core Contact Phone Directional Driller 67 i':X70-4 is 0 E STATE OF ALASKA ALASAIL AND GAS CONSERVATION COMMISSIN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well Rug Perforations r Perforate r Other rv— Install Tiltmeters Alter Casing r Pull Tubing Stimulate - Frac r Waiver r Time Extension Change Approved Program r—Operat. Shutdown �' Stimulate - Other Re-enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory Stratigraphic Service` 213-168-0 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23505-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25658, 25665 2E-04 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): none Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 14823 feet Plugs (measured) none true vertical 6259 feet Junk (measured) none Effective Depth measured 14816 feet Packer (measured) 8585 true vertical 6259 feet (true vertical) 6124 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 108 108 SURFACE 3788 10.75 3816 3277 INTERMEDIATE 8806 7.625 8831' 6161 LINER 6231 4.5" 14816' 6259 RECEIVED MAY 202014 Perforation depth: Measured depth: slotted liner 14585-14623 True Vertical Depth: slotted liner 6253-6253 MD, TVD) RBDMS* MAY 2 U 2P'a Tubing (size, grade, and 3.5, L-80, 8632 MD, 6133 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER HRD ZXP LINER TOP PACKER @ 8585 MD and 6124 TVD NIPPLE - CAMCO DS NIPPLE @ 613 MD and 613 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9238'44816' Treatment descriptions including volumes used and final pressure: 781500# of 16/20 proppant 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14. Attachments 15. Well Class after work: Exploratory r— Development + Service I— Stratigraphic Copies of Logs and Surveys run 16. Well Status after work: 0 Oil Gas r WDSPL Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 314-069 Contact Robert Blakney CcD 265-6417 Email Robert. G.Blakney(@-conocophiIlips.com Printed Name Robert B akne Title Completions Engineer l'j Signature Phone: 265-6417 Date ,/// A Vv[-- (r m P 4 Form 10-404 Revised 10/2012 ,ee, 4001W r Submit Original Only UP PROD Conoco hillips Alaska IOC Wellbore API/UWI Field Name Wellboi 500292350500 KUPARUK RIVER UNIT PROD 2E-04 qlllmppF- CommentH2S (ppm) I Date Annotation End Date KB-Grd (ft) Rig Release Data SSSV: Nipple Last WO: 27.42 2/17/2014 HORIZONTAL-2E-04, 519/201410:28:30 AM Van-, 0;M-2-12777- Annotation Depth (ftKB) End Date Annotation Last Motl By End Date Last Tag: Rev Reason: FRAC hipshkf 5/9/2014 .............................................................................. ....._......._.........-... HANGER; 22.9 ,,,,,, ,,,,,, ,,,,,,,,_„ Casing Description Do (in) 10(in) Top(ftKB) Set Dept KB) Set Depth (TVD). WtlLen (I... Grade Top Thread CONDUCTOR 16 15.250 27.0 107.5 107.5 62.50 H-40 Welded .. „ Casing Description OD (in) ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread SURFACE 103/4 9.950 28.0 3,816.3 3,277.0 45.50 L80 HYD 563 CONDUCTOR; 27.0-107.5 NIPPLE; 612.9 Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... IN Ln (I... Grade I Top Thread INTERMEDIATE 75/8 6.875 25.4 8,830.7 6,160.7 29.70 L-80 Hydril 563 Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... Wt/Len (I... Grade Top Thread LINER 41/2 3.910 8,584.8 14,816.0 6,259.3 12 60 L-80 Hyd 563 1.1(11 r iletalls ' Nominal ID GAS LIFT; 2,8300 Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Co. (in) 8,584.8 6,123.8 77.80 PACKER BAKER HRD ZXP LINER TOP PACKER 4.900 8,604.8 6,127.9 78.44 NIPPLE BAKER RS NIPPLE TSH -521 PxB 4.890 8,619.1 6,130.7 78.90 SEAL ASSY BAKER 80A0 20'x 4" ID Seal Bore Extension TSH 4.000 SURFACE, 28.1-3,816.3 521 PXP (effective seals 37 ft) GAS LIFT, 4,619.4 8,852.1 6,162.0 86.77 SWELL FREECAP IFSC-11 6.13" OD SWELL PACKER 3.910 PACKER 9,238.5 6,157.9 92.41 FRAC SLEEVE FracSleeve (Ball Actuated) (2.073" Seat for 2.125" 2.063 GAS LIFT; 5,946.0 Bell) 9,801.2 6,162.9 89.19 SWELL FREECAP IFSC-11 6.13" OD SWELL PACKER 3.910 PACKER GAS LIFT; 6,898.3 9,994.1 6,166.4 87.76 SWELL FREECAP I FSC -11 6.77D SWELL PACKER 3.910 PACKER GAS LIFT; 7,599.0 10,380.4 6,187.4 87.89 FRAC SLEEVE FracSleeve (Ball Actuated ) (2.011" Seat for 2.063" 2.000 Ball) 10,712.0 6,200.7 87.61 SWELL FREECAP I FSC -11 6.13" OD SWELL PACKER 3.910 PACKER NIPPLE; 7,844.8 11,097.9 6,197.5 91.68 FRAC SLEEVE FracSleeve (Ball Actuated ) (1.938" Seat for 2.000" 1.938 11,427.0 6,193.5 87.86 SWELL FREECAPI FSC -11 6.13" OD SWELL PACKER 3.910 PACKER GAUGE; 8,569.9 11,773.5 6,209.0 88.06 FRAC SLEEVE FracSleeve (Ball Actuated) (1.886" Seat for 1.938" 1.875 Ball) 12,104.2 6,213.6 90.37 SWELL FREECAP I FSC -11 6.13" OD SWELL PACKER 3.910 PACKER 12,297.4 6,213.3 89.87 SWELL FREECAP I FSC -11 6.13" OD SWELL PACKER 3.910 93L91010 PACKER SEAL ASSY; 8,620.9 12,758.6 6,231.5 87.81 FRAC SLEEVE FracSleeve (Ball Actuated ) (1.823" Seat for 1.875" 1.813 Ball) 13,051.4 6,236.4 87.62 SWELL FREECAPI FSC -11 6.13" OD SWELL PACKER 3.910 PACKER INTERMEDIATE; 25.4-13SWa 7 13,168.0 6,241.4 88.79 SWELL FREECAPI FSC -11 6.13" OD SWELL PACKER PACKER Imp 13,669.2 6,241.2 90.53 FRAC SLEEVE FracSleeve (Ball Actuated ) (1.761" Seat for 1.813" 1.750 Ball) j 14,103.6 6,244.3 89.07 SWELL FREECAPI FSC -11 6.13" OD SWELL PACKER 3.910 PACKER 1 Tubing Description ^string Ma... ID (in) Top (ftKB) Set Depth (ft.. Set Depth (ND) (.. Wt (lblk) Grade Top Connection TUBING 31/2 2.992 22.9 8,631.6 6,133.1 9.20 L-80 EUE 8Rd CoTnptet+on Details Nominal ID Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Co. (i n) 22.9 22.9 0.00 HANGER TUBING HANGER 4.500 612.9 612.7 3.02 NIPPLE CAMCO DS NIPPLE w/ 2.875" Profile 2.875 7,844.9 5,852.3 61.11 NIPPLE SLB DS NIPPLE w/ CAT STANDING VALVE (65") 2.812 8,569.9 6,120.6 77.32 GAUGE SLB GAUGE CARRIER 3-1/2" EUE P x P 2.992 8,620.9 6,131.1 78.96 SEAL ASSY BAKER 8040 GBH LOCATER SEAL ASSY (' 18 ft Fully 2.990 located. ShotDens p (ftKB) r14,584.5 etm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) (shot. Zone Date t) Type Com 14,623.0 6,252.8 6,253.8 12/1312014 SLOTS Slotted Liner, Hydril-563 Pref Joint (36 Holes @ 1/2") Hyd Fra,01her; 9,238.0 � 4 fi \; , Min Top Max Btm Depth Depth Top (TVD) Btm (TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 9,238.0 14,816.0 6,157.9 6,259.3 I Hyd Frac- Other 5/4/2014 I PUMP 781,500# 16/20 PROPPANT IN 7 STAGES FROM 9238'-14,816[ Mandrel Inserts St an on Top (TVD) Valve Latch PortSize TRO Run N Top (ftKB) I (ftKB) Make Model OD (in) Sew Type Type (in) (psi) Run Date Co. 1 2,830.0 2,611.9 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 2/15/2014 2 4,619.4 3,814.3 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 2/15/2014 3 5,946.0 4,697.4 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 2/15/2014 4 6,898.3 5,329.8 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 2/15/2014 51 7,599.0 5,730.1 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.014/25/2014 DCR-1 -; . End Date Annotation NOTE: SLOTS; 14,584.514,623.0 LINER, 8,5848-14.816.0 2E-04 WELL WORK SUMMARY DATE SUMMARY 4/25/2014 PULLED SOV & SET DV @ 7599' RKB. TESTED IA 2000 PSI: ZERO LOSS OVER 15 MIN. MIT TBG 4000 PSI, PASSED. PULLED 2.81 CAT SV @ 7844' RKB. MEASURED BHP @ 8634' SLM. READY FOR FRAC. 5/2/2014 Pump data frac, well freeze protected w/ diesel. Discussed potential challenges splitting lenghty frac between ball drops; concern for balls degrading over the next few days while reloading for next next stages and not providing isolation from previous fracs. Will return when fluids and sand have been loaded on location to enable completion of frac in one day. Note: SLB treating report to be added to Attachements 5/4/2014 Pumped 7 -stage, RA traced Kuparuk A -sand fracture treatment. Placed 781,500# of 16/20 proppant @ 1-8 PPA in horizontal using 30# linear/x-linked gel. Well freeze protected with diesel. Treating iron rigged off well; will return in A.M. to remove tree -saver and demobe equipment. Note: See attached SLB treating report for job detail 5/8/2014 RIH WITH MILLING BHA MILL THROUGH 6 FRAC SLEEVES PUMPING AT 1.75 BPM WITH ONLY THREE STALLS THE FIRST SLEEVE TOOK 8 MIN TO MILL THROUGH, THE SECOND ONE WAS 12MIN AND THEYAVERAGED 10-15 MIN THEREAFTER MILLED DOWN TO 14816' RKB LET THE FINAL GEL SWEEP OUT AND CHASED IT OUT OF HOLE AT 80% PUMPING 1.8 BPM AND PULLING AT 90FPM RETURN IN THE MORNING FOR LOGGING ****JOB IN PROGRESS**** 5/9/2014 START LOGGING FROM 6150' CTMD TO 14800' CTMD AT 30 FPM LOG UP FROM 14800' CTMD TO 6150' CTMD STOP THERE FOR 5 MIN, POOH RIG DOWN AND STAGE THE UNIT FOR THE NIGHT ON EDGE OF PAD ****TURN OVER TO DSO**** 5/11/2014 DRIFTED TBG (STALLED OUT DUE TO DEVIATION) @ 8660' SLM; MEASURE SBHP @ 8585' RKB; 3302 PSI. SET 2.81" CAT SV @ 7844' RKB; PULLED DV'S @ 7599'& 6898' RKB; SET OV @ 7599' RKB & GLV @ 6898' RKB. IN PROGRESS. 5/12/2014 PULLED DV'S & SET GLV'S @ 5946',4619', & 2830' RKB; MITT TO 2500 PSI (PASS); PULLED CAT SV @ 7844' RKB. READY FOR EXPRO FLOWBACK 6j THE STATE (71 GOVERNOR SEAN PARNELL Robert Blakney Completions Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 A"ILaska Oiland Gas 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2E-04 Sundry Number: 314-069 Dear Mr. Blakney: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. DATED this of February, 2014. Encl. Sincerely, Cathy P. oerster Chair STATE OF ALASKA ALA KA OIL AND GAS CONSERVATION COMMON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED FEB 0 5 2014 1. Type of Request: Abandon F Rug for Redrill r Perforate New Pool Repair w ell Change AppOeVNIrYhr Suspend r Rug Perforations Perforate Pull Tubing Time Extension Operational Shutdown Re-enter Susp. Well r Stimulate r Alter casing Other: d"';J t4 IJTI fill 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: z/z`//jp ConocoPhillips Alaska, Inc. lo t men Exploratory Development � Stratigraphic Service 213-168-0 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23505-00 ' 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes No r-7/, 2E-04 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25658, 25665 Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8842 6172 • none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16 108' 108' SURFACE 3788 10.75 3816' 3225' INTERMEDIATE 8803 7.625 8831' 6173' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): none none none - - Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) no packer none irs S� (el 3 / no SSSV none 12. Attachments: Description Summary of Proposal ry 13. Well Class after proposed work: Detailed Operations Program I— BOP Sketch Exploratory r— Stratigraphic Development . Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/1/2014 Oil Gas WDSPL Suspended VANJ GINJ WAG Abandoned 16. Verbal Approval: Date: Commission Representative: GSTOR r SPLUG 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Robert Blakney @ 265-6417 Email: Robert.G.BlakneyCcD.conocophillips.com Printed Name Rob la a Title: Completions Engineer Signature Phone: 265-6417 Date Commission Use Only Sundry Number: p Conditions of approval: Notify Commission so that a representative may witness Plug Integrity j` BOP Test f— Mechanical Integrity Test f— Location Clearance Other: " BDMS MAY 10 2014 Spacing Exception Required? Yes © No Subsequent Form Required: / d APPROVED BY Z --Z74 Approved by: /tom COM I SI N R THE COMMISSION Date: Approved appi(jRljNUfjX4LaTin5 TrOm Lne up to pi dpNruvdi. Form 10-403 (Revised 10/2012) � Submit Form and Attach in Duplicate . e, r „ I— , l , .r. 2E — 04 Sundry Application 2E-04 is currently being drilled. 2E -04's Intermediate (7 5/8") casing was landed on 2/3/14, the production hole will be drilled and completed over the next week. (A schematic of the planned completion is attached). The well will have an approximately 6000' horizontal placed in the Kuparuk A sand completed with a 4.5" liner with 7 ball actuated sliding sleeves and swellable packers between each sleeve. We will drop a ball (progressively getting larger) after each stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. We expect the production to be 300 bpd in 2013 if a successful stimulation is achieved. 2E-04 is the first well in an upcoming southern periphery redevelopment, and because of this we are performing data acquisition during the frac. Prior to the stimulation surface tiltmeters will be installed in an array around the well to monitor fracture orientation during the stimulation. Radioactive tracers will be pumped during each stage. We will come back and log the well to confirm we have good isolation between the stages and that the entire interval was effectively stimulated. Additional documentation discussing the tiltmeter installation and the radioactive tracers are attached. Proposed Procedure: Schlumberger Pumping Services: (Kuparuk A sand Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre -frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 24 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 8400 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 7. PT Surface lines to 9,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 300 bbl breakdown stage (25# linear gel, WF125) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 20 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule @ 20bpm with a maximum expected treating pressure of 7000 psi. W. 0 Stage 1 • 475 bbls YF125FX-D Pad • 240 bbls YF125FX-D w/ 2 ppa 16/20 Carbolite • 240 bbls YF125FX-D w/ 4 ppa 16/20 Carbolite • 95 bbls YF125FX-D w/ 5 ppa 16/20 Carbolite • 80 bbls YF125FX-D w/ 6 ppa 16/20 Carbolite • Ir -192 ZW (RA tracer) • Drop ball 1 Stage 2 • 475 bbls YF125FX-D Pad • 240 bbls YF125FX-D w/ 2 ppa 16/20 Carbolite • 240 bbls YF125FX-D w/ 4 ppa 16/20 Carbolite • 95 bbls YF125FX-D w/ 5 ppa 16/20 Carbolite • 80 bbls YF125FX-D w/ 6 ppa 16/20 Carbolite • Sc -46 ZW (RA tracer) • Drop ball 2 Stage 3 • 475 bbls YF125FX-D Pad • 240 bbls YF125FX-D w/ 2 ppa 16/20 Carbolite • 240 bbls YF125FX-D w/ 4 ppa 16/20 Carbolite • 95 bbls YF125FX-D w/ 5 ppa 16/20 Carbolite • 80 bbls YF125FX-D w/ 6 ppa 16/20 Carbolite • Sb -124 ZW (RA tracer) • Drop ball 3 Stage 4 • 475 bbls YF125FX-D Pad • 240 bbls YF125FX-D w/ 2 ppa 16/20 Carbolite • 240 bbls YF125FX-D w/ 4 ppa 16/20 Carbolite • 95 bbls YF125FX-D w/ 5 ppa 16/20 Carbolite • 80 bbis YF125FX-D w/ 6 ppa 16/20 Carbolite • Ir -192 ZW (RA tracer) • Drop ball 4 Stage 5 • 715 bbls YF125FX-D Pad • 240 bbls YF125FX-D w/ 2 ppa 16/20 Carbolite • 240 bbls YF125FX-D w/ 4 ppa 16/20 Carbolite • 70 bbls YF125FX-D w/ 5 ppa 16/20 Carbolite • 80 bbls YF125FX-D w/ 6 ppa 16/20 Carbolite • 60 bbls YF125FX-D w/ 6 ppa 16/20 Carbolite • Sc -46 ZW (RA tracer) • Drop ball 5 Stage 6 • 715 bbls YF125FX-D Pad • 240 bbls YF125FX-D w/ 2 ppa 16/20 Carbolite 0 0 • 240 bbls YF125FX-D w/ 4 ppa 16/20 Carbolite • 70 bbls YF125FX-D w/ 5 ppa 16/20 Carbolite • 80 bbls YF125FX-D w/ 6 ppa 16/20 Carbolite • 60 bbls YF125FX-D w/ 6 ppa 16/20 Carbolite • Sb -124 ZW (RA tracer) Drop ball 6 Stage 7 • 715 bbls YF125FX-D Pad • 240 bbls YF125FX-D w/ 2 ppa 16/20 Carbolite • 240 bbls YF125FX-D w/ 4 ppa 16/20 Carbolite • 70 bbls YF125FX-D w/ 5 ppa 16/20 Carbolite • 80 bbls YF125FX-D w/ 6 ppa 16/20 Carbolite • 60 bbls YF125FX-D w/ 6 ppa 16/20 Carbolite • Ir -192 ZW (RA tracer) • Flush with 80 bbls of linear fluid (WF125) and freeze protect • Total Sand: Approx. 775,000 lbs 16/20 Carbolite 12. Monitor the surface pressure fall-off at the end of the job for 30 minutes, if the well does not screen out. 13. RDMO SLB Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 14. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). 15. Flowback will be initiated through Expro until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to appropriate disposal well until they are clean enough for production.) 16. All radioactive material will be disposed of according to ConocoPhillips and regulatory standards. (see attachment for handling guidelines). Cement Evaluation of 2E-04 and wells within'/4 mile of 2E-04 2E - 04: 7 5/8" Casing cement job was pumped on 2/4/2013 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 10.3 ppg mud. The plug was bumped @ 1300 psi; the floats were checked and they held. Good returns were observed during the job. No other wells in the area Summary Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. It has also been determined that the frac will not adversely affect wells within a % mile radius or any other nearby well. W. S Stimulation Surface Rig -Up 1 Minimum pressure rating on all surface treating lines 10,000 psi Main treating line PRV is set to 95% of max treating pressure IA parallel PRV set to 3500 psi Frac pump trip pressure setting are staggered and set below main treating line PRV Tree saver used on all fracs rated for 15,000 psi. I Pop-off Tame I Roo Trtmk 0 0 Stimulation Tree Saver OPEN POSITION CLOSED POSITION (PRIOR TO MANDREL INSERTION) (UNNDRE! INSERTED) OPERATED VALVE OPERATED VALVE L 11 ra OLIAD N ASSE6 PLACE IN' • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 1/2tubing and 1.75" down 3 1/2 tubing. • Max rate with 2.25" mandrel is 60 bpm and with 1.75" mandrel 36 bpm E Surface Tiltmeters - Construction, Installation, Decommission 53 surface tiltmeter are planned to be installed prior to the 2E-04 hydraulic fracture stimulation (see attached map for proposed locations). Each tiltmeter will be constructed using the plan shown in the downhole diagram below. The holes are to be drilled with a Geoprobe machine to 40 feet. Once the holes have been drilled and the PVC casing installed, the tiltmeters will be installed and allowed to settle for up to 4 weeks before the frac. After the frac has been completed, all of the tiltmeter data will be downloaded and the tiltmeter holes decommissioned. The PVC casing will be tried to be recovered, but failing that the casing will be cut several inches below grade and removed as stipulated by the approval conditions from the Department of Natural Resources. Tundra travel is required to access the tiltmeter hole locations. Typical surface Tiltmeter Downhole Diagram General outline for Construction, Installation, Decommission: 1. Drill 6"-8" hole to a depth of 40 feet using a Geoprobe machine that is capable of drilling with air and push/pull. 2. Install -45' long 4" PVC casing in the hole. Ensure end cap has been sealed before run in hole. 3. Pour water in the annulus to freeze the casing in place (coupling the casing to the formation). 4. Install tiltmeter followed by 70 mesh dry sand. 5. Install -5-6'x 8" PVC outer casing over the 4" casing to shield the hole from the elements. 6. Allow tiltmeters to "settle" for up to 4 weeks prior to the frac. 7. Prior to frac ensure all tiltmeters are fully operational (batteries, etc.). 8. Download data after frac. i 9. Pull PVC casing. If cannot pull the whole casing, pull the casing until it breaks ensuring the break is below the tundra grade. 10. Back fill hole with the native material and locally sourced sand if required. WELLBORE TARGET DETAILS (MAP 00-ORDINATES)2 E®® ■ W p06 Name TVDSS +W-S+E!-W Northing Easting Shape 2E-04 (wp02) CP1 6031.00 -5745.16 -2654.77 5938218.00 1667372.00 Point 14:10, August 28 2013 211-04 (wp02) Heel 6038.00 -4943.63 -2462.60 5939020.00 1667561.00 Point QuarterMile V ew 2E-04 (wIp02j CP4 Circle 6055.00 8058.27 -2945 69 593 11 5904.00 1667094.00 Point6038.00 -4943.83 -2462.60 5939020.00 1667561.00 Circle (Radius 132(100) on 2E-04 (wp02) CP5 6130.00 -8552.28 -2954.83 5935410.00 1667083.00 Point r E-04 (wp02) CP7 6136.00 -9888.26 -2995.08 5934074.00 1667048.00 Point -04 2) CP6 6143.00 -9070.27 -2971.87 5934892.00 1667068.00 Point - 2Toe 6148.00 -10820.32 -3004.74 5933142.00 1667042.00 P --- � W ry� E 2) Toe Circle 6148.00 70820.32 3004.74 5933142.00 166704200 Circle (Radius: 1320.00) a 0 1 ti � � I iL ! -2500 N -------- -- 24 C 2F -11A L3 p^ 2F-11 AL1 R• 4- - - o -5000 --- - -------------- N 2F -19A ! -0 z -7500 - ----------- C/) -10000 .... - ------------- - t - -- - __{...----------- - - 1 E'-04wp 6 i -12500 - -- - --------------------...._--_ --- - - --- ---- --- ..... - - ------ -- - - i -10000 -7500 -5000 -2500 0 - 2500 5000 7500 10000 West( -)/East(+) (2500 Win) 2E — 04 Kuparuk A sand Multi -stage Frac Model E 0 Frac Design 1 stage Job Description Step Name Pump Rate (bbl/min) Fluid Name Step Fluid Volume (gal) Gel Conc. (Ib/mgal) Prop. Type and Mesh Prop. Conc. (PPA) Pad 20 YF125ST 20000 25.0 0.00 2.0 PPA 20 YF125ST 10000 25.0 16/20 C -Lite 1.00 4.0 PPA 20 YF125ST 10000 25.0 16/20 C -Lite 2.00 5.0 PPA 20 YF125ST 4000 25.0 16/20 C -Lite 3.00 6.0 PPA 20 YF125ST 3334 25.0 16/20 C -Lite 4.00 Flush 20 YF125ST 3360 25.0 0.00 Totals (7 stages) YF 125 FX -D - 9,600 bbls WF 125 - 359 bbls 16/20 Carbolite - 775,000 Ibs r1 0 Model Results Initial Fracture Top TVD - 6280.0 ft Initial Fracture Bottom TVD - 6340.0 ft Propped Fracture Half -Length - 380.0 ft EOJ Hyd Height at Well - 60. ft Average Propped Width - 0.21 in Disclaimer Notice: — This model was generated using commercially available modeling software and is based on engineering estimates of reservoir properties. ConocoPhillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results. n u I DIM 149'50'0"W 149'40'0"W DS2V RM OS23 D72 H -DS2F DS -2S Ice Road DS2Z DS2D , §2EE* 9E* IF �S1 L Kuparuk River Unit 01011W 149*50'0"W 149'40'0"VV 1E Q CD I - Proposed Tiltmeter Locations Proposed Tiltmeter Location Infrastructure Road Pipeline Pad Boundaries Unit 0 0.75 1.5 m I Miles May 31, 2013 ConocoPhillips Alaska, Inc. 1. GUIDELINES FOR USE OF RADIOACTIVE TRACERS DURING WELL STIMULATIONS ALASKA OPERATIONS 1. Only licensed personnel providing radioactive (R/A) tracing services are allowed to handle R/A material to, from, or at any location or facility. 2. The licensed R/A service company representative must maintain their company's license and carry MSDS sheets on location for all R/A isotopes present or in use. 3. The following equipment and paperwork shall be present prior to beginning any tracer operation: TLD Badge - for monitoring exposure Survey Meter - currently calibrated -capable of detecting beta and gamma radiation Warning Signs - Posted at the proper restricted area ( 2mr/hr) Rubber Gloves - For protecting hands while handling radiation Trash Bags - For collecting R/A waste Sponges - For cleaning in case of spill Rad Wash (or similar surfactant) - For decontamination Current License - Contains important information and documents MSDS Sheets - Identifies safety and health concerns Operating/Emergency Manual - Contains important procedures 4. The following procedures should be followed on each job involving R/A tracers: a. Radio contact between the R/A service personnel and frac personnel must be maintained. b. Restricted area must be identified and marked with signs. Access to this area must be restricted to authorized personnel. C. Any leaks in the frac line need to be checked for radiation before being repaired. d. Bleed off lines or lines used for treesaver safety should be laid to the flow -back tank. e. Surveys to check radiation levels should be made on the following areas before the job and documented: pumps, frac line, restricted area, wellhead, flowback tank. 5 After the job, the same areas should be checked again for radiation levels to insure that no significant amounts of radiation remain in the equipment or on the location. 6. The following injection procedures should be observed: a. Multiple injection points for back-up contingency. b. Ability to isolate with a valve the radioactive injection pump if malfunction develops. C. Loading in injector not more than 30 mCi at any one time, to reduce restricted area exposure and reduce spill potential. 0 • d. Do not inject directly into blender and/or manifold. Rather, isolate pump entry points. 7. The following procedures should be utilized during flowback of a well when R/A material has been used: a. People in charge of the flowback should be made aware that the R/A material has been used. b. All people contacting flowback fluids or proppants should wash the contacted areas with soap and water. C. Hands should be cleansed thoroughly before eating, drinking or smoking. d. Fluids and proppants should not be handled unnecessarily. e. Flow any returns to holding tank. EMERGENCY PROCEDURES Uncontrolled Sandout or Fluid Reversal - In the event of an uncontrolled sandout or fluid reversal, the following steps shall be taken to prevent personnel and environmental contamination. a. Remove all unnecessary personnel from the area and perform a survey prior to each exit unless other hazards require immediate personnel removal. b. Establish and secure a restricted area with ropes and the proper warning signs to indicate the nature of the hazard. C. Divert all flowback to the holding tank. d. After the flowback has ceased, initiate a complete survey of the area, equipment, vehicles and personnel. Indicate, on a sketch of the area, the magnitude of the contamination and inform all personnel of the nature and extent of the contamination. All items free of contamination shall be removed from the area in a manner to prevent the spread of contamination. e. Proceed to clean contaminated items until survey results are at ambient levels. Retain all decontamination fluid, towels, etc. for later disposal. Obtain samples of fluids, soil, and any other media. Assay samples on a portable survey instrument (using both the end window and gamma scintillation probes). Note on the sketch of the area the degree of contamination. Remove the top six inches of soil and contain in the tank. Also divert any standing fluid to the tank. Resurvey the locations where the contamination was removed. If the survey instrument does not record any reading over ambient levels, collect samples and submit to the Houston facility for analysis. g. If the sample results indicate the release was below the prescribed limits, then no subsequent action is necessary. 0 • h. If the sample results are above the prescribed limits, the area in question will be decontaminated until the limits are met. The material in the tank shall be disposed class II disposal well or held for decay. 2. Routine Sandout or Fluid Reversal - Routine sandout or fluid reversal shall be handled in accordance with the following procedures. a. If the fluid is diverted to a holding tank, sample the well fluid contained in the holding tank. If the instrument readings are above unrestricted area levels, post the tank with caution signs and erect a temporary personnel barrier. Notify the Radiation Safety Officer of the situation. ProTechnics must maintain control of the tank until release can be accomplished. Submit the samples for analysis. The sample analysis will indicate which of the following is the preferred disposal method for the contents of the tank: b. Dispose into a class II disposal well 11. Sandout/Fluid Reversal Limit - Every effort shall be made to keep releases of tracer material As Low As Reasonably Achievable (ALARA). The following limits apply only to our Zero Wash® products. The activity limit for disposal in a class II disposal well will be 1,000 pCi/gm (0.001 uCi/gm) of each Zero Wash® isotope. (Sc -46, Ir -192, & Sb -124). 2E-04 PRODUCER S (As Drilled Depths) 4-1/2" Tubing Hanger / Tree 16" Conductor to -- 110' 3-%" DS Landing Nipple 3-1/." MMG GLM x 1-1/." OD 10-3/4" 45.5# L-80 BTC -M Surface Casing @ 3816' MD / 3283' TVD cemented to surface 3-1/2" 9.3 # L-80 EUE Tubing 3-%" 2.813" DS Nipple @ 61 deg Uoper Completion 1) Tubing Hanger, 4-'/z" IBTM @ 22.93' MD / 22.93' TVD 2) 4-%" 12.6#/ft IBT-M Tubing (1 joint) 3) XO 4-'/2' 12.6# IBT-M x 3-%" 9.3# EUE-8rd-M L-80 @ 57' MD / 57' TVD 4) Cameo 2.875" DS -Profile @ 613' MD / 612' TVD 5)3-1/2" x 1%' Cameo MMG GLM w/ DV @ 2830' MD / 2605' TVD 6)3-1/2" x 1-%" Cameo MMG GLM w/ DV @ 4619' MD / 3801' TVD 7)3-1/2" x 1-%" Cameo MMG GLM w/ DV @ 5946' MD / 4698' TVD 8) 3-%"x 1%2' Cameo MMG GLM w/ DV @ 6898' MD / 5317' TVD 9) 3-%" X 1-Y2" Cameo MMG GLM w/DCK2 @ 7599' MD / 5710' TVD 10) Cameo 2.813" DS -Profile wl CAT Standing Valve @ 7845' MD 15850' TVD 11) SLB Bottom Hole Pressure Gauge @ 8570' MD 16114' TVD 12) 80-40 Seal Assembly @ 8621' MD / 6133' TVD Lower Completion 13) HRD ZXP Liner top Packer @ 8585' MD / 6113' TVD RS Nipple TSH -521 PxB @ 8605' MD / 6128' TVD Flex Lock Liner Hanger TSH -521 PxP @ 8608' MD / 6130' TVD 14) 6.13" OD Swell Packer @ 8852' MD / 6162' TVD 15) Ball Actuated Sleeve (2.073" Seat for 2.125" Ball) @ 9239' MD / 6157' TVD 16) 6.13" OD Swell Packer @ 9801' MD / 6163' TVD 17) 6.13" OD Swell Packer @ 9994' MD / 6167' TVD 18) Ball Actuated Sleeve (2.011" Seat for 2.063" Ball) @ 10,380'/ 6188' TVD 19) 6.13" OD Swell Packer @ 10,712' MD / 6201' TVD 20) Ball Actuated Sleeve (1.948" Seat for 2.000" Ball) @ 11,098' MD / 6197' TVD 21) 6.13" OD Swell Packer @ 11,427' MD / 6194' TVD 22) Ball Actuated Sleeve (1.886" Seat for 1.938" Ball) @ 11,774' MD / 6208' TVD 23) 6.13" OD Swell Packer @ 12,104' MD / 6214' TVD 24) 6.13" OD Swell Packer @ 12,297' MD / 6213' TVD 25) Ball Actuated Sleeve (1.823" Seat for 1.875" Ball) @ 12,759' MD t 6231' TVD 26) 6.13" OD Swell Packer @ 13,051' MD / 6236' TVD 27) 6.13" OD Swell Packer @ 13,167' MD / 6240' TVD 28) Ball Actuated Sleeve (1.761" Seat for 1.813" Ball) @ 13669' MD ! 6240' TVD 29) 6.13" OD Swell Packer @ 14,103' MD / 6259' TVD 30) 4-'/2', 12.6 #/ft, Hydril-563 Pre -Perforated Pup @ 14,623' MD / 6252' TVD 31) 4-%," L-80 12.6# Orange Peel Shoe @ 14,816' MD / 6258' TVD 7-5/8" ZXP Liner Hanger / Top Packer 7-5/8" 39# TN-11OSS Hyd-563 Casing @ 8830' MD / 6162' TVD (88° ) 7-5/8" 29.7# L-80 BTC -M Casing @ 8281' MD / 6030' TVD (70') 6.13" x 4-'/2" Swell Packer Drillable Frac Sleeve (Drop Ball System) 6-1/2" Hole TD @ 14823' MD / 6259' TVD 0 M—Aff—A ED 0 4-1/2" 12.6# L-80 Hydril-563 Liner Pre-perf Pup 5993' Horizontal Section 4-%" Orange Peel Shoe 1w Weathed" LABORATORIES State of Alaska Oil and Gas Cotnmision. 333 7`b Ave. Anchorage, AK Weatherford Labs 3209 Denali Anchorage, AK 907-646-8605 Chip Samples: Conoco -Phillips KRU 2E-04PB1, N. Slope, AK, HH -68486 Date: Z - 2 J-/51 Material Shipping Record Depths 7425-7512 Contact: Dave Foster (307) 265-8800 Signed: ' State of Alaska: 1 ` total boxes JAN 2 3 2014 AOGCC Weatherford' LABORATORIES ConocoPhillips Alaska, Inc. 2E-04PB1 Kuparuk River Unit 1.00 7425.00 X 2.00 7426.00 X 3.00 7427.00 X 4.00 7428.00 X 5.00 7429.00 X 6.00 7430.00 X 7.00 7431.00 X 8.00 7432.00 X 9.00 7433.00 X 10.00 7434.00 X 11.00 7435.00 X 12.00 7436.00 X 13.00 7437.00 X 14.00 7438.00 X 15.00 7439.00 X 16.00 7440.00 X 17.00 7441.00 X 18.00 7442.00 X 19.00 7443.00 X 20.00 7444.00 X 21.00 7445.00 X 22.00 7446.00 X 23.00 7447.00 X 24.00 7448.00 X 25.00 7449.00 X 26.00 7450.00 X 27.00 7451.00 X 28.00 7452.00 X 29.00 7453.00 X 30.00 7454.00 X 31.00 7455.00 X 32.00 7456.00 X 33.00 7457.00 X 34.00 7458.00 X 35.00 7459.00 X 36.00 7460.00 X 37.00 7461.00 X 38.00 7462.00 X 39.00 7463.00 X • DRILL SHEET State of Alaska Samples 40.00 7464.00 X 41.00 7465.00 X 42.00 7466.00 X 43.00 7467.00 X 44.00 7468.00 X 45.00 7469.00 X 46.00 7470.00 X 47.00 7471.00 X 48.00 7472.00 X 49.00 7473.00 X 50.00 7474.00 X 51.00 7475.00 X 52.00 7476.00 X 53.00 7477.00 X 54.00 7478.00 X 55.00 7479.00 X 56.00 7480.00 X 57.00 7481.00 X 58.00 7482.00 X 59.00 7483.00 X 60.00 7484.00 X 61.00 7485.00 X 62.00 7486.00 X 63.00 7487.00 X 64.00 7488.00 X 65.00 7489.00 X 66.00 7490.00 X 67.00 7491.00 X 68.00 7492.00 X 69.00 7493-00 X 70.00 7494.00 X 71.00 7495.00 X 72.00 7496.00 X 73.00 7497.00 X 74.00 1 7498.00 X 75.00 7499.00 X 76.00 7500.00 X 77.00 7501.00 X 78.00 7502.00 X North Slope Burrough, Alaska HH -68486 79.00 75_03.00 X 80.00 7504.00 X 81.00 7505.00 X 82.00 7506.00 X 83.00 7507.00 X 84.00 7508.00 X 85.00 7509.00 X 86.00 7510.00 X 87.00 7511.00 X 88.00 7512.00 X THE STATE F 0 1 W 4F, W W441k GOVERNOR SEAN PARNELL G.L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk Oil Pool, 2E-04 ConocoPhillips Alaska, Inc. Permit No: 213-168 Alaska Oil and Gas Surface Location: 580' FSL, 160' FWL, Sec. 36, TI IN, R9E, UM Bottomhole Location: 319' FSL, 2853' FEL, Sec. 11, T10N, R9E, UM Dear Mr. Alvord: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Enclosed is the approved application for permit to drill the above referenced development well. 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 KRU 2E-04 PH and API number (50-029-23505-70- 00 from records, data and logs acquired for well (name on permit). 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. 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 a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P. ioerster Chair, Commissioner DATED this /;) day of November, 2013. • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 C IV a NOV 042013 AOGCC 1a. Type of Work: 1 b. Proposed Well Class: Development - Oil 0 Service - Winj ❑ Single Zone ❑✓ , 1 c. Specify if well is proposed for: Drill ❑ • Lateral Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: / ,Blanket, U Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180. 2E-04 . 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 14738' - TVD: 6282' - Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 580' FSL, 160' FWL, Sec. 36, T11 N, R9E, UM - ADL 25658, 25665 Kuparuk River Oil Pool - Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1240' FSL, 2174' FEL, Sec. 2, TION, R9E, UM - 2584, 2586 12/15/2013 Total Depth: 9. Acres in Property: -WO 14. Distance to 319' FSL, 2853' FEL, Sec. 11, T10N, R9E, UM • -25M 5 61 (LI Nearest Property: 2427' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 134 feet 15. Distance to Nearest Well Open Surface: x- 529972 y- 5944222 Zone- 4 • GL Elevation above MSL: 106 feet to Same Pool: 2E-06, 4399' 16. Deviated wells: Kickoff depth: • 528 ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: - 92° deg Downhole: 3400 psig . Surface: 2796 psig 1 18. Casing Program: Spec fications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing_Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5# H-40 Welded 79.5' 28' 28' 107.5' 107.5' pre -driven 13.5" 10.75" 45.5# L-80 Hydril 563 3872' 28' 28' 3900' 3290' 1498 sx ALC, 195 sx DeepCRETE 9.875" 7.625" 29.7 & L-80 & Hydril 563 8072' 28' 28' 8100' 6111' 425 sx Class G 9.875" 7.625" 39# TN-110SE Hydril 563 500' 8100' 6111' 8600' 6174' included above 6.5" 4.5" 1 12.6# 1 L-80 Hydril 563 5429' 8400' 6157' 14738' 6282' open hole liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Property Plat ❑ BOP Sketct ❑ Drilling Prograrr ❑ Time v. Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q t 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: f..,.,%, of, 2,0)3 22. 1 hereby certify that the foregoing is true and correct. Contact Haibin Guo t4va', t''; , %i-- i-oEmail EmailHaibin.Guo(aD-contractoccoa.com Printed Name G. L. Alvord Title Alaska Drilling Manager Signature'rte, i --Phone: 265-6120 Date Commission Use Only Permit to Drill API Number: Permit App See cover letter C� I 50- Q 35 Date: for other requirements 11 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: //"� //,� O� Samples req'd: Yes ❑ No Mud log req'd: Yes❑ No bK IS vt� H2S measures: Yes [✓� No ❑ Directional svy req'd: Yes ff No Spacing exception req'd: Yes ❑ No Inclination -only svy req'd: Yes❑ No,[ ' // � APPROVED 13Y THE ,.a l Approved bv(, / - COMMISSIONED' COMMISSION Date: e Form 10-401 (Re visaed 10/2012) �� `This permit is valid for 24 rponths frpm the date of approval (20 AAC 25.005(g)) s , 51 W 15 ConocoPhillips Alaska, Inc. • Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 November 05, 2013 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 NOV 0 �6 20" W- ConocoPhillips Re: Application for Permit to Drill Well 2E-04, A Kuparuk A5 Sand Producer Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a permit to drill an onshore grassroots producer well from the 2E pad. The expected spud date for this well is December 15th, 2013. It is planned to use Rig Doyon 141. ✓ 2E-04 is planned to be a horizontal Kuparuk A5 sand producer. The surface section will be drilled with 13-1/2" bit and run 10-3/4" casing to +/-3,900'MD/3,290'TVD. A pilot hole will be drilled with 9-7/8" bit to the top of A5 sand and run coring BHA to take 90' core across A5 sand for formation evaluations. After the coring we'll continue to drill and logging the formations to the base of Miluveach, which is +/-300' below A5. The pilot hole will be P&A to +/- 5,500'MD/4,487'TVD with cement. The 9-7/8" intermediate hole will be kicked off at +/-5,671'MD/4,615'TVD and landed in A5 sand at +/-8,600'MD/6,174'TVD. 7-5/8" casing will be run and cemented. The production hole will be drilled with 6-1/2" bit and run 4-1/2" liner to +/- 14,738'MD/6,282'TVD. The upper completion will be run on 3-1/2" tubing with gas lift mandrels. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d) (2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Haibin Guo at 265-1487 (Haibin.GuogConocoPhillips.com) or Chip Alvord at 265-6120. Sincerely, �S hip Alvord Drilling Manager Application for Permit to Drill Document Kuparuk Well 2E-04 Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as 2E-04 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 580' FSL, 160' FWL, Sec 36, T 11N, R009E, UM NGS Coordinates Northings: 5,944,222.34' Eastings: 529,972.04' IRKB Elevation 133.9' AMSL Pad Elevation 105.9' AMSL Location at Top of 1,240.46' FSL, 2,173.58' FEL, Sec 2, T1ON, R009E, UM Productive Interval Ku aruk A5 Sand NGS Coordinates Measured Depth, RKB: 8,465' Northings: 5,939,594.77' Eastings: 527,660.04' Total Vertical Depth, RKB: 6,163' Total Vertical Depth, SS: 6,029' Location at Total Depth 319.16' FSL, 2,852.57' FEL, Sec 11, T1ON, R009E, UM NGS Coordinates Northings: 5,933,391.70' Eastings: 527,010.01' Measured Depth, RKB: 14,738' Total Vertical Depth, RKB: 6,282' Total Vertical Depth, SS: 6,148' and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment: Directional Plan And (2) for all wells within 200feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, exceptfor an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (ROPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 141. • • Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The maximum potential surface pressure (MPSP) while drilling 2E-04 is calculated using a maximum reservoir pressure of 3,400 psi, a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A5 sand at 6,040' TVD (WP06): A Sand max. BHP = 3,400 psi A Sand estimated depth (WP06) = 6,040' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 604 psi (6,040' TVD * 0.10 psi/ft) MPSP = BHP — gas column = 2,796 psi (3,400 psi — 604 psi) (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. And (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensityfor differential sticking; See attached 2E-04 Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.0300; A procedure is on file with the commission for performing LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application fora Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre -perforated liner, or screen to be installed Casing and Cement Program Casing and Cementing Program CsglTbg Hole Size Weight Grade Conn. Length Top MD/TVD Btm MDlTVD Cement Program OD (in) (Ib/ft) (0) (ft) (ft) 16 24 62.5 H-40 Welded 79.5 Surf 107.5 / 107.5 Cemented on 10/27/1984 Cement to Surface with 10-3/4 1/2 L-80 Hydril 3,872 Surf 3,900 / 3,290 1,498 sx ALC Lead 11.02 ppg, 45.5 195 sx Dee CRETE Tail Slurry 12.0 ppg 7-5/8 9-7/8 29.7 L-80 Hydril 8,072 Surf 8,100 / 6,111 425 sx Class G at 15.8 ppg w/ TOC at 7,000' MD 7-5/8 9-7/8 39 TN- Hydril 500 8,100 / 6,111 8,600 / 6,174 11OSS 563 41/2 6-1/2 12.6 L-80 Hydril 5,429 8,400 / 6,157 14,738 / 6,282 Open hole liner w/ frac sleeves • • Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the divetter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference diverter schematic on file for Doyon 141. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, exceptfor an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Mud Program Summary Diagram of Doyon 141 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Surface 13-1/2" Hole 10-3/4" Casing 2E-04 P61 9-7/8" Hole Intermediate 9-7/8" Hole 7-5/8" Casing Production 6-3/4" Hole 4-1/2" Liner Mud System Spud Mud KLASHIELD LSND FLO-PRO NT Density 8.8-9.4 10.5-11.0 9.5-10.0 9.5-10.0 PV 30-50 10-20 10-20 10-20 YP 40-80 20-28 16-24 16-24 Funnel Viscosity 200-300 N/A N/A N/A Initial Gel 30-50 10-12 10-12 5 - 8 10 minute Gel 30-50 10-18 10-18 5-12 API Filtrate NC <6 <6 < 6 HTHP Fluid Loss at 160 F N/A <8 <10 <10 ipH 9.0-10.0 9.5-10.0 9.0-10.0 9.5-10.0 Diagram of Doyon 141 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to attachment for proposed well schematic. 1. MIRU Doyon 141 on 2E-04 conductor. 2. NU and function test diverter system and prepare spud mud. 3. Spud and directionally drill 13-1/2" hole to the 10-3/4" surface using point at +/-3,900 MD/ 3,290' TVD according to the directional plan. Run MWD / LWD (GR/RES) logging tools in drill string as required for directional monitoring and formation data gathering. 4. Run and cement 10-3/4" 45.5# L-80 casing with stage cementing tool (contingency, in case primary cement doesn't come to surface). Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with mud. 5. Nipple down diverter and install wellhead and test. Nipple up BOPE and test to 3,500psi x 30min. Chart and record results. 6. PU 9-7/8" drilling BHA. Drill out stage cementing tool. Pressure test 10-3/4" casing to 2500 psi x 30 min. Chart and record results. 7. Drill out cement and 20' of new formation. Perform LOT. Minimum acceptable leak -off for drilling ahead is 12.7 ppg EMW. 8. Directionally drill 9-7/8" pilot hole to core point at +/-7,332' MD / 6,156' TVD. Run MWD/LWD (GR/RES/NEU/DEN) logging tools in drill string as required for directional monitoring and formation data gathering. 9. Run 8-1/2" x 4" coring BHA to cut 90' core of A5 sand. 10. Continue to drill 9-7/8" pilot hole to TD at +/-7,700' MD / 6,527' TVD. Run MWD/LWD (GR/RES/NEU/DEN) logging tools in drill string as required for directional monitoring and formation data gathering. 11. Set cement plug to P&A the 9-7/8" pilot hole to +/-5,500'MD/4,487'TVD. 12. Run 9-7/8" drilling BHA to kick off at +/-5,671'MD/4,615'TVD. irectionally drill 9-7/8" intermediate hole to TD at +/-8,600' MD / 6,174' TVD. Run MWD/LWD (GR/RES)"logging tools in drill string as required for directional monitoring and formation data gathering. 13. Change upper rams to 7-5/8". Test BOPE to 3,500psi x 30min. Chart and record results. 14. Run 7-5/8" 29.7# L-80 and 7-5/8" 39# TN-110SS casing and cement. 15. Freeze protects 7-5/8" casing backside. 16. Change upper rams to 3-1/2" x 6" for next drill string. Test BOPE to 3,500psi x 30min. Chart and record the results. 17. LD 5" DP and PU 4" DP with 6-1/2" hole BHA. 18. Pressure test 7-5/8" casing to 3,500 psi x 30 min. Chart and record results. 19. Drill out cement and 20' new formation and perform LOT. Minimum acceptable leak -off for drilling ahead is 12.7 ppg EMW. 20. Directionally drill 6-1/2" production hole to TD at +/-14,738' MD / 6,282' TVD. Run MWD/LWD 1 (GR/RES/NEU/DEN) logging tools in drill string as required for directional monitoring and formation data gathering. 21. Run lower completion of 4-1/2" liner with frac sleeves, liner top hanger/packer and swell packers for zonal isolation. n D i n i �,11!,?];, C] • 22. Displace 7-5/8" casing to kill weight brine. 23. Run upper completion of 3-'/2, 9.3#, L-80 EUE tubing with GLMs. Space out and land hanger. 24. Test tubing and tubing -casing annulus separately to 3500 psi x30min. Chart and record the results. 25. ND BOP and NU X -MAS tree. Test tree and freeze protect annulus. 26. Rig down and move out rig. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill music be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the 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 Il disposal well (1R- 18 or 1B 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. (659-7212). Attachments: Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 0 Di� IV t V` tfI ConocoPhillips(Alaska) Inc. Kuparuk River Unit CD Kuparuk 2E Pad Plan: 2E-04 �- Plan: 2E-04PB1 Plan: 2E-04PB1wp06 Permit P Plan Summary � 28 August, 2013 ConocoPhillips Alaska 2F-10 -14 111 k2F-11AL2 2k-JIfAL 1 2E-04PB1 wp06 Easting (2000 ft/in) 2E -162E-11 / 1 L- 16:36, August 27 2013 11—L -16 1 L-22 1L-19 - 1 L -26A -15 2E-10 1L-17 1L-1 - 1L- 8 2E-08 1 L-23 1 L-24 Z O N O O O 2E-07 2E-05 2E-17 • 2E-06 2E-03wp05 Easting (2000 ft/in) D J 2E-04PB1wp06 Plan View 1,000 -500 2000 1000 3000 0 0 X1500 10-3/4" x 13-1/2'/1 Z 4000 0 X2000 S000 -2500- 25006000 6 000 -3000 -3000 -2500 -2000 -1500 -1000 -500 0 500 1000 West( -)/East(+) (500 ft/in) 2E-04PB1 wp06 Section View 0- 00 1000 1500 'po C) �O�O 7- �� O 0 3000 0 10-3/4" x 13-1/2" hPl0 4500— -7000 7000 6000 1 ° [2&04PB-1 7707 7500— -4500 -3000 -1500 0 1500 3000 4500 6000 7500 Vertical Section at 180.00° (1500 ft/in) Schluder9epPlan 21E-04P[31wp06 Audit Notes: Schlumberger 'w,, ConocoPhillips Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section Summary w -Ire c tion -5 00, XikA Alaska Company: ConocoPhillips(Alask a) Inc. . ... . Local Co-ordinate Reference: Well Plan: 2E-04 Project: Kuparuk River Unit . . . . . . . .. . TV D Reference: Plan: 105.9+28 @ 133.90ft (Doyon 141) Site: Kuparuk 2E Pad MD Reference: Plan: 105.9+28 @ 133.90ft (Doyon 141) Well: Plan: 2E-04 . ... . .. ... . .. . . . . . . North Reference: True Wellbore: Plan: 2E-04PB1 Survey Calculation Method: Minimum Curvature Design: 2E-04PB1wp06 Database: EDM v16 Prod C-7) r� Project Kuparuk River Unit Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Kuparuk 2E Pad ite Position: Northing: 5,944,247.48 ft Latitude: 70o 15'31.481 N rom: Map Easting: 529,971.75 ft Longitude: 149' 45'27.897 W osition Uncertainty: 0.00 ft Slot Radius: Grid Convergence: 0.23 W— Plan: 2E-04 Well Position +N/ -S 0.00 ft Northing: 5,944,222.34 ft Latitude: 70' 15' 31.234 N +E/ -W 0.00 ft Easting: 529,972.04 ft Longitude: 149'45'27.891 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 105.90ft agnetics Model Name Sample Date Dechrtatio a gg BGGM2012 8/27/201315.47 79.88 57,350 812812013 1:50:26PM Page 2 COMPASS 2003.16 Build 69 0 0 21E-04P[31wp06 Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section Depth From w -Ire c tion -5 00, XikA im 0, '0 28.00 0.00 0.00 180.00 812812013 1:50:26PM Page 2 COMPASS 2003.16 Build 69 0 0 ConocoPhillips Alaska Survey Tool Program Date >I Vert. Error (ft) From To 529,972.04 0.00 (ft) (ft) Survey (Wellbore) Tool Name Description 28.00 700.00 2E-04PB1wp06 (Plan: 2E-04PB1) GYD-GC-SS Gyrodata gyro single shots 700.00 3,900.00 2E-04PB1wp06 (Plan: 2E-04PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3,900.00 7,707.23 2E-04PB1wp06 (Plan: 2E-04PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC d Survey Lata Error >I Vert. Error (ft) (ft) (ft) 529,972.04 0.00 ND Inc 529,972.04 Azi TVD TVDSS DLeg TFace Northing eft) f) 2.30 (°) (ft); (ft) (-1100ft) V) (ft) 28.00 0.00 0.00 28.00 -105.90 0.00 0.00 5,944,222.34 100.00 0.00 0.00 100.00 -33.90 0.00 0.00 5,944,222.34 200.00 0.00 0.00 200.00 66.10 0.00 0.00 5,944,222.34 300.00 0.00 0.00 300.00 166.10 0.00 0.00 5,944,222.34 400.00 0.00 0.00 400.00 266.10 0.00 0.00 5,944,222.34 500.00 0.00 0.00 500.00 366.10 0.00 0.00 5,944,222.34 528.00 0.00 0.00 528.00 394.10 0.00 0.00 5,944,222.34 KOP: DLS 2 TFO 210 600.00 1.44 210.00 599.99 466.09 2.00 210.00 5,944,221.55 700.00 3.44 210.00 699.90 566.00 2.00 0.00 5,944,217.86 800.00 5.44 210.00 799.59 665.69 2.00 0.00 5,944,211.14 866.89 6.78 210.00 866.10 732.20 2.00 0.00 5,944,204.96 Start 100.00 hold at 866.89 MD 900.00 6.78 210.00 898.98 765.08 0.00 0.00 5,944,201.57 966.89 6.78 210.00 965.40 831.50 0.00 0.00 5,944,194.72 Start DLS 4.00 TFO 0.00 977.47 7.20 210.00 975.90 842.00 4.00 0.00 5,944,193.60 T-3 Sand 1,000.00 8.10 210.00 998.23 864.33 4.00 0.00 5,944,191.00 1,100.00 12.10 210.00 1,096.66 962.76 4.00 0.00 5,944,175.78 1,200.00 16.10 210.00 1,193.63 1,059.73 4.00 0.00 5,944,154.64 Easting Lata Error >I Vert. Error (ft) (ft) (ft) 529,972.04 0.00 0.00 529,972.04 0.10 2.30 529,972.04 0.39 2.30 529,972.04 0.68 2.30 529,972.04 0.97 2.301 529,972.04 1.26 2.31 529,972.04 1.34 2.31 529,971.59 1.46 2.31 529,969.48 1.54 2.32 529,965.63 1.61 2.32 529,962.10 1.63 2.32 529,960.16 1.65 2.32 529,956.24 1.70 2.33 529,955.60 1.70 2.33 529,954.11 1.74 2.33 529,945.40 1.88 2.32 529,933.31 2.09 2.30 8/28/2013 1:50:26PM Page 3 COMPASS 2003.16 Build 69 • 0 Schlumbep9ep Company: , ConocoPhiIli ps(Alaska) Inc. Project: Kuparuk River Unit Site* Kuparuk 2E Pad Well: Plan: 2E-04 Wellbore: Plan: 2E-04PB1 Design: 2E-04PB1wp06 ... . _,: Schlumberger Plan summary �,,.. Local Co-ordinate Ref i TVD Reference: ,•, MID Reference ,; North Reference;' :True Survey Calculation Method: Datiabase. ConocoPhllllps Alaska Well Plan: 2E-04 Plan: 105.9+28 @ 133.90ft (Doyon 141) Plan: 105.9+28 @ 133.90ft (Doyon 141) ',Minimum Curvature EDM v16 Prod -- Planned Survey MD Inc Azi TVD TVDSS DLeg TFace Northing Easfiing Lat. Error Vert. Error (ft) V) (0) (ft) (ft) (°/100ft) V) O ) ? (ft) 1,216.97 16.78 210.00 1,209.90 1,076.00 4.00 0.00 5,944,150.47 529,930.93 2.09 2.30 K-15 Marker 1,300.00 20.10 210.00 1,288.66 1,154.76 4.00 0.00 5,944,127.67 529,917.89 2.37 2.28 1,400.00 24.10 210.00 1,381.29 1,247.39 4.00 0.00 5,944,095.02 529,899.21 2.73 2.25 1,500.00 28.10 210.00 1,471.07 1,337.17 4.00 0.00 5,944,056.84 529,877.37 3.16 2.23 1,519.14 28.87 210.00 1,487.90 1,354.00 4.00 0.00 5,944,048.92 529,872.83 3.16 2.23 base Permafrost 1,600.00 32.10 210.00 1,557.57 1,423.67 4.00 0.00 5,944,013.32 529,852.47 3.67 2.20 .�� 1,700.00 36.10 210.00 1,640.36 1,506.46 4.00 0.00 5,943,964.67 529,824.64 4.25 2.19 1,800.00 40.10 210.00 1,719.03 1,585.13 4.00 0.00 5,943,911.13 529,794.01 4.90 2.19 1,836.89 41.58 210.00 1,746.94 1,613.04 4.00 0.00 5,943,890.19 529,782.03 5.16 2.17 v-- Start 2163.11 hold at 1836.89 MD 1,900.00 41.58 210.00 1,794.15 1,660.25 0.00 0.00 5,943,853.84 529,761.24 5.60 2.22 2,000.00 41.58 210.00 1,868.96 1,735.06 0.00 0.00 5,943,796.24 529,728.29 6.31 2.33 2,100.00 41.58 210.00 1,943.76 1,809.86 0.00 0.00 5,943,738.64 529,695.34 7.04 2.46 2,195.10 41.58 210.00 2,014.90 1,881.00 0.00 0.00 5,943,683.87 529,664.00 7.04 2.46 Top Ugnu (Ugnu C) 2,200.00 41.58 210.00 2,018.57 1,884.67 0.00 0.00 5,943,681.04 529,662.39 7.77 2.60 2,300.00 41.58 210.00 2,093.37 1,959.47 0.00 0.00 5,943,623.44 529,629.44 8.51 2.74 2,400.00 41.58 210.00 2,168.18 2,034.28 0.00 0.00 5,943,565.85 529,596.49 9.25 2.89 2,500.00 41.58 210.00 2,242.98 2,109.08 0.00 0.00 5,943,508.25 529,563.54 9.99 3.05 2,600.00 41.58 210.00 2,317.79 2,183.89 0.00 0.00 5,943,450.65 529,530.59 10.74 3.21 2,700.00 41.58 210.00 2,392.59 2,258.69 0.00 0.00 5,943,393.05 529,497.64 11.48 3.38 2,800.00 41.58 210.00 2,467.40 2,333.50 0.00 0.00 5,943,335.45 529,464.69 12.23 3.55 2,900.00 41.58 210.00 2,542.21 2,408.31 0.00 0.00 5,943,277.85 529,431.74 12.98 3.72 3,000.00 41.58 210.00 2,617.01 2,483.11 0.00 0.00 5,943,220.25 529,398.79 13.73 3.90 3,100.00 41.58 210.00 2,691.82 2,557.92 0.00 0.00 5,943,162.66 529,365.84 14.49 4.071 8/28/2013 1:50:26PM Page 4 COMPASS 2003.16 Build 69 SchlumbePor Schlumberger Company: ConocoPhill ips(Alaska) Inc. Project: Kuparuk River Unit `✓ Site: Kuparuk 2E Pad Plan Well: Plan: 2E-04 Wellbore: Plan: 2E-04PB1 Design: 2E-04PB1wp06 Planned Survey MD Inc Azi Alaska 3,116.15 41.58 210.00 top W Sak (WSak D) 3,200.00 41.58 210.00 3,300.00 41.58 210.00 3,400.00 41.58 210.00 _ 3,500.00 41.58 210.00 6 3,598.74 41.58 210.00 .waw W Sak Al 3,600.00 41.58 210.00 -� 3,700.00 41.58 210.00 3,800.00 41.58 210.00 True 3,813.96 41.58 210.00 base W Sak Survey Calculation Method: 3,900.00 41.58 210.00 10-3/4" x 13-1/2" Database: 4,000.00 41.58 210.00 Start 1610.00 hold at 4000.00 MD TVD TVDSS 4,100.00 41.58 210.00 Northing 4,200.00 41.58 210.00 Vert. Error 4,300.00 41.58 210.00 pi 00ft) 4,400.00 41.58 210.00 (ft) 4,500.00 41.58 210.00 2,703.90 4,600.00 41.58 210.00 0.00 4,700.00 41.58 210.00 14.49 4,800.00 41.58 210.00 2,632.72 4,900.00 41.58 210.00 5,943,105.06 5,000.00 41.58 210.00 4.26 5,100.00 41.58 210.00 8/28/2013 1:50:26PM Page 5 COMPASS 2003.16 Build 69 0 s Schlumberger `✓ Plan Summary ConocoPhillips Alaska Local Co-ordinate Reference: Well Plan: 2E-04 TVD Reference: Plan: 105.9+28 @ 133.90ft (Doyon 141) MD Reference: Plan: 105.9+28 @ 133.90ft (Doyon 141) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM v16 Prod TVD TVDSS DLeg TFace Northing Easting Lat. Error Vert. Error (ft) (ft) pi 00ft) (I (ft) (ft) (ft) (ft) 2,703.90 2,570.00 0.00 0.00 5,943,153.35 529,360.52 14.49 4.07 2,766.62 2,632.72 0.00 0.00 5,943,105.06 529,332.89 15.24 4.26 2,841.43 2,707.53 0.00 0.00 5,943,047.46 529,299.94 15.99 4.44 2,916.23 2,782.33 0.00 0.00 5,942,989.86 529,266.99 16.75 4.62 2,991.04 2,857.14 0.00 0.00 5,942,932.26 529,234.04 17.50 4.81 3,064.90 2,931.00 0.00 0.00 5,942,875.39 529,201.51 17.50 4.81 3,065.84 2,931.94 0.00 0.00 5,942,874.66 529,201.09 18.26 4.99 3,140.65 3,006.75 0.00 0.00 5,942,817.07 529,168.14 19.01 5.18 3,215.46 3,081.56 0.00 0.00 5,942,759.47 529,135.19 19.77 5.37 3,225.90 3,092.00 0.00 0.00 5,942,751.42 529,130.59 19.77 5.37 3,290.26 3,156.36 0.00 0.00 5,942,701.87 529,102.25 20.52 5.56 3,365.07 3,231.17 0.00 0.00 5,942,644.27 529,069.30 21.01 5.62 3,439.87 3,305.97 0.00 0.00 5,942,586.67 529,036.35 21.26 5.63 3,514.68 3,380.78 0.00 0.00 5,942,529.07 529,003.40 21.53 5.66 3,589.48 3,455.58 0.00 0.00 5,942,471.47 528,970.45 21.83 5.69 3,664.29 3,530.39 0.00 0.00 5,942,413.88 528,937.50 22.14 5.72 3,739.09 3,605.19 0.00 0.00 5,942,356.28 528,904.55 22.48 5.77 3,813.90 3,680.00 0.00 0.00 5,942,298.68 528,871.60 22.84 5.82 3,888.71 3,754.81 0.00 0.00 5,942,241.08 528,838.65 23.21 5.88 3,963.51 3,829.61 0.00 0.00 5,942,183.48 528,805.70 23.61 5.94 4,038.32 3,904.42 0.00 0.00 5,942,125.88 528,772.75 24.02 6.01 4,113.12 3,979.22 0.00 0.00 5,942,068.29 528,739.80 24.45 6.09 4,187.93 4,054.03 0.00 0.00 5,942,010.69 528,706.85 24.90 6.17 8/28/2013 1:50:26PM Page 5 COMPASS 2003.16 Build 69 0 s Schlumbep9ep Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 2E Pad Well: Plan: 2E-04 Wellbore: ;, Plan: 2E-04PB1 Design: 2E-04PB1wp06 Schlumberger Flan summary Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: 'I" , ConocoPhllllps Alaska Well Plan: 2E-04 Plan: 105.9+28 @ 133.90ft (Doyon 141) Plan: 105.9+28 @ 133.90ft (Doyon 141) True Minimum Curvature EDM v16 Prod - Planned Survey MD Inc Azi TVD TVDSS DLeg TFace Northing Easting Lat.>sError Vert. Error (ft) (p) (,) " (ft) (ft) pi00ft) V) (ft) (ft) (ft) (ft) 5,200.00 41.58 210.00 4,262.73 4,128.83 0.00 0.00 5,941,953.09 528,673.90 25.36 6.26; 5,300.00 41.58 210.00 4,337.54 4,203.64 0.00 0.00 5,941,895.49 528,640.95 25.83 6.35 5,400.00 41.58 210.00 4,412.34 4,278.44 0.00 0.00 5,941,837.89 528,608.00 26.32 6.45 5,500.00 41.58 210.00 4,487.15 4,353.25 0.00 0.00 5,941,780.29 528,575.05 26.82 6.55 5,600.00 41.58 210.00 4,561.95 4,428.05 0.00 0.00 5,941,722.69 528,542.10 27.33 6.66 5,610.00 41.58 210.00 4,569.44 4,435.54 0.00 0.00 5,941,716.93 528,538.81 27.38 6.67 Start DLS 4.00 TFO -36.14 5,671.30 43.58 207.90 4,614.57 4,480.67 4.00 -36.14 5,941,680.56 528,518.89 27.69 6.73 Start 50.00 hold at 5671.30 MD •� 5,700.00 43.58 207.90 4,635.36 4,501.46 0.00 0.00 5,941,663.04 528,509.71 27.83 6.75 5,721.30 43.58 207.90 4,650.79 4,516.89 0.00 0.00 5,941,650.04 528,502.89 27.95 6.78 Start DLS 4.00 TFO -179.33 ° 5,800.00 40.43 207.84 4,709.27 4,575.37 4.00 -179.35 5,941,603.40 528,478.46 28.20 6.88 5,900.00 36.43 207.76 4,787.58 4,653.68 4.00 -179.30 5,941,548.32 528,449.69 28.31 7.00 6,000.00 32.43 207.66 4,870.05 4,736.15 4.00 -179.24 5,941,498.17 528,423.60 28.43 7.12 6,100.00 28.43 207.54 4,956.25 4,822.35 4.00 -179.16 5,941,453.21 528,400.31 28.55 7.23 6,200.00 24.43 207.38 5,045.78 4,911.88 4.00 -179.05 5,941,413.64 528,379.94 28.66 7.32 6,300.00 20.43 207.16 5,138.19 5,004.29 4.00 -178.91 5,941,379.66 528,362.59 28.76 7.40 6,400.00 16.44 206.84 5,233.04 5,099.14 4.00 -178.71 5,941,351.44 528,348.34 28.85 7.47 6,500.00 12.44 206.33 5,329.86 5,195.96 4.00 -178.41 5,941,329.12 528,337.26 28.92 7.53 6,600.00 8.44 205.33 5,428.19 5,294.29 4.00 -177.90 5,941,312.79 528,329.41 28.97 7.57 6,700.00 4.45 202.57 5,527.54 5,393.64 4.00 -176.93 5,941,302.55 528,324.82 28.91 7.60 6,788.16 1.01 181.85 5,615.58 5,481.68 4.00 -174.18 5,941,298.61 528,323.49 28.91 7.60 Start 919.08 hold at 6788.16 MD 6,788.24 1.01 181.77 5,615.66 5,481.76 4.00 -153.47 5,941,298.61 528,323.49 26.22 7.62 6,800.00 1.01 181.77 5,627.42 5,493.52 0.00 0.00 5,941,298.40 528,323.49 26.23 7.63 6,898.49 1.01 181.77 5,725.90 5,592.00 0.00 0.00 5,941,296.67 528,323.44 26.23 7.63 top HRZ (K-2 Marker) W8/2013 1:50:26PM Page 6 COMPASS 2003.16 Build 69 Kuparuk 131 base HRZ (upper Kalubik) Schlumberger 7,198.54 1.01 181.77 'I", SchlumbepUep 0.00 0.00 5,941,291.40 528,323.30 26.41 7.68 `�"�► lower Kalubik (K-1 Marker) 181.77 6,132.90 Flan summary 0.00 0.00 ConocoPhilli ps 528,323.25 26.55 7.71 s 7,200.00 1.01 181.77 Alaska Company: ConocoPhillips(Alaska) Inc. 0.00 0.00 5,941,291.37 Local Co-ordinate (deference: Well Plan: 2E-04 7.70 Project: Kuparuk River Unit, 7,288.55 1.01 181.77 6,115.90 TVD Reference:.Plan: 105.9+28 @ 133.90ft (Doyon 141) Site: Kuparuk 2E Pad 5,941,289.82 528,323.26 26.48 �Dt�nce Plan: 105.9+28 @ 133.90ft (Doyon 141) Well: PIan:2E-04 ' True Wellbore: Plan:2E-04P61 �f, �' . Ah ,.,;Minimum Curvature Design: 2E-04P61wp06 6,119.90 5,986.00 = 0.00 E DM v16 Prod 528,323.25 Planned Survey 7.70 „l -= �.. MD Inc Azi TVD TVDSS DLeg Trace Not",l #ink La t ,Error (ft) (°) (°) 181.77 (ft) (ft) (°l1ooft)) 0.00 0.00 (ft) (ft) 6,900.00 1.01 181.77 5,727.41 5,593.51 0.00 0.00 5,941,296.64 528,323.44 26.29 7.64 7,000.00 1.01 181.77 5,827.39 5,693.49 0.00 0.00 5,941,294.89 528,323.39 26.35 7.66 7,100.00 1.01 181.77 5,927.37 5,793.47 0.00 0.00 5,941,293.13 528,323.34 26.41 7.68 7,108.53 1.01 181.77 5,935.90 5,802.00 0.00 0.00 5,941,292.98 528,323.34 26.41 7.68 Kuparuk 131 base HRZ (upper Kalubik) �. 7,198.54 1.01 181.77 6,025.90 5,892.00 0.00 0.00 5,941,291.40 528,323.30 26.41 7.68 `�"�► lower Kalubik (K-1 Marker) 181.77 6,132.90 5,999.00 0.00 0.00 5,941,289.52 528,323.25 26.55 7.71 s 7,200.00 1.01 181.77 6,027.36 5,893.46 0.00 0.00 5,941,291.37 528,323.30 26.48 7.70 7,331.56 7,288.55 1.01 181.77 6,115.90 5,982.00 0.00 0.00 5,941,289.82 528,323.26 26.48 7.70 -; Kuparuk C Sand •.�® 7,292.55 1.01 181.77 6,119.90 5,986.00 0.00 0.00 5,941,289.74 528,323.25 26.48 7.70 „l -= Kuparuk B2 7,376.57 7,294.56 1.01 181.77 6,121.90 5,988.00 0.00 0.00 5,941,289.71 528,323.25 26.48 7.70 t Kuparuk 131 7,300.00 1.01 181.77 6,127.34 5,993.44 0.00 0.00 5,941,289.61 528,323.25 26.55 7.71 7,305.56 1.01 181.77 6,132.90 5,999.00 0.00 0.00 5,941,289.52 528,323.25 26.55 7.71 CORE POINT 7,331.56 1.01 181.77 6,158.90 6,025.00 0.00 0.00 5,941,289.06 528,323.24 26.55 7.71 Kuparuk A6 7,346.56 1.01 181.77 6,173.90 6,040.00 0.00 0.00 5,941,288.80 528,323.23 26.55 7.71 Kuparuk A5 7,376.57 1.01 181.77 6,203.90 6,070.00 0.00 0.00 5,941,288.27 528,323.21 26.55 7.71 Kuparuk A4 7,400.00 1.01 181.77 6,227.33 6,093.43 0.00 0.00 5,941,287.86 528,323.20 26.62 7.73 7,441.58 1.01 181.77 6,268.90 6,135.00 0.00 0.00 5,941,287.13 528,323.18 26.62 7.73 Miluveach 7,500.00 1.01 181.77 6,327.31 6,193.41 0.00 0.00 5,941,286.10 528,323.16 26.69 7.75 7,600.00 1.01 181.77 6,427.30 6,293.40 0.00 0.00 5,941,284.34 528,323.11 26.76 7.77 7,700.00 1.01 181.77 6,527.28 6,393.38 0.00 0.00 5,941,282.59 528,323.06 26.83 7.79 c; W8/2013 1:50:26PM Page 7 COMPASS 2003.16 Build 69 0 Schlumhepgep Schlumberger 'W, ConocoPhillips Plan Summary Alaska Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well Plan: 2E-04 Project: Kuparuk River Unit TVD Reference: Plan: 105.9+28 @ 133.90ft (Doyon 141) Site: Kuparuk 2E Pad MD Reference: Plan: 105.9+28 @ 133.90ft (Doyon 141) Well: Plan: 2E-04 North Reference: True Wellbore: Plan: 2E-04PB1 Survey Calculation Method: Minimum Curvature Design: d2E-04PB1wp06 Database: EDM v16 Prod MID Inc Azi TVD TVDSS DLeg TFace Northing Easting Lat. Error Vert. Error (ft) (°) (°) (ft) (ft) (°/100ft) (°) (ft) (ft) (ft) (ft) 7,707.23 1.01 181.77 6,534.51 6,400.61 0.00 0.00 5,941,282.46 528,323.06 26.84 7.79 2E-04PB1 TD revl mets Dip Angle Dip Dir. TVD +N/ -S +E/ -W (ft) (ft) (ft) 0.00 6,534.51 -2,933.59 -1,660.83 2E-04PB1 TD revl plan hits target center - Point Northing Easting (ft) (ft) Latitude Longitude 5,941,282.46 528,323.06 70° 15' 2.380 N 149'46'16.193W Casing Points Measured Vertical Casing Hate ' Depth Depth Diameter Diameter Name (..) i..);tNia, ER �, 3,900.00 3,290.26 10-3/4" x 13-1/2" 10-3/4 13-1/2 8/28/2013 1:50:26PM Page 8 COMPASS 2003.16 Build 69 �J Schlumberger Plan Summary Company: ConocoPhill ips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 2E Pad Well: Plan: 2E-04 Wellbore: Plan: 2E-04PB1 Design: 2E-04PB1wp06 Formations Well Plan: 2E-04 ND Reference: Measured Vertical Plan: 105.9+28 @ 133.90ft (Doyon 141) Depth Depth Survey Calculation Method: (ft) (ft) Name 977.47 975.90 T-3 Sand 7,441.58 6,268.90 Miluveach 1,519.14 1,487.90 base Permafrost 7,294.56 6,121.90 Kuparuk B1 3,813.96 3,225.90 base W Sak 7,346.56 6,173.90 Kuparuk A5 7,198.54 6,025.90 lower Kalubik (K-1 Marker) 7,108.53 5,935.90 base HRZ (upper Kalubik) 7,376.57 6,203.90 Kuparuk A4 6,898.49 5,725.90 top HRZ (K-2 Marker) 7,331.56 6,158.90 Kuparuk A6 1,216.97 1,209.90 K-15 Marker 3,116.15 2,703.90 top W Sak (WSak D) 2,195.10 2,014.90 Top Ugnu (Ugnu C) 7,305.56 6,132.90 CORE POINT 7,288.55 6,115.90 Kuparuk C Sand 3,598.74 3,064.90 W Sak Al 7,292.55 6,119.90 Kuparuk 132 ConocoPhillips Alaska Local Co-ordinate Reference: Well Plan: 2E-04 ND Reference: Plan: 105.9+28 @ 133.90ft (Doyon 141) MD Reference: Plan: 105.9+28 @ 133.90ft (Doyon 141) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM v16 Prod Dip Dip ' Direction Lithology (1) (°) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0 8/28/2013 1:50:26PM Page 9 COMPASS 2003.16 Build 69 Schlumberger SchlumbePoeP ConOcoPhillips Flan summary Alaska Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well Plan: 2E-04 Project: Kuparuk River Unit ;> TVD Reference: Plan: 105.9+28 @ 133.90ft (Doyon 141) Site: Kuparuk 2E Pad MD Reference: Plan: 105.9+28 @ 133.90ft (Doyon 141) Well: Plan: 2E-04 North Reference: True Wellbore: Plan: 2E-04PB1Survey Calculation Method: Minimum Curvature Design: 2E-04PB1wp06Database: EDM v16 Prod Plan Annotations ss ksk Measured Vertical Local Coordinates Depth Depth +N/ -S +Ei-W Zllls'- ss (ft) (ft) O (ft) Comment � 528.00 528.00 0.00 0.00 KOP: DLS 2 TFO 210 866.89 866.10 -17.34 -10.01 Start 100.00 hold at 866.89 MD 966.89 965.40 -27.56 -15.91 Start DLS 4.00 TFO 0.00 1,836.89 1,746.94 -331.43 -191.35 Start 2163.11 hold at 1836.89 MD 4,000.00 3,365.07 -1,574.62 -909.11 Start 1610.00 hold at 4000.00 MD 5,610.00 4,569.44 -2,499.93 -1,443.33 Start DLS 4.00 TFO -36.14 5,671.30 4,614.57 -2,536.22 -1,463.40 Start 50.00 hold at 5671.30 MD 5,721.30 4,650.79 -2,566.69 -1,479.52 Start DLS 4.00 TFO -179.33 6,788.16 5,615.58 -2,917.44 -1,660.33 Start 919.08 hold at 6788.16 MD 7,707.23 6,534.51 -2,933.59 -1,660.83 TD at 7707.23 Checked By: Approved By: Date: 8/28/2013 1:50:26PM Page 10 COMPASS 2003.16 Build 69 Schlumber9 er ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2E Pad Plan: 2E-04 Plan: 2E-04PB1 2E-04PB1wp06 Anticollision Report 27 August, 2013 ConocoPhillips 9Schlumber er Schlumhepgep Anticollision Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 2E Pad Site Error: 0.00ft Reference Well: Plan: 2E-04 Well Error: 0.00ft Reference Wellbore Plan: 2E-04PB1 Reference Design: , 2E-04PB1wp06 Cont Phillips Local Co-ordinate Reference:. Well Plan: 2E-04 TVD Reference: Plan: 105.9+28 @ 133.90ft (Doyon 141) MD Reference: Plan: 105.9+28 @ 133.90ft (Doyon 141) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: ' EDM v16 Prod Offset TVD Reference: Offset Datum Reference 2E-04PB1wp06 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 967.92ft Error Surface: Elliptical Conic Warning Levels Evaluated at: 2.00 Sigma Survey Tool Program Date 8/27/2013 From To Reference (ft) (ft) Survey (Wellbore) Tool Name Description 28.00 700.00 2E-04PB1wp06 (Plan: 2E-04PB1) GYD-GC-SS Gyrodata gyro single shots 700.00 3,900.00 2E-04PB1wp06 (Plan: 2E-04PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3,900.00 7,707.23 2E-04PB1wp06 (Plan: 2E-04PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Summary Reference Offset Distance Measured Measured Between Between Separation Warning Site Name Depth Depth Centres Ellipses Factor Offset Well - Wellbore - Design , , (ft) (ft) (ft) (ft) Kuparuk 2E Pad 2E-05 - 2E-05 - 2E-05 461.47 475.00 24.64 14.04 2.323 No Errors, CC 2E-05 - 2E-05 - 2E-05 535.973 550.00 25.64 13.16 2.054 No Errors, ES, SF'; 2E-06 - 2E-06 - 2E-06 561.41 575.00 47.33 37.54 4.835 CC 2E-06 - 2E-06 - 2E-06 610.69 625.00 47.81 37.27 4.536 ES, SF 2E-07 - 2E-07 - 2E-07 536.70 550.00 73.58 61.11 5.902 CC 2E-07 - 2E-07 - 2E-07 610.05 625.00 74.35 60.15 5.234 ES, SF 2E-08 - 2E-08 - 2E-08 536.64 550.00 98.14 85.68 7.877 CC 2E-08 - 2E-08 - 2E-08 609.47 625.00 98.73 84.53 6.955 ES, SF 2E-09 - 2E-09 - 2E-09 778.81 800.00 168.34 150.59 9.484 CC 2E-09 - 2E-09 - 2E-09 972.31 1,000.00 170.43 148.21 7.669 ES, SF 2E-10 - 2E-10 - 2E-10 133.90 142.00 199.98 197.65 85.797 CC 2E-10 - 2E-10 - 2E-10 611.80 625.00 201.16 187.26 14.474 ES, SF 2E-11 - 2E-11 - 2E-11 133.90 142.00 225.11 222.78 96.580 CC 2E-11 - 2E-11 - 2E-11 564.40 575.00 227.01 214.18 17.696 ES, SF 2E-12 - 2E-12 - 2E-12 133.90 142.00 250.00 247.67 107.260 CC 2E-12 - 2E-12 - 2E-12 587.40 600.00 251.81 238.39 18.772 ES, SF 2E-17 - 2E-17 - 2E-17 137.90 150.00 62.50 60.09 25.950 CC 2E-17 - 2E-17 - 2E-17 611.17 625.00 66.42 52.19 4.668 ES, SF Plan: 2E-03 - Plan: 2E-03-;2E-03wp05 s 751.35 750.00 24.36 12.50 2.054 No Errors; CC Plan: 2E-03 - Plan: 2E-03-,2E-03wp05 801.62r 800.00 24.53 12.07 1:969 No Errors, ES, SF Plan: 2E-04 - Plan: 2E-04 - 2E-04wp06 5,675.00 5,675.00 0.00: -0.95 0.005 No Errors, CC Plan: 2E-04 - Plan: 2E-04 -s 2E-04wp06 5,700.00; 5,700.00 0.29 -1.2T 0.192 No?Errors, ES„SF CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 81272013 4:23:12PM Page 2 of 30 COMPASS 2003.16 Build 69 r-1 Ab Wr Cono4hillips 2 E-04 P B 1 wp06 Schlumberger Alaska ANTI -COLLISION SETTINGS 16:27, August 272013 Interpolation Method: MD, interval: 25.00 Depth Range From: 28.00 To 7707.23 Results Limited By: Centre Distance: 967.92 GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 700.00 2E-04PB1wp06 (Plan: 2E-04PB1) GYD-GC-SS 700.00 3900.00 2E-04PB1wp06 (Plan: 2E-04PB1) MWD+IFR-AK-CAZ-SC 3900.00 7707.23 2E-04PB1wp06 (Plan: 2E-04PB1) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 3290.26 3900.00 10-3/4" x 13-1/2" 10-3/4 8 O Ob O O O. 3 300— I/H ME 11111V LU11V c O CO Q 47 U O L 2150 U o c m U 0 0 1000 2000 3000 4000 5000 6000 7000 Measured Depth LEGEND -� 2E-05, 2E-05, 2E-05 V2 2E -09,2E -09,2E -09V1 2E-17, 2E-17, 2E-17 Vi �- 2E-06, 2E-06, 2E-06 V1 -f3- 2E-10, 2E-10, 2E-10 V4 Plan: 2E-03, Plan: 2E-03, 2&03w05 VO -� 2E-07, 2E-07, 2E-07 V1 $- 2E-11, 2E-11, 2E-11 V1 - Plan: 2E-04, Plan: 2E-04, 2E-04wp06 VO - 2E-08, 2E-08, 2E-08 V1 — 2E -12,2E -12,2E -12V1 2E-04PB1wl)06 ConocoPhil li psI 2 E- 0 4 P B 1 w p 0 6 Schlumberger Alaska C 0 CASING DETAILS TVD MD Name Size 3290.26 3900.00 10-3/4" x 13-1/2" 10-3/4 N 8 0 500 1000 1500 2000 zouu avuu oow Measured Depth LEGEND �— 2E -05,2E -05,2E -05V2 —e— 2E-09, 2E-09, 2E-09 V1 2E-17, 2E-17, 2E-17 V1 �— 2E-06, 2E-06, 2E-06 V1 —3- 2E-10, 2E-10, 2E-10 V4 Plan: 2E-03, Plan: 2E-03, 2E-03wp05 VO —400.— 2E-07, 2E-07, 2E-07 V1 $ 2E-11, 2E-11, 2E-11 V1 Plan: 2E-04, Plan: 2E-04, 2E-04wp06 VO -->(— 2E-08, 2E-08, 2E-08 Vt — 2E -12,2E -12,2E -12V1 2E-04PB1wp06 ANTI -COLLISION SETTINGS 16:27, August 27 2013 Interpolation Method: MD, interval: 25.00 Depth Range From: 28.00 To 7707.23 Results Limited By: Centre Distance: 967.92 GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 700.00 2E-04PB1wp06 (Plan: 2E-04PB1) GYD-GC-SS 700.00 3900.00 2E-04PB1wp06 (Plan: 2E-04PB1) MWD+IFR-AK-CAZ-SC 3900.00 7707.23 2E-04PB1wp06 (Plan: 2E-04PB1) MWD+IFR-AK-CAZ-SC C 0 CASING DETAILS TVD MD Name Size 3290.26 3900.00 10-3/4" x 13-1/2" 10-3/4 N 8 0 500 1000 1500 2000 zouu avuu oow Measured Depth LEGEND �— 2E -05,2E -05,2E -05V2 —e— 2E-09, 2E-09, 2E-09 V1 2E-17, 2E-17, 2E-17 V1 �— 2E-06, 2E-06, 2E-06 V1 —3- 2E-10, 2E-10, 2E-10 V4 Plan: 2E-03, Plan: 2E-03, 2E-03wp05 VO —400.— 2E-07, 2E-07, 2E-07 V1 $ 2E-11, 2E-11, 2E-11 V1 Plan: 2E-04, Plan: 2E-04, 2E-04wp06 VO -->(— 2E-08, 2E-08, 2E-08 Vt — 2E -12,2E -12,2E -12V1 2E-04PB1wp06 -90/27 0/360 -180/180 �E aea v eo4ze IEI 11. 1111 VI $ zA a -e- 4Ex._:$ zev �o zE-o4w 2E-04PB1 wp06 From NWr- To MD 2 3 528.00 866.89 0.00 6.78 0.00 210.00 528.00 866 to ` .00 17.34 0.00 10.01 0.00 2.00 0.00 210.00 0.00 17.34 4 966.89 6.78 210.00 965.40 -27.56 -15.91 0.00 0.00 27.56 7707.23 - 5 1836.89 41.58 210.00 1746.99 331.43 10911 9.00 0.00 331.43 28.00 To 28 250 1650 1850 6 9000.00 41.58 210.00 3365.07 -1574.62 -909.11 0.00 0.00 1579.62 250 300 300 350 1850 - 2350 - 2350 2850 7 8 9 5610.00 5671.30 5721.30 41.58 43.58 43.58 210.00 207.90 207.90 4569.44 4614.57 4650.79 -2499.93 -2536.22 -2566.69 -1443.33 -1963.40 -1979.52 0.00 4.00 0.00 0.00 -36.14 0.00 2499.93 2536.22 2566.69 16:27. 14UCJU5[ 27 2013 1 678.16 1.01 181.32 -2917.49 -1660.24 4.00 9.33 170.00 2917.49 350 400 - 400 - 450 2850 - 3350 - 3350 3850 11 7707.23 1.01 181.32 6534.51 -293376 1660.62 0.00 2933.76 2E-04PB1 TD reel DBAL FILTER APPLIED: 450 - 550 3850 - - 4600 • ••�•••--•• 550 650 - ---- 650 "-"'---' 750 4600 5350 5350 6100 yy-•••• 'as oo VOW 2ND=.wp.0- 2E -6a pc -55 700003900.002-4PB IwpOfi 1%an: 2&010r®1 AB -CM -SC 900.007707.232EJ)4PBIwp061%aa: 2FaXor®kOR-AK-CAZ-SC 750 IiSQ 6100 6850 850 1050 - 1050 1250 6850 - 7850 '-----" 7850 8850 cnsr:c DErals TVD Name Slee N 3290.28100.00-3/4" x 13-12' 10-314125Q 1450 8850 9850 1450 1650 -90/27 0/360 -180/180 �E aea v eo4ze IEI 11. 1111 VI $ zA a -e- 4Ex._:$ zev �o zE-o4w 2E-04PB1wp06 FmmbHRWr-T°MD 3000.00 TO 7707.23 28 250 1650 - 1850 250 - 300 1850 - 2350 16:29, August 27 2013 300 - 350 2350 - 2850 350 - 400 2850 - 3350 400 - 450 3350 - 3850 OBAL FILTER APPLIED: 450 - 550 3850 4600 ��•••-•••••••••--•• 550'-- 650 4600 - 5350 1h 28F 00 70%M 2'EZVa roc Ing. zE aT GC- s 650 - 750 5350 - 6100 ]00003900.00 2EZBj qA6 (Ran: 2E-0M6®fffR-AK-CPZ-SC 3MO M 7707.232E414MB 06 (Ran: 2E 01.9®�ffft-AI(CAZ-SC 750 850 6100 6850 850 - 1050 6850 7850 cwsrvc Decals 1050 - 1250 7850 8850 TVO MD Name Size 3290.2®0060-3/4-3-- 103/4 1256 1450 8850 9850 1450 1650 [:D � r)t °' e Wales -90/ 1 28.00 0.00 0.00 28.00 1w 0.00 0.00 0.00 0.00 2 528.00 0.00 0.00 528.00 0 0.00 0.00 0.00 0.00 3 866.89 6.78 210.00 866. 10 -17.34 -10.01 2.00 210.00 17.34 4 966.89 6.78 210.00 965.40 -27.56 -15.91 0.00 0.00 27.56 5 1836.89 41.58 210.00 1746.94 -331.43 -191.35 4.00 0.00 331.43 6 4000.00 41.58 210.00 3365.07 -1574.62 -909.11 0.00 0.00 1574.62 7 5610.00 41.58 210.00 4569.44 -2499.93 -1443.33 0.00 0.00 2499.93 8 5671.30 43.58 207.90 4614.57 -2536.22 -1463.40 4.00 -36.14 2536.22 9 5721.30 43.58 207.90 4650.79 -2566.69 -1479.52 0.00 0.00 2566.69 10 6788.16 1.01 181.32 5615.58 -2917.49 -1660.24 4.00 -179.33 2917.49 11 7707.23 1.01 181.32 6534.51 -2933.76 -1660.62 0.00 0.00 2933.76 2E-04PB1 TD reel 0/360 -180/180 2E a zEa zE $ ,. EE E 0 zE E ne E a<o a ,E6.zE6E.,Ea Eaa.=E....V � E 6..E�a.MI.I. -� a.e �� 90 AC weds ONLY (NOT a Spider) 2E-09 2E-04PB1wP06 2E-03wP05 Easting (2000 ftlin) 2E-10 2E-06 Easting (2000 Min) 2E-11 2E-08 2E-17 2E-07 2E-05 • Z O Q N O O O • i[III I I I ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2E Pad Plan: 2E-04 Plan: 2E-04 Plan: 2E-04wp06 Plan Summary 28 August, 2013 0 is 040 all] F-12 \ ` 2F-14 2G-17L1-01_wp03 1 2F-11 AL 0 Easting (2500 ftlin) RU STATE 1 Easting (2500 ftlin) 2EFW B 1 12:31, August 28 2013 1L-11 2 -1 TR, f y 2F -18L1-01 1L-19 2F-19AL2 _ 0 2F-19AL3 Lo 2F -18L1-02 2F-19AL1 t 5' 0 2F -18L1 2F 19A Z 2G-17L1-01_wp03 1 2F-11 AL 0 Easting (2500 ftlin) RU STATE 1 Easting (2500 ftlin) 1L-13 1 L-24 2E-05 111 L -26A 1 8 • 0 1L-21 12:31, August 28 2013 1L-11 1L-12 f y 1 L-22 1L-19 1L-13 1 L-24 2E-05 111 L -26A 1 8 • 0 1 2E-04wp06 Plan View -� 0 X000 2000 300 0 10-3/4" x 13-1/2 11000 -2000 000 5000 6000 X000 CD 0 -4000 800CD 0 7-5/8" X 9-7/8" + 9000 Z -6000 10000 110000 U) -8000 12000 13000 -10000 14000 2E-04wp06 4-1/2" x 6-1/2" j L14739 -10000 -8000 -6000 -4000 -2000 0 2000 4000 6000 West( -)/East(+) (2000 ft/in) 1 2E-04wp06 Section View -1500- 0- -00 0° 1000 3P°op0 1500 2 � � T �O�O 0-3000— 3000 10-3/4" x 13-1/2" �p �O m > �o 4500— 500 00 � �0000 °p o 0 C)0 0 0 00 O O O o rn O M CO 6) o C) r" O O oM row O yO oM�y� I.�\..4� T T 6000 W !� T W W T W � /� ty o to c- 7-5/8" X 9-7/8" o 4-1/2" x 6-1/2' o w N 7500- -1500 0 1500 3000 4500 6000 7500 9000 10500 12000 Vertical Section at 180.000 (1500 ft/in) Project Kuparuk River Unit Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 2E Pad Site Position: Northing: 5,944,247.48 ft Latitude: 70° 15'31.481 N From: Map Easting: 529,971.75 ft Longitude: 149° 45'27.897 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.23 ° Well Plan: 2E-04 Well Position +N/ -S 0.00 ft Northing: 5,944,222.34 ft Latitude: 70° 15'31.234 N +E/ -W 0.00 ft Easting: 529,972.04 ft Longitude: 149'45'27.891 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 105.90ft Schlumberger .= Schlumher er Plan Summary ConocoPhIllips Alaska Company: Conoco Phi Ili ps(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 2E Pad Local Co-ordinate Reference: TVD Reference: MD Reference: Well Plan: 2E-04 Plan: 105.9+28 @ 133.90ft (Doyon 141) Plan: 105.9+28 @ 133.90ft (Doyon 141) Well: Plan: 2E-04 North Reference: True Wellbore: Plan: 2E-04 Survey Calculation Method: Minimum Curvature Design: 2E-04wp06 Database: EDM v16 Prod Project Kuparuk River Unit Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 2E Pad Site Position: Northing: 5,944,247.48 ft Latitude: 70° 15'31.481 N From: Map Easting: 529,971.75 ft Longitude: 149° 45'27.897 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.23 ° Well Plan: 2E-04 Well Position +N/ -S 0.00 ft Northing: 5,944,222.34 ft Latitude: 70° 15'31.234 N +E/ -W 0.00 ft Easting: 529,972.04 ft Longitude: 149'45'27.891 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 105.90ft 8/282013 1:54:03PM Page 2 COMPASS 2003.16 Build 69 • Wellbore Plan: 2E-04 Magnetics Model Name Sample Date Declination Dip Angle Field Strength .� BGGM2012 8/27/2013 15.47 79.88 57,350 Design 2E-04wp06 Audit Notes: Version: Phase: PLAN Tie On Depth: 5,671.29 Vertical Section: Depth From (TVD) +N/ -S +E! W Direction (ft) (ft) 28.00 0.00 0.00 180.00 8/282013 1:54:03PM Page 2 COMPASS 2003.16 Build 69 • Schlumber Date 5,941,662.85 528,509.90 From To er 4,501.38 Schlumberger ConocoPhillips Tool Name Description 28.00 700.00 2E-04PB1wp06 (Plan: 2E-04PB1) GYD-GC-SS Gyrodata gyro single shots 700.00 3,900.00 2E-04PB1wp06 (Plan: 2E-04PB1) Plan Summary MWD+IFR AK CAZ SCC 3,900.00 5,671.29 2E-04PB1wp06 (Plan: 2E-04PB1) Alaska Company: Conoco Phi Ili ps(Alaska) Inc. Local Co-ordinate Reference: Well Plan: 2E-04 Project: Kuparuk River Unit TVD Reference: Plan: 105.9+28 @ 133.90ft (Doyon 141) Site: Kuparuk 2E Pad MD Reference: Plan: 105.9+28 @ 133.90ft (Doyon 141) Well, Plan: 2E-04 North Reference: True Wellbore: Plan: 2E-04 Survey Calculation Method: Minimum Curvature Design: 2E-04wp06 Database: EDM v16 Prod Survey Tool Program Date 5,941,662.85 528,509.90 From To 4,635.28 4,501.38 (ft) 'i (ft) Survey (Wellbore) Tool Name Description 28.00 700.00 2E-04PB1wp06 (Plan: 2E-04PB1) GYD-GC-SS Gyrodata gyro single shots 700.00 3,900.00 2E-04PB1wp06 (Plan: 2E-04PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3,900.00 5,671.29 2E-04PB1wp06 (Plan: 2E-04PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5,671.29 8,568.30 2E-04wp06 (Plan: 2E-04) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,568.30 14,738.90 2E-04wp06 (Plan: 2E-04) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi TVD TVDSS DLeg TFace Northing' Easting Lat. Error Vert. Error (ft) (°) (°) (ft) (ft) pi00ft) (I , (ft) (ft) (ft) (ft) 5671.29 43.58 207.90 4,614.57 4,480.67 3.44 -36.14 5,941,680.57 528,518.90 27.69 6.73 KOP: DLS 4.00 TFO -65.00 -65.00 5,941,662.85 528,509.90 5,700.00 44.07 206.40 4,635.28 4,501.38 5,721.30 44.45 205.31 4,650.53 4,516.63 Start 50.00 hold at 5721.30 MD 0.00 5,941,617.73 528,488.62 5,771.30 44.45 205.31 4,686.22 4,552.32 Start DLS 5.00 TFO -23.25 528,480.13 28.02 6.72 5,800.00 45.78 204.52 4,706.48 4,572.58 5,882.38 49.60 202.44 4,761.93 4,628.03 Start 1726.56 hold at 5882.38 MD 528,451.06 28.27 6.71 5,900.00 49.60 202.44 4,773.35 4,639.45 6,000.00 49.60 202.44 4,838.17 4,704.27 6,100.00 49.60 202.44 4,902.98 4,769.08 6,200.00 49.60 202.44 4,967.80 4,833.90 6,300.00 49.60 202.44 5,032.62 4,898.72 6,400.00 49.60 202.44 5,097.44 4,963.54 6,500.00 49.60 202.44 5,162.25 5,028.35 6,600.00 49.60 202.44 5,227.07 5,093.17 6,700.00 49.60 202.44 5,291.89 5,157.99 6,800.00 49.60 202.44 5,356.71 5,222.81 4.00 -65.00 5,941,662.85 528,509.90 27.77 6.72 4.00 -63.92 5,941,649.44 528,503.47 27.81 6.72 0.00 0.00 5,941,617.73 528,488.62 27.96 6.72 5.00 -23.25 5,941,599.26 528,480.13 28.02 6.72 5.00 -22.69 5,941,543.30 528,456.13 28.02 6.72 0.00 52.55 5,941,530.88 528,451.06 28.27 6.71 0.00 0.00 5,941,460.38 528,422.28 28.63 6.75 0.00 0.00 5,941,389.89 528,393.50 29.01 6.78 0.00 0.00 5,941,319.40 528,364.72 29.42 6.83 0.00 0.00 5,941,248.90 528,335.94 29.84 6.89 0.00 0.00 5,941,178.41 528,307.17 30.28 6.95 0.00 0.00 5,941,107.92 528,278.39 30.73 7.02 0.00 0.00 5,941,037.42 528,249.61 31.20 7.10 0.00 0.00 5,940,966.93 528,220.83 31.69 7.19. 0.00 0.00 5,940,896.44 528,192.05 32.19 7.29 8/28/2013 1:54:03PM Page 3 COMPASS 2003.16 Build 69 is Schlumhepgep Schlumberger 'I" , ConocoPhlllips Plan Summary Alaska Company: ConocoPhiIli ps(Alaska) Inc. Local Co-ordinate Reference: Well Plan: 2E-04 Project: Kuparuk River Unit TVD References Plan: 105.9+28 @ 133.90ft (Doyon 141) Site: Kuparuk 2E Pad MI) Reference: Plan: 105.9+28 @ 133.90ft (Doyon 141) Well: Plan: 2E-04 North Reference: True Wellbore: Plan: 2E-04 Survey Calculation Method:'' Minimum Curvature Design: 2E-04wp06 Database: EDM v16 Prod Planned Survey MD Inc Azi TVD TVDSS DLeg TFace Northing Easting Lat. Error Vert. Error (ft) (°) (°) (ft) (ft) (°/100ft) (°) (ft) (ft) (ft) (ft) 6,900.00 49.60 202.44 5,421.53 5,287.63 0.00 0.00 5,940,825.94 528,163.27 32.71 7.39 7,000.00 49.60 202.44 5,486.34 5,352.44 0.00 0.00 5,940,755.45 528,134.50 33.24 7.49 7,100.00 49.60 202.44 5,551.16 5,417.26 0.00 0.00 5,940,684.96 528,105.72 33.78 7.61 7,200.00 49.60 202.44 5,615.98 5,482.08 0.00 0.00 5,940,614.46 528,076.94 34.34 7.73 i 7,300.00 49.60 202.44 5,680.80 5,546.90 0.00 0.00 5,940,543.97 528,048.16 34.91 7.85 7,380.38 49.60 202.44 5,732.90 5,599.00 0.00 0.00 5,940,487.30 528,025.03 34.91 7.85 top HRZ (K-2 Marker) 7,400.00 49.60 202.44 5,745.62 5,611.72 0.00 0.00 5,940,473.48 528,019.38 35.49 7.98 7,500.00 49.60 202.44 5,810.43 5,676.53 0.00 0.00 5,940,402.98 527,990.60 36.07 8.12 7,600.00 49.60 202.44 5,875.25 5,741.35 0.00 0.00 5,940,332.49 527,961.83 36.67 8.26 7,608.94 49.60 202.44 5,881.05 5,747.15 0.00 0.00 5,940,326.19 527,959.25 36.73 8.27 Start DLS 5.00 TFO 0.11 7,700.00 54.15 202.45 5,937.25 5,803.35 5.00 0.11 5,940,259.90 527,932.18 37.30 8.40 7,709.70 54.63 202.45 5,942.90 5,809.00 5.00 0.10 5,940,252.60 527,929.20 37.30 8.40 base HRZ (upper Kalubik) 7,800.00 59.15 202.46 5,992.21 5,858.31 5.00 0.10 5,940,182.60 527,900.60 37.97 8.55 7,875.79 62.94 202.46 6,028.90 5,895.00 5.00 0.10 5,940,121.23 527,875.52 37.97 8.55 lower Kalubik (K-1 Marker) 7,900.00 64.15 202.47 6,039.69 5,905.79 5.00 0.10 5,940,101.17 527,867.32 38.69 8.71 8,000.00 69.15 202.48 6,079.31 5,945.41 5.00 0.09 5,940,016.23 527,832.58 39.44 8.89 8,082.58 73.28 202.48 6,105.90 5,972.00 5.00 0.09 5,939,943.89 527,802.98 39.44 8.89 Kuparuk C Sand 8,096.78 73.99 I 202.48 6,109.90 5,976.00 5.00 0.09 5,939,931.29 527,797.83 39.44 8.89 Kuparuk 132 8,100.00 74.15 202.48 6,110.79 5,976.89 5.00 0.09 5,939,928.42 527,796.65 40.23 9.09 8,104.11 74.35 202.48 6,111.90 5,978.00 5.00 0.09 5,939,924.76 527,795.16 40.23 9.09 Kuparuk 61 8,200.00 79.15 202.49 6,133.87 5,999.97 5.00 0.09 5,939,838.41 527,759.81 41.04 9.30 8/28/2013 1:54:03PM Page 4 COMPASS 2003.16 Build 69 Schlumbep9ep Schlumberger ,.-- Plan Summary ConocoPhilll,p s Alaska pang Con ocoPhill ips(Alaska) Inc.°' 1 ate Referee: Well Plan: 2E-04 Kuparuk River Unit p�,� Plan: 105.9+28 @ 133.90ft (Doyon 141) �� Kuparuk 2E Pad �� �"�� ��� .� �„ � s �� � Plan: 105.9+28 @ 133.90ft (Doyon 141) �UPlan: 2E-04 � ��.._ � � �, ,..� .,...,. . te�ce:True Wfttidke: Plan: 2E-04 SukyDaiculation Method: Minimum Curvature Design: 2E-04wp06 Database: EDM v16 Prod V TVD TVDSS DLeg TFace Northing Easting Lat. Error Vert. Error (ft) (ft) (°I100ft) (°) (ft) (ft) (ft) (ft) 8,286.2083.46 202.50 6,146.90 6,013.00 5.00 0.09 5,939,759.59 527,727.54 41.04 9.30 Kuparuk A6 8,300.00 84.15 202.50 6,148.39 6,014.49 5.00 0.09 5,939,746.89 527,722.34 41.87 9.53 8,317.03 85.00 202.50 6,150.00 6,016.10 5.00 0.09 5,939,731.20 527,715.91 42.02 9.56 Start 251.27 hold at 8317.03 MD 8,400.00 85.00 202.50 6,157.23 6,023.33 0.00 0.00 5,939,654.72 527,684.59 42.72 9.76 8,465.04 85.00 202.50 6,162.90 6,029.00 0.00 0.00 5,939,594.77 527,660.04 42.72 9.76 Kuparuk A5 8,500.00 85.00 202.50 6,165.95 6,032.05 0.00 0.00 5,939,562.54 527,646.84 43.58 10.00 8,522.41 85.00 202.50 6,167.90 6,034.00 0.00 0.00 5,939,541.89 527,638.38 43.58 10.00 Fault 1 8,568.30 85.00 202.50 6,171.90 6,038.00 0.00 0.00 5,939,499.59 527,621.05 43.58 10.00 Start DLS 5.00 TFO -33.63 - 7-5/8" X 9-7/8" 8,600.00 86.33 201.64 6,174.30 6,040.40 5.00 -32.93 5,939,470.25 527,609.29 44.14 10.01 8,700.00 90.53 198.93 6,177.03 6,043.13 5.00 -32.87 5,939,376.39 527,575.03 44.43 10.02 8,723.35 91.51 198.29 6,176.62 6,042.72 5.00 -32.79 5,939,354.24 527,567.67 44.49 10.03 8,724.86 91.51 198.29 6,176.58 6,042.68 0.00 0.00 5,939,352.79 527,567.20 44.49 10.03 Start 168.92 hold at 8724.86 MD 8,800.00 91.51 198.29 6,174.59 6,040.69 0.00 0.00 5,939,281.39 527,543.92 44.89 10.05 8,891.30 91.51 198.29 6,172.18 6,038.28 0.00 0.00 5,939,194.64 527,515.62 45.36 10.08 8,893.78 91.49 198.17 6,172.11 6,038.21 5.00 -101.99 5,939,192.27 527,514.85 45.36 10.08 Start DLS 5.00 TFO -102.43 8,900.00 91.42 197.87 6,171.95 6,038.05 5.00 -101.99 5,939,186.36 527,512.95 45.36 10.09 8,989.50 90.49 193.49 6,170.46 6,036.56 5.00 -102.00 5,939,100.13 527,489.12 45.22 10.13 8,989.68 90.49 193.49 6,170.46 6,036.56 0.00 0.00 5,939,099.95 527,489.08 45.22 10.13 Start 650.00 hold at 8989.68 MD 9,000.00 90.49 193.49 6,170.37 6,036.47 0.00 0.00 5,939,089.91 527,486.71 45.27 10.14 9,100.00 90.49 193.49 6,169.51 6,035.61 0.00 0.00 5,938,992.59 527,463.77 45.81 10.21 8/28/2013 1:54:03PM Page 5 COMPASS 2003.16 Build 69 IS schlumhopgop 6,031.27 9,700.00 Schlumberger Plan Summary 191.59 9,800.00 'w,', ConocoPhilllps 188.45 9,822.89 85.95 187.72 9,823.24 85.95 187.72 Start 147.50 hold at 9823.24 MD 6,170.60 9,900.00 85.95 187.72 9,970.72 85.95 187.72 9,970.74 85.95 187.72 Start DLS 4.00 TFO 51.84 5,938,287.05 Alaska Cor Con' Phillips(Alaska) Inc. 188.65 10,017.95 87.12 t } al Co-ordinate Reference: Well Plan: 2E-04 5,938,211.14 so Project ' Kuparuk River Unit' 10,018.14 87.12 189.21 Start DLS 4.00 TFO (ifQ#eCeCi: Plan: 105.9+28 @ 133.90ft (Doyon 141) Site Kuparuk 2E PadIgen 86.50 188.61 10,040.56 86.50 Plan: 105.9+28 @ 133.90ft (Doyon 141) Well . Plan: 2E-04.,�..til2eference: 0.00 10,100.00 86.50 188.61 11.25 True 6,049.03 _5� Wellbore: Plan: 2E-04 51.74 5,938,112.27 527,283.73 50.04 Surrey Calculationehod:+ Minimum Curvature Design: 2E-04wp06 4.00 51.68 5,938,094.56 Database: EDM v16 Prod 6,183.91 Planned Survey 0.00 0.00 5,938,094.37 527,280.99 50.27 11.33 6,185.10 6,051.20 4.04 -135.89 5,938,073.23 527,277.77 50.24 11.36 MD Inc Azi 6,051.26 ND Fel 5,938,072.25 Northir►g ,.itttgLat: 50.24 Error Vert. Error (ft) (°) (°) 6,054.89 (ft) t°I 5,938,013.55 ,; (ft } t (ft) (ft) 9,200.00 90.49 193.49 6,168.66 6,034.76 0.00 0.00 5,938,895.27 527,440.84 46.38 10.28 9,300.00 90.49 193.49 6,167.80 6,033.90 0.00 0.00 5,938,797.95 527,417.90 46.95 10.37 9,400.00 90.49 193.49 6,166.95 6,033.05 0.00 0.00 5,938,700.63 527,394.96 47.55 10.47 9,500.00 90.49 193.49 6,166.09 6,032.19 0.00 0.00 5,938,603.31 527,372.02 48.16 10.58 9,600.00 90.49 193.49 6,165.24 6,031.34 0.00 0.00 5,938,505.99 527,349.09 48.79 10.71 9,639.50 90.49 193.49 6,164.90 6,031.00 0.00 0.00 5,938,467.55 527,340.03 49.04 10.76 2E-04 (wp02) CPI 9,639.68 90.49 193.49 6,164.90 6,031.00 0.00 0.00 5,938,467.37 527,339.98 49.04 10.76 Start DLS 4.00 TFO -128.27 6,031.27 9,700.00 88.99 191.59 9,800.00 86.51 188.45 9,822.89 85.95 187.72 9,823.24 85.95 187.72 Start 147.50 hold at 9823.24 MD 6,170.60 9,900.00 85.95 187.72 9,970.72 85.95 187.72 9,970.74 85.95 187.72 Start DLS 4.00 TFO 51.84 5,938,287.05 10,000.00 86.67 188.65 10,017.95 87.12 189.21 2E-04 (wp02) CP2 5,938,211.14 527,296.98 10,018.14 87.12 189.21 Start DLS 4.00 TFO -133.96 0.00 10,039.57 86.50 188.61 10,040.56 86.50 188.61 Start 81.10 hold at 10040.56 MD 0.00 10,100.00 86.50 188.61 6,165.17 6,031.27 4.01 -128.30 5,938,408.46 527,327.13 49.03 10.84 6,169.10 6,035.20 4.00 -128.29 5,938,310.02 527,310.14 48.82 10.98 6,170.60 6,036.70 4.00 -128.17 5,938,287.40 527,307.02 48.76 11.02 6,170.63 6,036.73 0.00 0.00 5,938,287.05 527,306.97 48.76 11.02 6,176.05 6,042.15 0.00 0.00 5,938,211.14 527,296.98 49.19 11.14 6,181.05 6,047.15 0.00 0.00 5,938,141.21 527,287.78 49.64 11.25 6,181.05 6,047.15 0.00 0.00 5,938,141.19 527,287.78 49.64 11.25 6,182.93 6,049.03 4.00 51.74 5,938,112.27 527,283.73 50.04 11.30 6,183.90 6,050.00 4.00 51.68 5,938,094.56 527,281.02 50.27 11.33 6,183.91 6,050.01 0.00 0.00 5,938,094.37 527,280.99 50.27 11.33 6,185.10 6,051.20 4.04 -135.89 5,938,073.23 527,277.77 50.24 11.36 6,185.16 6,051.26 0.00 0.00 5,938,072.25 527,277.62 50.24 11.36 6,188.79 6,054.89 0.00 0.00 5,938,013.55 527,268.98 50.58 11.47 8/28/2013 1:54:03PM Page 6 COMPASS 2003.16 Build 69 • • Schlumher er Company: ConocoPhiIli ps(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 2E Pad Well: Plan: 2E-04 Wellbore: Plan: 2E-04 Design: 2E-04wp06 86.58 2E-04 (wp02) CP3 Schlumberger Plan Summary Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: SurveyCalculation Method:' Database: �✓ ConocoPhillips Alaska Well Plan: 2E-04 Plan: 105.9+28 @ 133.90ft (Doyon 141) Plan: 105.9+28 @ 133.90ft (Doyon 141) True Minimum Curvature EDM v16 Prod ! Planned Survey 11,200.00 88.45 11,300.00 90.92 11,338.08 91.86 11,339.12 91.86 Start 63.18 hold at 11339.12 MD 11,400.00 MD Inc Azi 6,118.93 TVD TVDSS DLeg TFace Northing Easting Lat. Error Vert. Error 6,252.79 6,118.89 (ft) (0) (1) 0.00 (ft)` (ft) (°/100ft) V) " (ft) (ft) (ft) (ft) 0.00 0.00 5,936,727.52 10,121.66 86.50 188.61 6,190.12 6,056.22 0.00 0.00 5,937,992.17 527,265.83 50.58 11.47 Start DLS 4.00 TFO 29.58 10,121.78 86.50 188.61 6,190.12 6,056.22 0.00 0.00 5,937,992.04 527,265.81 50.73 11.51 10,123.80 86.58 188.61 6,190.25 6,056.35 4.00 2.14 5,937,990.05 527,265.52 50.74 11.51 10,124.02 86.58 188.61 6,190.26 6,056.36 0.00 0.00 5,937,989.83 527,265.48 50.74 11.51 Start 1000.00 hold at 10124.02 MD 10,200.00 86.58 188.61 6,194.79 6,060.89 0.00 0.00 5,937,914.81 527,254.43 51.25 11.65 10,300.00 86.58 188.61 6,200.76 6,066.86 0.00 0.00 5,937,816.06 527,239.88 51.92 11.83 10,400.00 86.58 188.61 6,206.72 6,072.82 0.00 0.00 5,937,717.32 527,225.33 52.61 12.03 10,500.00 86.58 188.61 6,212.69 6,078.79 0.00 0.00 5,937,618.57 527,210.78 53.32 12.23 10,600.00 86.58 188.61 6,218.65 6,084.75 0.00 0.00 5,937,519.83 527,196.23 54.03 12.44 -, 10,700.00 86.58 188.61 6,224.62 6,090.72 0.00 0.00 5,937,421.08 527,181.68 54.75 12.66 10,800.00 86.58 188.61 6,230.58 6,096.68 0.00 0.00 5,937,322.34 527,167.13 55.49 12.88 10,900.00 86.58 188.61 6,236.55 6,102.65 0.00 0.00 5,937,223.59 527,152.58 56.24 13.11 11,000.00 86.58 188.61 6,242.51 6,108.61 0.00 0.00 5,937,124.84 527,138.03 56.99 13.34 11,100.00 86.58 188.61 6,248.48 6,114.58 0.00 0.00 5,937,026.10 527,123.48 57.76 13.58 , 10 11,107.04 86.58 188.61 6,248.90 6,115.00 0.00 0.00 5,937,019.15 527,122.46 57.76 13.58 Fault 2 11,123.80 86.58 2E-04 (wp02) CP3 4.01 11,124.02 86.58 Start DLS 4.00 TFO -52.16 11,200.00 88.45 11,300.00 90.92 11,338.08 91.86 11,339.12 91.86 Start 63.18 hold at 11339.12 MD 11,400.00 91.86 188.61 6,249.90 6,116.00 0.00 0.00 5,937,002.59 527,120.02 57.94 13.64 188.61 6,249.91 6,116.01 0.00 0.00 5,937,002.37 527,119.98 57.94 13.64 186.20 6,253.20 6,119.30 4.01 -52.10 5,936,927.08 527,110.51 57.92 13.82 183.05 6,253.75 6,119.85 4.00 -52.00 5,936,827.41 527,102.84 57.72 14.07 181.85 6,252.83 6,118.93 4.00 -51.98 5,936,789.37 527,101.36 57.61 14.17 181.85 6,252.79 6,118.89 0.00 0.00 5,936,788.33 527,101.33 57.61 14.17 181.85 6,250.82 6,116.92 0.00 0.00 5,936,727.52 527,099.60 58.08 14.33 8128/2013 1:54:03PM Page 7 COMPASS 2003.16 Build 69 El I• 8/28/2013 1:54:03PM Page 8 COMPASS 2003.16 Build 69 Schlumberger sehlumbopgop Plan Summary ConocoPhillips Abska C044-,- C onocoPhillips(Alaska) Inc. erence: Well Plan: 2E -04 Prol ' , uparuk River Unit t4,: Plan: 105.9+28 @ 133.90ft (Doyon 141) Sit?, Kuparuk 2E Pad Plan: 105.9+28 @ 133-90ft (Doyon 141) Well: Plan: 2E-04 True Wellbore: Plan: 2E-04 Minimum Curvature Design: 2E-04wp06 ,L EDM v16 Prod - - - , ............ ------ -- - 4 Planned Survey - ------- - --- --- MD Inc Azi ,i TVD TVDSS DLeg (ft) (ft) (ft) 0100ft) 11,402.30 91.86 181.85 6,250.75 6,116.85 0.00 0.00 5,936,725.22 527,099.54 58.08 14.3: Start DILS 4.00 TFO 127.93 11,402.86 91.86 181.85 6,250.73 6,116.83 0.00 0.00 5,936,724.66 527,099.52 58.11 14.3: 11,475.22 90.07 184.13 6,249.51 6,115.61 4.00 128.09 5,936,652.41 527,096.04 59.24 14.5: 11,475.47 90.07 184.13 6,249.51 6,115.61 0.00 0.00 5,936,652.16 527,096.02 59.24 14.5: Start 500.00 hold at 11475.47 MD 11,500.00 90.07 184.13 6,249.48 6,115.58 0.00 0.00 5,936,627.69 527,094.35 59.38 14.51 11,600.00 90.07 184.13 6,249.36 6,115.46 0.00 0.00 5,936,527.93 527,087.55 60.18 14.8: 11,700.00 90.07 184.13 6,249.24 6,115.34 0.00 0.00 5,936,428.17 527,080.74 60.99 15.1 11,800.00 90.07 184.13 6,249.11 6,115.21 0.00 0.00 5,936,328.41 527,073.94 61.80 15.3� 11,900.00 90.07 184.13 6,248.99 6,115.09 0.00 0.00 5,936,228.65 527,067.13 62.62 15.61 11,975.22 90.07 184.13 6,248.90 6,115.00 0.00 0.00 5,936,153.62 527,062.01 63.25 15.8 2E-04 (wp02) CP4 11,975.47 90.07 184.13 6,248.90 6,115.00 0.00 0.00 5,936,153.37 527,062.00 63.25 15.8 Start DILS 4.00 TFO -124.54 12,000.00 89.51 183.31 6,248.99 6,115.09 4.04 -124.57 5,936,128.89 527,060.50 63.15 15.9 12,062.66 88.09 181.25 6,250.31 6,116.41 4.00 -124.57 5,936,066.29 527,058.26 62.74 16.1 12,062.98 88.09 181.25 6,250.32 6,116.42 0.00 0.00 5,936,065.97 527,058.25 62.74 16.1 Start 406.93 hold at 12062.98 MD 12,100.00 88.09 181.25 6,251.55 6,117.65 0.00 0.00 5,936,028.98 527,057.60 62.97 16.2 12,200.00 88.09 181.25 6,254.89 6,120.99 0.00 0.00 5,935,929.06 527,055.81 63.81 16.5 12,300.00 88.09 181.25 6,258.23 6,124.33 0.00 0.00 5,935,829.14 527,054.03 64.65 16.7 12,400.00 88.09 181.25 6,261.57 6,127.67 0.00 0.00 5,935,729.23 527,052.25 65.49 17.0 12,469.65 88.09 181.25 6,263.90 6,130.00 0.00 0.00 5,935,659.63 527,051.01 66.09 17.2 2E-04 (wp02) CP5 12,469.91 88.09 181.26 6,263.91 6,130.01 4.00 53.21 5,935,659.37 527,051.01 66.09 17.2 Start DILS 4.00 TFO 53.23 12,489.96 88.57 181.90 6,264.49 6,130.59 4.00 53.21 5,935,639.34 527,050.54 66.46 17.3 El I• 8/28/2013 1:54:03PM Page 8 COMPASS 2003.16 Build 69 schlumbepgop Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 2E Pad Well: Plan: 2E-04 Wellbore: Plan: 2E-04 Design: 2E-04wp06 � PI ned S rve an u y 0.00 13,000.00 89.05 181.83 6 MD Inc 90.55 Azi TVD` a (ft) (°) Start 768.43 hold at (°) (ft) (ft) 12,490.23 88.57 181.90 6,264.50 6,130.60 Start 498.11 hold at 12490.23 MD 181.62 6 13,400.00 90.55 12,500.00 88.57 181.90 6,264.74 6,130.84 12,600.00 88.57 181.90 6,267.23 6,133.33 12,700.00 88.57 181.90 6,269.72 6,135.82 12,707.06 88.57 181.90 6,269.90 6,136.00 Fault 3 73.47 19.78 1273.80 6,139.90 12,800.00 88.57 181.90 6,272.22 6,138.32 12,900.00 88.57 181.90 6,274.71 6,140.81 12,988.07 88.57 181.90 6,276.90 6,143.00 2E-04 (wp02) CP6 0.00 0.00 5,934,529.99 527,021.02 12,988.35 88.58 181.90 6,276.91 6,143.01 Start DLS 4.00 TFO -8.04 0.00 13,000.00 89.05 181.83 6 13,038.00 90.55 181.62 6 13,038.28 90.55 181.62 6 Start 768.43 hold at 13038.28 MD 0.00 13,100.00 90.55 181.62 6 13,200.00 90.55 181.62 6 13,300.00 90.55 181.62 6 13,400.00 90.55 181.62 6 13,500.00 90.55 181.62 6 13,600.00 90.55 181.62 13,700.00 90.55 181.62 13,800.00 90.55 181.62 13, 806.41 90.55 181.62 2E-04 (wn02) CP7 0.00 0.00 0.00 0.00 5,935,639.07 527,050.53 66.46 17.34 0.00 0.00 5,935,629.31 527,050.24 66.54 17.37 0.00 0.00 5,935,529.39 527,047.33 67.40 17.66 0.00 0.00 5,935,429.47 527,044.41 68.27 17.96 0.00 0.00 5,935,422.42 527,044.21 68.27 17.96 0.00 0.00 5,935,329.56 527,041.50 69.14 18.26 0.00 0.00 5,935,229.64 527,038.58 70.01 18.56 0.00 0.00 5,935,141.65 527,036.01 70.01 18.56 4.00 -8.04 5,935,141.37 527,036.00 70.79 18.82 1277.15 6,271.88 6,270.92 6,269.96 6,269.90 6,143.25 4.00 -8.04 5,935,129.72 527,035.67 70.87 18.86 ,277.28 6,143.38 4.00 -8.04 5,935,091.74 527,034.68 71.14 18.98 1277.28 6,143.38 0.00 0.00 5,935,091.46 527,034.67 71.14 18.98 ,276.69 6,142.79 0.00 0.00 5,935,029.77 527,033.17 71.69 19.16 ,275.73 6,141.83 0.00 0.00 5,934,929.81 527,030.74 72.58 19.47 ,274.77 6,140.87 0.00 0.00 5,934,829.86 527,028.31 73.47 19.78 1273.80 6,139.90 0.00 0.00 5,934,729.90 527,025.88 74.37 20.09 ,272.84 6,138.94 0.00 0.00 5,934,629.94 527,023.45 75.27 20.40 6,137.98 0.00 0.00 5,934,529.99 527,021.02 76.18 20.71 6,137.02 0.00 0.00 5,934,430.03 527,018.60 77.09 21.03 6,136.06 0.00 0.00 5,934,330.08 527,016.17 78.01 21.34 6,136.00 0.00 0.00 5,934,323.67 527,016.01 78.06 21.36 8/28/2013 1:54:03PM Page 9 COMPASS 2003.16 Build 69 Wellbore: Plan: 2E-04 89.23 180.57 6,277.37 6,143.47 0.00 Survey Calculation Method: Minimum Curvature Design: 2E-04wp06 Schlumberger i►' , Schlumhugep 89.23 180.57 Database: 6,144.80 EDM v16 Prod 0.00 Planned Survey 527,011.45 Plan Summary ConocoPhllllps 14,600.00 89.23 Alaska Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well Plan: 2E-04 Project: Kuparuk River Unit TVD Reference: Plan: 105.9+28 @ 133.90ft (Doyon 141) Site: Kuparuk 2E Pad MDReference: Plan: 105.9+28 @ 133.90ft (Doyon 141) Well: Plan: 2E-04 North Reference: True Wellbore: Plan: 2E-04 89.23 180.57 6,277.37 6,143.47 0.00 Survey Calculation Method: Minimum Curvature Design: 2E-04wp06 82.91 23.27 14,500.00 89.23 180.57 Database: 6,144.80 EDM v16 Prod 0.00 Planned Survey 527,011.45 83.84 23.59 14,600.00 89.23 180.57 6,280.04 6,146.14 0.00 MD Inc 5,933,530.25 Azi TVD TVDSS DLeg TFace Northing Easting Let. Error Vert. (ft) (I 0.00 (°) (ft) (ft) (°/100ft) V) (ft) (ft) (ft) (1 13,806.71 90.54 181.61 6,269.90 6,136.00 4.00 -141.53 5,934,323.37 527,016.00 78.06 Start DLS 4.00 TFO -141.54 13,848.49 89.23 180.57 6,269.98 6,136.08 4.00 -141.53 5,934,281.61 527,015.37 77.96 13,848.78 89.23 180.57 6,269.98 6,136.08 0.00 0.00 5,934,281.31 527,015.37 77.96 Start 890.12 hold at 13848.78 MD 13,900.00 89.23 180.57 6,270.67 6,136.77 0.00 0.00 5,934,230.10 527,015.06 78.27 14,000.00 89.23 180.57 6,272.01 6,138.11 0.00 0.00 5,934,130.12 527,014.46 79.19 14,100.00 89.23 180.57 6,273.35 6,139.45 0.00 0.00 5,934,030.14 527,013.86 80.12 14,200.00 89.23 180.57 6,274.69 6,140.79 0.00 0.00 5,933,930.16 527,013.25 81.04 14,300.00 89.23 180.57 6,276.03 6,142.13 0.00 0.00 5,933,830.18 527,012.65 81.97 21.36 �* 21.50 21.50 21.66 21.98 22.30 22.62 22.94 14,400.00 89.23 180.57 6,277.37 6,143.47 0.00 0.00 5,933,730.20 527,012.05 82.91 23.27 14,500.00 89.23 180.57 6,278.70 6,144.80 0.00 0.00 5,933,630.22 527,011.45 83.84 23.59 14,600.00 89.23 180.57 6,280.04 6,146.14 0.00 0.00 5,933,530.25 527,010.84 84.78 23.91 14,700.00 89.23 180.57 6,281.38 6,147.48 0.00 0.00 5,933,430.27 527,010.24 85.72 24.24 14,738.58 89.23 180.57 6,281.90 6,148.00 0.00 0.00 5,933,391.70 527,010.01 86.09 24.37 2E-04 (wp02) Toe 8/28/2013 1:54:03PM Page 10 COMPASS 2003.16 Build 69 is SchlumbePor 0.00 Schlumberger 6,276.90 ✓ COt'1000PhiII1p5 -2,972.44 - plan hits target center 149° 46'46.837 W Plan summary 527,051.01 70° 14'7.121 N 149° 46'53.779 W - Point 527,120.02 70° 14'20.327 N 149° 46'51.633 W Alaska Company: ConocoPhillips(Alaska) Inc. 0.00 i ttlitt f8t Well Plan: 2E-04 Project: ; Kuparuk River Unit plan hits target center „, .... :. plan: 105.9+28 @ 133.90ft (Doyon 141) Site: Kuparuk 2E Pad Point , , +#tt;,. Plan: 105.9+28 @ 133.90ft (Doyon 141) Well: Plan: 2E-04 2E-04 (wp02) CP5 0.00 0.00 True Wellbore: Plan: 2E-04 �.itC ; tt fit!` Minimum Curvature Design: 2E-04wp06 " ' '' } EDM v16 Prod Targets Target Name hit/miss target Dip Angle Dip Dir. - Shape (1) (°) TND' (ft)' 2E-04 (wp02) CP6 0.00 0.00 6,276.90 -9,069.83 -2,972.44 - plan hits target center 149° 46'46.837 W 5,935,659.63 527,051.01 70° 14'7.121 N 149° 46'53.779 W - Point 527,120.02 70° 14'20.327 N 149° 46'51.633 W 5,936,153.62 527,062.01 2E-04 (wp02) CP2 0.00 0.00 6,183.90 -6,117.63 -2,715.65 plan hits target center 527,010.01 70° 13'44.815 N 149° 46'55.206 W 5,939,269.52 527,529.03 Point 149° 46'39.502 W 5,938,467.55 527,340.03 70° 14'34.729 N 149° 46'45.083 W 2E-04 (wp02) CP5 0.00 0.00 6,263.90 -8,551.86 -2,955.37 - plan hits target center - Point 2E-04 (wp02) CP3 0.00 0.00 6,249.90 -7,209.05 -2,881.02 - plan hits target center - Point 2E-04 (wp02) CP4 0.00 0.00 6,248.90 -8,057.87 -2,942.40 - plan hits target center - Point 2E-04 (wp02) CP7 0.00 0.00 6,269.90 -9,887.81 -2,995.70 plan hits target center Point 2E-04 (wp02) Toe 0.00 0.00 6,281.90 -10,819.84 -3,005.41 - plan hits target center - Point 2E-04 (wp02) Heel 0.00 0.00 6,171.90 -4,943.54 -2,462.94 plan misses target center by 10.71ft at 8815.97ft MD (6174.17 TVD, -4946.89 N, -2453.02 E) - Point 2E-04 (wp02) CP1 0.00 0.00 6,164.90 -5,744.84 -2,655.16 plan hits target center - Point 5,935,141.65 527,036.01 70'14'2.026N 149° 46' 54.269 W 5,938,094.56 527,281.02 70° 14'31.062 N 149° 46'46.837 W 5,935,659.63 527,051.01 70° 14'7.121 N 149° 46'53.779 W 5,937,002.59 527,120.02 70° 14'20.327 N 149° 46'51.633 W 5,936,153.62 527,062.01 70° 14' 11.979 N 149° 46' 53.407 W 5,934,323.67 527,016.01 70° 13'53.981 N 149° 46'54.935 W 5,933,391.70 527,010.01 70° 13'44.815 N 149° 46'55.206 W 5,939,269.52 527,529.03 70° 14'42.610 N 149° 46'39.502 W 5,938,467.55 527,340.03 70° 14'34.729 N 149° 46'45.083 W 8/28/2013 1:54.03PM Page 11 COMPASS 2003.16 Build 69 • • 1 Schtuberer u �J pany: Conoco Phi Ili ps(Alaska) Inc. Kuparuk River Unit Kuparuk 2E Pad Well`.'Plan: 2E-04 Wellbore: Plan: 2E-04 Design: 2E-04wp06 Casing Points Measured Vertical " Casing Hole Depth Depth; = Diameter Diameter (ft) (ft)�. 3,900.00 3,290.26 10-3/4" x 13-1/2' 10-3/4 13-1/2 8,568.30 6,171.90 7-5/8" X 9-7/8" 7-5/8 9-7/8 14,738.90 6,281.90 4-1/2" x 6-1/2" 4-1/2 6-1/2 FormatYott Measured VpTtl l Depth3." a 1 #Lett (ft) Name Lithology 7,875.79 6,028.90 lower Kalubik (K-1 Marker) 8,465.04 6,162.90 Kuparuk A5 8,096.78 6,109.90 Kuparuk B2 11,107.04 6,248.90 Fault 2 8,104.11 6,111.90 Kuparuk 131 7,380.38 5,732.90 top HRZ (K-2 Marker) 8,082.58 6,105.90 Kuparuk C Sand 12,707.06 6,269.90 Fault 3 8,522.41 6,167.90 Fault 1 8,286.20 6,146.90 Kuparuk A6 7,709.70 5,942.90 base HRZ (upper Kalubik) 8/282013 1:54:03PM Page 12 COMPASS 2003.16 Build 69 is Schlumbep9ep Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 2E Pad Well: Plan: 2E-04 Wellbore: Plan: 2E-04 Design: 2E-04wp06 Plan Annotations Measured Vertical Local Coordinates:_ . y Depth Depth +N/ -S +E/ -W :.,., (ft) (ft) (ft) (ft) Comment 5,671.29 4,614.57 -2,536.22 -1,463.39 KOP: DLS 4.00 TFO -65.00 5,721.30 4,650.53 -2,567.29 -1,478.95 Start 50.00 hold at 5721.30 MD 5,771.30 4,686.22 -2,598.94 -1,493.92 Start DLS 5.00 TFO -23.25 5,882.38 4,761.93 -2,673.25 -1,526.71 Start 1726.56 hold at 5882.38 MD 7,608.94 5,881.05 -3,888.50 -2,028.48 Start DLS 5.00 TFO 0.11 8,317.03 6,150.00 -4,482.57 -2,274.21 Start 251.27 hold at 8317.03 MD 8,568.30 6,171.90 -4,713.83 -2,370.00 Start DLS 5.00 TFO -33.63 8,724.86 6,176.58 -4,860.42 -2,424.44 Start 168.92 hold at 8724.86 MD 8,893.78 6,172.11 -5,020.75 -2,477.44 Start DLS 5.00 TFO -102.43 8,989.68 6,170.46 -5,112.97 -2,503.58 Start 650.00 hold at 8989.68 MD 9,639.68 6,164.90 -5,745.01 -2,655.20 Start DLS 4.00 TFO -128.27 9,823.24 6,170.63 -5,925.22 -2,688.93 Start 147.50 hold at 9823.24 MD 9,970.74 6,181.05 -6,071.02 -2,708.71 Start DLS 4.00 TFO 51.84 10,018.14 6,183.91 -6,117.81 -2,715.68 Start DLS 4.00 TFO -133.96 10,040.56 6,185.16 -6,139.93 -2,719.14 Start 81.10 hold at 10040.56 MD 10,121.66 6,190.12 -6,219.97 -2,731.26 Start DLS 4.00 TFO 29.58 10,124.02 6,190.26 -6,222.30 -2,731.61 Start 1000.00 hold at 10124.02 MD 11,124.02 6,249.91 -7,209.27 -2,881.05 Start DLS 4.00 TFO -52.16 11,339.12 6,252.79 -7,423.26 -2,900.56 Start 63.18 hold at 11339.12 MD 11,402.30 6,250.75 -7,486.37 -2,902.60 Start DLS 4.00 TFO 127.93 11,475.47 6,249.51 -7,559.42 -2,906.41 Start 500.00 hold at 11475.47 MD 11,975.47 6,248.90 -8,058.12 -2,942.42 Start DLS 4.00 TFO -124.54 12,062.98 6,250.32 -8,145.52 -2,946.51 Start 406.93 hold at 12062.98 MD 12,469.91 6,263.91 -8,552.12 -2,955.38 Start DLS 4.00 TFO 53.23 12,490.23 6,264.50 -8,572.43 -2,955.94 Start 498.11 hold at 12490.23 MD 12,988.35 6,276.91 -9,070.11 -2,972.45 Start DLS 4.00 TFO -8.04 13,038.28 6,277.28 -9,120.02 -2,973.98 Start 768.43 hold at 13038.28 MD 13,806.71 6,269.90 -9,888.11 -2,995.70 Start DLS 4.00 TFO -141.54 13,848.78 6,269.98 -9,930.17 -2,996.50 Start 890.12 hold at 13848.78 MD 14,738.90 TD at 14738.90 El 812812013 1:54:03PM Page 13 COMPASS 2003.16 Build 69 i Schlumberger Schlumberger Plan Summary ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc.k Local Co-ordinate Reference: Well Plan: 2E-04 Project: Kuparuk River Unit TVD Reference: Plan: 105.9+28 @ 133.90ft (Doyon 141) Site: Kuparuk 2E Pad MD Reference: Plan: 105.9+28 @ 133.90ft (Doyon 141) Well: Plan: 2E-04 North Reference: True Wellbore: Plan: 2E-04 Survey Calculation Method: Minimum Curvature Design: 2E 04wp06 Database: EDM v16 Prod Checked By: Approved By: Date: 8/28/2013 1:54:03PM Page 14 COMPASS 2003.16 Build 69 • • • �1 6 1711 � 1 1 • ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2E Pad Plan: 2E-04 Anticollision Report 28 August, 2013 ConocoPhillips 0 SchlumbepUep Schlumberger Anticollision Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 2E Pad Site Error: 0.00ft Reference Well: Plan: 2E-04 Well Error: 0.00ft Reference Wellbore Plan: 2E-04 Reference Design: 2E-04wp06 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: ConocOP 11ll1P5 Well Plan: 2E-04 Plan: 105.9+28 @ 133.90ft (Doyon 141) Plan: 105.9+28 @ 133.90ft (Doyon 141) True Minimum Curvature 1.00 sigma EDM v16 Prod Offset Datum Reference 2E-04wp06 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of referE Interpolation Method: MD Interval 25.O0ft Error Model: ISCWSA Depth Range: 5,671.29 to 14,738.90ft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,671.09ft Error Surface: Elliptical Conic Warning Levels Evaluated at: 2.00 Sigma Survey Tool Program From (ft) 28.00 700.00 3,900.00 5,671.29 8,568.30 Summary Date 8/28/2013 To (ft) Survey (Wellbore) 700.00 2E-04PB1wp06 (Plan: 2E-04PB1) 3,900.00 2E-04PB1wp06 (Plan: 2E-04PB1) 5,671.29 2E-04PB1wp06 (Plan: 2E-04PB1) 8,568.30 2E-04wp06 (Plan: 2E-04) 14,738.90 2E-04wp06 (Plan: 2E-04) Site Name Offset Well - Wellbore - Design Kuparuk 2E Pad 2E-06 - 2E-06 - 2E-06 2E-07 - 2E-07 - 2E-07 2E-09 - 2E-09 - 2E-09 2E-17 - 2E-17 - 2E-17 Plan: 2E-03 - Plan: 2E-03 - 2E-03wp05 Plan: 2E-04 - Plan: 2E-04PB1 - 2E-04PB1wp06 Plan: 2E-04 - Plan: 2E-04PB1 - 2E-04PB1wp06 Tool Name GYD-GC-SS MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC M W D+I FR-AK-CAZ-SC M W D+I FR-AK-CAZ-SC Description Gyrodata gyro single shots MWD+IFR AK CAZ SCC MWD+IFR AK CAZ SCC MWD+IFR AK CAZ SCC MWD+IFR AK CAZ SCC Reference Offset Distance Measured Measured Between Between Separation Warning Depth Depth Centres Ellipses Factor (ft) (ft) (ft) (ft) 5,728.98 5,950.00 1,620.81 1,494.71 5,675.00 5,675.00 0.00 -0.93 5,700.00 5,700.00 0.29 -1.19 Out of range Out of range Out of range Out of range 12.853 CC, ES, SF 0.005 No Errors, CC 0.195 No Errors, ES, SF1 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 812812013 11:01:03AM Page 2 of 6 COMPASS 2003.16 Build 69 /c lumbergY� Conoco`Phillips 2 E-04wp06 Alaska LEGEND 2E -05,2E -05,2E -05V2 2E-09, 2E-09, 2E-09 V1 - 2E-17, 2E-17, 2E-17 V1 2E-06, 2E-06, 2E-06 V1 $- 2E-10, 2E-10, 2E-10 V4 Plan: 2E-03, Plan: 2E-03, 2E-03wp05 VO -� 2E-07, 2E-07, 2E-07 V1 -E3- 2E-11, 2E-11, 2E-11 V1 Plan: 2E-04, Plan: 2E-04PB1, 2E-04PB1wp06 VO 2E-08, 2E-08, 2E-08 V1 —I— 2E-12, 2E-12, 2E-12 Vt - 2E-04wp06 ANTI -COLLISION SETTINGS 11:09, August 28 2013 CASING DETAILS Interpolation Method: MD, interval: 25.00 Depth Range From: 5671.29 To 14738.90 MD Name Results Limited By: Centre Distance: 1671.09 GLOBAL FILTER APPLIED.* All wellpaths within 200'+ 100/1000 of reference 3290.26 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 700.00 2E-04PB1wp06 (Plan: 2E-04PB1) GYD-GC-SS 700.00 3900.00 2E-04PB1wp06 (Plan: 2E-04PB1) MWD+IFR-AK-CAZ-SC 3900.00 5671.29 2E-04PB1wp06 (Plan: 2E-04PB1) MWD+IFR-AK-CAZ-SC 5671.29 8568.30 2E-04wp06 (Plan: 2E-04) MWD+IFR-AK-CAZ-SC 8568.30 14738.90 2E-04wp06 (Plan: 2E-04) MWD+IFR-AK-CAZ-SC LEGEND 2E -05,2E -05,2E -05V2 2E-09, 2E-09, 2E-09 V1 - 2E-17, 2E-17, 2E-17 V1 2E-06, 2E-06, 2E-06 V1 $- 2E-10, 2E-10, 2E-10 V4 Plan: 2E-03, Plan: 2E-03, 2E-03wp05 VO -� 2E-07, 2E-07, 2E-07 V1 -E3- 2E-11, 2E-11, 2E-11 V1 Plan: 2E-04, Plan: 2E-04PB1, 2E-04PB1wp06 VO 2E-08, 2E-08, 2E-08 V1 —I— 2E-12, 2E-12, 2E-12 Vt - 2E-04wp06 CASING DETAILS TVD MD Name Size 3290.26 3900.00 10-3/4" x 13-1/2" 10-3/4 6171.90 8568.30 7-5/8" X 9-7/8" 7-5/8 6281.90 14738.90 4-1/2" x 6-1/2" 4-1/2 0 a 3 m a 0 w 300 c 0 is a m 150- 0 O c U 0 0 1500 3000 4500 6000 7500 Measured Depth LEGEND 2E -05,2E -05,2E -05V2 2E-09, 2E-09, 2E-09 V1 - 2E-17, 2E-17, 2E-17 V1 2E-06, 2E-06, 2E-06 V1 $- 2E-10, 2E-10, 2E-10 V4 Plan: 2E-03, Plan: 2E-03, 2E-03wp05 VO -� 2E-07, 2E-07, 2E-07 V1 -E3- 2E-11, 2E-11, 2E-11 V1 Plan: 2E-04, Plan: 2E-04PB1, 2E-04PB1wp06 VO 2E-08, 2E-08, 2E-08 V1 —I— 2E-12, 2E-12, 2E-12 Vt - 2E-04wp06 1 57 9 43.58 207.90 4614 -1463.39 0.00 2536.22 From MW To MD 2 5721.3.53 -1478.95 4.00 -65.00 2567.29 2E-04wp06 3 5771.30 44.45 205.31 4686.22 -2598.90 44.45 205.31 46504 -1493.92 0.00 0.00 2598.94 4 5882.38 49.60 202.44 4761.93 -2673.25 -1526.71 5.00 -23.25 2673.25 5671.29 To 14738• 0 5650 7050 - 7250 5 7608.94 49.60 202.44 5881.05 -3888.50 -2028.48 0.00 0.00 3888.50 6 8317.03 85.00 202.50 6150.00 -4482.57 -2274.21 5.00 0.11 4482.57 5650 5700 7250 - 7750 7 8568.30 85.00 202.50 6171.90 -4713.83 -2370.00 0.00 0.00 4713.83 8 8724.86 91.53 198.17 6176.65 -4860.45 -2424.33 5.00 -33.63 4860.45 5700 5750 7750 - 8250 9 8893.78 91.53 198.17 6172.15 -5020.89 -2477.00 0.00 0.00 5020.89 11:10, August 28 2013 02.43 5113.11 5750 - 5800 8250 - 8750 11 8989.68 90.49 193.49 6170.46 -5113.11 -2503.15 5.00 10 9639.68 90.49 193.49 6164.90 -5745.16 2654.77 0.00 0.00 5745.16 2E-04 (wP02) CPl 5800 5850 8750 9250 12 9823.24 85.95 187.72 6170.61 -5925.36 -2688.52 4.00 -128.27 5925.36 13 9970.74 85.95 187.72 6181.03 -6071.16 -2708.28 0.00 0.00 6071.16 MAL FILTER APPLIED: 5850 5950 9250 - --' 10000 14 10018.14 87.12 189.21 6183.90 -6117.96 -271524 4.00 51.84 6117.96 2E-04(wP02)CP2 15 10040.56 86.50 188.56 6185.15 -6140.07 -2718.70 4.00 -133.96 6140.07 -••--------•--•• 5950 6050 10000 10750 16 10121.66 86.50 188.56 6190.10 -6220.12 -2730.75 0.00 0.00 6220.12 i FmnDeplh To man Tool 17 10124.02 86.58 188.61 6190.25 -6222.46 -2731.10 C. 29.58 6222.46 ze o0 0001 ZE 4 sl.Fu6 (.- zE-as FC -Es 6050 6150 10750 11500 18 11124.02 86.58 188.61 6249.90 -7209.43 -2880.55 0.00 0.00 7209.43 2E-04 (wp02) CP3 ro0.00a900.00 2E 4M (eim�: ze-tl11V®i1''E-ac-cnz-Ec 19 11339.12 91.87 181.82 6252.81 -7423.41 -2900.07 4.00 -52.16 7423.41 9n1.o15671.29 2Et lw, 61:: zF.aar®'IffR-ac-MK 6150 - 6250 11500 12250 20 11402.30 91.87 181.82 6250.75 -7486.52 -2902.08 0.00 0.00 7486.52 1.298568312E-04wp061F1- 1-) NIwO.IFR-AI(-CAZSC Sfie.4]38.902E-04vp061F�mi: 2EA4) xlwo.lx-uc-cnzsc 6250 - 6450 12250 13250 21 11475.47 90.07 184.13 6249.51 -7559.57 -2905.88 4.00 127.93 7559.57 22 11975.47 90.07 184.13 6248.90 -8058.27 -2941.89 0.00 0.00 8058.27 2E-04 (.P02) CP4 cwsrvc oernls 6450 - 6650 13250 '-"`"" 14250 23 12062.98 88.09 181.25 6250.31 -8145.67 -2945.99 4.00 -124.54 8145.67 aw Mo Nmee see 24 12469.91 88.09 181.25 6263.90 -8552.28 -2954.83 0.00 0.00 8552.28 2E-04 (wP02) CP5 az91.z®10.ao-m+•aa.lrz l0-ap 6650 6850 14250 - 15250 25 12490.23 88.57 181.90 6264.49 -8572.58 -2955.39 4.00 53.23 8572.58 _119868317-WX9-79" 7 -LB 26 12988.35 88.57 181.90 6276.90 -9070.27 -2971.87 0.00 0.00 9070.27 2E-04 (wp02) CP6 6281®38.904-t/r-M- 4-1/2 6850 7050 27 13038.28 90.55 181.62 6277.28 -9120.17 -2973.40 4.00 -8.04 9120.17 28 13806.71 90.55 181.62 6269.90 -9888.26 -2995.08 0.00 0.00 9888.26 2E-04 (wP02) CP7 29 13848.78 89.23 180.57 6269.98 -9930.33 -2995.88 4.00 -141.54 9930.33 30 14738.90 89.23 180.57 6281.90 -10820.32 -3004.74 0.00 0.00 10820.32 2E-04 (wp02) Toe El -90/270 0/360 E-04PB1W 180/180 90 e ,E -yE:Ea,� Pw Mo4 .Pa�ze ae0 , 'o" o,+ [AC weirsONLY (NOT a Spider) Eastinq (2500 ft/in) Easting (2500 ttnn) 2E-05 • z 0 5' e N CT O O 2' 0 I -2500 o -5000 LON 0 -7500 0 -10000 -12500 -1000U - /Z)UU -0000 --,000 U CUUU JUUU /JUU IUUUU West( -)/East(+) (2500 Win) WELLBORE TARGET DETAILS (MAP CO-ORDINATES) 2 E -O ■ W pO6 Name 2E-04 (v pO2) CP1 2E-04 Heel TVDSS 6031.00 6038.00 +N/ -S -5745.16 -4943.83 +E/ -W -2654.77 -2462.60 Northing 5938218.00 5939020.00 Easti ng 1667372.00 1667561.00 Shape Point Point 14:16, August 28 2013 Quarter Mile View (wp02) 2E-04 (wp02) Heel Circle 2E-04 (pO2) CP2 2E-04 (wp02) CP4 6038.00 6050.00 6115.00 -0943. 63 -6117.96 -8058.27 -2462.60 -2715.24 -2941.89 5939020.00 5937845.00 5935904.001667094.00 1667561.00 1667313.00 Circle (Rad us: 1320.00) Point P Point 2E-04 (Wp02) CP5 6130.00 ,8552.28 -2954.83 5935410.00 1667063.00 Point 2E-04 (Wp02) CP7 6136.00 -9888.26 -2995.08 5934074.00 1667048.00 Point 2E-04 (wp02) CP6 6143.00 -9070.27 -2971.87 5934892.00 1667068.00 Point 2E-04 (wp02) Toe 6148.00 -10820.32 -3004.74 5933142.00 1667042.00 Point 2E-04 (wo02) Toe Circle 6148.00 -10820.32 -3004.74 5933142.00 1667042.00 Circle (Radius: 1320.00) I -2500 o -5000 LON 0 -7500 0 -10000 -12500 -1000U - /Z)UU -0000 --,000 U CUUU JUUU /JUU IUUUU West( -)/East(+) (2500 Win) Plan: 2E-04 2E-04wp06 Schlumberger 0 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 2E Pad Site Error: 0.00ft Reference Well: Plan: 2E-04 Well Error: 0.00ft Reference Wellbore Plan: 2E-04 Reference Design: 2E-04wp06 • Schlumberger Anticollision Report Local Co-ordinate Reference: Well Plan: 2E-04 ConocoPhillips TVD Reference: Plan: 105.9+28 @ 133.90ft (Doyon 141) MD Reference: Plan: 105.9+28 @ 133.90ft (Doyon 141) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: EDM v16 Prod Offset TVD Reference: Offset Datum Reference 2E-04wp06 Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 25.O0ft Error Model: ISCWSA Depth Range: 8,568.30 to 14,738.90ft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 100,000.00f Error Surface: Elliptical Conic Warning Levels Evaluated at: 2.00 Sigma rvey Tool Program Date 8/28/2013 From To (ft) (ft) Survey (Wellbore) 28.00 700.00 2E-04PB1wp06 (Plan: 2E-04PB1) 700.00 3,900.00 2E-04PB1wp06 (Plan: 2E-04PB1) 3,900.00 5,671.29 2E-04PB1wp06 (Plan: 2E-04PB1) 5,671.29 8,568.30 2E-04wp06 (Plan: 2E-04) 8,568.30 14,738.90 2E-04wp06 (Plan: 2E-04) Tool Name Description GYD-GC-SS Gyrodata gyro single shots MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Summary Reference Offset Distance Measured Measured Between Between Separation Warning Site Name° Depth Depth Centres Ellipses Factor " Offset Well -Wellbore -Design (ftl (ft) (ftl (ft) Kuparuk 2E Pad 2E-06 - 2E-06 - 2E-06 9,112.08 8,850.00 4,107.62 3,898.67 19.658 CC, ES, SF \ctual 3D distance in pool" = 4399.38' CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 8/28/2013 2:24:56PM Page 2 of 5 COMPASS 2003.16 Build 69 Schlumbergerer 0 Schlumhepgep Anticollision Report COt1000Pi1iffipS �p�-0 GOnOCOPnlillpS (AIaSKa)'ine. -Kup'z "FI&Ieran„' , ;uvea Ylan: Lt -u4 Project: Kuparuk River Unit TVD Reference: Plan: 105.9+28 @ 133.90ft (Doyon 141) Reference Site: Kuparuk 2E Pad MD Reference: Plan: 105.9+28 @ 133.90ft (Doyon 141) Site Error: 0.00ft North ReferencW, True Reference Well: Plan: 2E-04 Survey Calculation Method Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan: 2E-04 Database: EDM v16 Prod Reference Design: ` 2E-04wp06 Offset TVD Rsference: Offset Datums Offset Design Kuparuk 2E Pad - 2E-06 - 2E-06 2E-06 Survey Program: 150-GYD-CT-CMS Offset .WeliExror; 0- 00'(t -Reference Offset" Semi Major Axis Distance Measured Vertical Measured Vertical Reference :Offset Azimuth Offset Wellbo re Centre Between Between "Minimum Separation ,' yamlrtg Depth Depth Depth depth from North +NIS : +E/ -W Centres Eihp"$: "Separation F�9etor (ft) (it) (ft) till (it) (4) i") fti) lift t ii (toNif 9,112.08 6,169.41 8,850.00 5,165.42 25.28 42.31 117.83 -6,152.03 1,340.23 4,107.62 3,898.67 215.20 19.658 CC, ES, SF 9,131.69 6,169.24 8,875.00 5,177.44 25.34 42.47 117.63 -6,173.44 1,344.95 4,113.91 3,904.33 215.73 19.630 9,151.31 6,169.08 8,900.00 5,189.58 25.39 42.63 117.43 -6,194.81 1,349.51 4,120.07 3,909.87 216.25 19.601 9,170.89 6,168.91 8,925.00 5,201.78 25.45 42.78 117.23 -6,216.15 1,354.07 4,126.24 3,915.42 216.77 19.572 9,190.40 6,168.74 8,950.00 5,214.12 25.51 42.94 117.03 -6,237.42 1,358.60 4,132.39 3,920.95 217.30 19.544 9,209.80 6,168.58 8,975.00 5,226.74 25.57 43.10 116.83 -6,258.54 1,363.03 4,138.40 3,926.34 217.82 19.515 9,229.12 6,168.41 9,000.00 5,239.54 25.63 43.25 116.63 -6,279.57 1,367.38 4,144.32 3,931.63 218.34 19.485 9,248.43 6,168.25 9,025.00 5,252.38 25.68 43.40 116.42 -6,300.58 1,371.71 4,150.27 3,936.96 218.87 19.456 9,267.65 6,168.08 9,050.00 5,265.36 25.74 43.56 116.22 -6,321.50 1,376.05 4,156.22 3,942.29 219.39 19.428 9,286.66 6,167.92 9,075.00 5,278.66 25.80 43.71 116.01 -6,342.21 1,380.41 4,162.13 3,947.59 219.90 19.400 9,305.47 6,167.76 9,100.00 5,292.26 25.86 43.86 115.80 -6,362.72 1,384.81 4,168.02 3,952.87 220.42 19.372 9,324.19 6,167.60 9,125.00 5,305.97 25.92 44.01 115.59 -6,383.16 1,389.22 4,173.94 3,958.18 220.93 19.345 9,342.82 6,167.44 9,150.00 5,319.82 25.98 44.16 115.37 -6,403.50 1,393.63 4,179.87 3,963.49 221.44 19.318 9,361.34 6,167.28 9,175.00 5,333.87 26.03 44.31 115.16 -6,423.71 1,397.98 4,185.73 3,968.74 221.95 19.291 9,379.79 6,167.12 9,200.00 5,348.06 26.09 44.46 114.94 -6,443.84 1,402.29 4,191.56 3,973.97 222.46 19.264 9,398.16 6,166.97 9,225.00 5,362.34 26.15 44.61 114.72 -6,463.90 1,406.62 4,197.43 3,979.24 222.96 19.238 9,416.37 6,166.81 9,250.00 5,376.85 26.21 44.76 114.50 -6,483.79 1,410.93 4,203.27 3,984.48 223.47 19.212 9,434.39 6,166.66 9,275.00 5,391.68 26.27 44.91 114.28 -6,503.47 1,415.17 4,208.99 3,989.61 223.97 19.186 9,452.26 6,166.50 9,300.00 5,406.73 26.32 45.05 114.06 -6,522.99 1,419.36 4,214.65 3,994.68 224.47 19.160 9,470.07 6,166.35 9,325.00 5,421.86 26.38 45.20 113.83 -6,542.44 1,423.55 4,220.35 3,999.79 224.96 19.135 9,487.77 6,166.20 9,350.00 5,437.14 26.44 45.34 113.60 -6,561.78 1,427.74 4,226.06 4,004.91 225.46 19.110 9,505.30 6,166.05 9,375.00 5,452.61 26.49 45.48 113.38 -6,580.96 1,431.97 4,231.80 4,010.07 225.95 19.086 9,522.70 6,165.90 9,400.00 5,468.21 26.55 45.63 113.15 -6,600.02 1,436.24 4,237.60 4,015.30 226.44 19.063 9,539.99 6,165.75 9,425.00 5,483.95 26.61 45.77 112.92 -6,618.97 1,440.52 4,243.44 4,020.56 226.93 19.040 9,925.38 6,177.83 9,450.00 5,499.93 27.70 45.91 107.10 -6,637.72 1,444.78 4,248.38 4,019.94 233.30 18.597 9,944.30 6,179.17 9,475.00 5,516.15 27.76 46.05 106.89 -6,656.27 1,448.99 4,252.55 4,023.51 233.82 18.567 9,963.13 6,180.50 9,500.00 5,532.49 27.83 46.19 106.67 -6,674.72 1,453.17 4,256.72 4,027.08 234.33 18.537 9,970.74 6,181.03 9,525.00 5,548.96 27.85 46.32 106.46 -6,693.06 1,457.35 4,260.92 4,030.79 234.73 18.515 9,970.74 6,181.03 9,550.00 5,565.63 27.85 46.46 106.24 -6,711.22 1,461.50 4,265.18 4,034.63 235.07 18.500 9,986.50 6,182.09 9,575.00 5,582.50 27.90 46.60 106.48 -6,729.21 1,465.63 4,269.41 4,038.45 235.33 18.485 10,000.00 6,182.92 9,600.00 5,599.46 27.94 46.73 106.66 -6,747.10 1,469.76 4,273.78 4,042.43 235.59 18.473 10,000.00 6,182.92 9,625.00 5,616.60 27.94 46.87 106.43 -6,764.83 1,473.87 4,278.17 4,046.41 235.92 18.459 10,000.00 6,182.92 9,650.00 5,633.89 27.94 47.00 106.20 -6,782.42 1,477.94 4,282.61 4,050.44 236.24 18.446 10,009.73 6,183.46 9,675.00 5,651.27 27.97 47.13 106.26 -6,799.93 1,481.96 4,287.10 4,054.55 236.50 18.436 10,051.77 6,185.83 9,700.00 5,668.77 28.09 47.26 105.67 -6,817.34 1,485.96 4,291.63 4,058.24 237.32 18.388 10,069.23 6,186.90 9,725.00 5,686.50 28.14 47.39 105.44 -6,834.52 1,489.88 4,295.98 4,062.07 237.78 18.365 10,086.49 6,187.95 9,750.00 5,704.47 28.19 47.52 105.21 -6,851.47 1,493.73 4,300.27 4,065.83 238.23 18.343 10,103.60 6,189.00 9,775.00 5,722.59 28.24 47.65 104.97 -6,868.26 1,497.56 4,304.57 4,069.61 238.68 18.320 10,120.50 6,190.03 9,800.00 5,740.91 28.30 47.78 104.73 -6,884.83 1,501.41 4,308.91 4,073.41 239.14 18.297 10,134.23 6,190.85 9,825.00 5,759.51 28.35 47.90 104.53 -6,901.08 1,505.30 4,313.30 4,077.32 239.55 18.278 10,150.55 6,191.83 9,850.00 5,778.31 28.40 48.02 104.29 -6,917.07 1,509.25 4,317.75 4,081.26 240.00 18.257 10,166.73 6,192.79 9,875.00 5,797.22 28.46 48.15 104.05 -6,932.93 1,513.24 4,322.31 4,085.31 240.44 18.238 10,182.69 6,193.74 9,900.00 5,816.33 28.51 48.27 103.80 -6,948.55 1,517.24 4,326.89 4,089.39 240.88 18.218 10,198.33 6,194.68 9,925.00 5,835.73 28.56 48.38 103.55 -6,963.81 1,521.15 4,331.39 4,093.40 241.31 18.200 10,213.72 6,195.60 9,950.00 5,855.37 28.62 48.50 103.29 -6,978.80 1,525.00 4,335.84 4,097.37 241.74 18.182 10,228.96 6,196.51 9,975.00 5,875.13 28.67 48.61 103.04 -6,993.63 1,528.83 4,340.33 4,101.38 242.16 18.164 10,243.99 6,197.40 10,000.00 5,895.05 28.72 48.73 102.78 -7,008.24 1,532.66 4,344.86 4,105.44 242.58 18.148 10,258.72 6,198.28 10,025.00 5,915.21 28.77 48.84 102.52 -7,022.52 1,536.49 4,349.40 4,109.53 242.99 18.132 10,273.22 6,199.15 10,050.00 5,935.56 28.83 48.95 102.26 -7,036.55 1,540.25 4,353.92 4,113.60 243.39 18.117 10,287.66 6,200.01 10,075.00 5,955.96 28.88 49.06 102.00 -7,050.51 1,543.99 4,358.50 4,117.73 243.79 18.102 10,302.10 6,200.87 10,100.00 5,976.33 28.93 49.17 101.74 -7,064.49 1,547.77 4,363.21 4,122.00 244.19 18.089 10,316.54 6,201.73 10,125.00 5,996.72 28.98 49.27 101.48 -7,078.46 1,551.56 4,368.02 4,126.37 244.60 18.076 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 8/28/2013 2:24:56PM Page 3 of 5 COMPASS 2003.16 Build 69 Schlumberger 0 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 2E Pad Site Error: 0.00ft Reference Well: Plan: 2E-04 Well Error: 0.00ft Reference Wellbore Plan: 2E-04 Reference Design: 2E-04wp06 0 Schlumberger Anticollision Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: CowcoPhillips Well Plan: 2E-04 Plan: 105.9+28 @ 133.90ft (Doyon 141) Plan: 105.9+28 @ 133.90ft (Doyon 141) True Minimum Curvature 1.00 sigma EDM v16 Prod Offset Datum Offset Design Kuparuk 2E Pad - 2E-06 - 2E-06 - 2E-06 Offset site Error; 0.00ft Survey Program: 150-GYD-CT-CMS Offset Well ErroY: Oi00ft Reference Offset Semi Major Axis Distance Measured Vertical Measured Vertical. Reference Offset Azimuth Offset Wellbore Centre Between Between Minimum Separation Wanting Depth Depth Depth Depth from North +N/ -S +E/ -W Centres Ellipses Separation 'Factor (ft).. (ft) (ft) (ft) (ft) (ft). (°) (ft) (ft) (ft) (ft) (ft) 10,330.98 6,202.59 10,150.00 6,017.13 29.03 49.38 101.22 -7,092.41 1,555.25 4,372.81 4,130.73 245.00 18.063 10,345.57 6,203.46 10,175.00 6,037.52 29.08 49.49 100.96 -7,106.47 1,558.63 4,377.41 4,134.89 245.41 18.050 10,360.42 6,204.35 1Q200.00 6,057.83 29.14 49.60 100.70 -7,120.74 1,561.63 4,381.75 4,138.79 245.83 18.035 10,375.49 6,205.25 10,225.00 6,078.03 29.19 49.71 100.45 -7,135.21 1,564.40 4,385.99 4,142.59 246.25 18.019 10,390.69 6,206.15 10,250.00 6,098.14 29.24 49.83 100.19 -7,149.82 1,567.13 4,390.30 4,146.46 246.68 18.004 10,405.97 6,207.06 10,275.00 6,118.18 29.30 49.94 99.94 -7,164.50 1,569.89 4,394.74 4,150.45 247.11 17.990 10,421.32 6,207.98 10,300.00 6,138.15 29.35 50.05 99.69 -7,179.28 1,572.68 4,399.31 4,154.58 247.54 17.976 10,436.75 6,208.90 10,325.00 6,158.07 29.41 50.17 99.44 -7,194.12 1,575.47 4,403.98 4,158.80 247.97 17.963 10,452.23 6,209.82 10,350.00 6,177.96 29.47 50.28 99.20 -7,209.02 1,578.21 4,408.68 4,163.06 248.41 17.949 10,467.75 6,210.75 10,375.00 6,197.81 29.52 50.40 98.95 -7,223.96 1,580.96 4,413.48 4,167.42 248.85 17.937 10,483.29 6,211.68 10,400.00 6,217.64 29.58 50.51 98.70 -7,238.93 1,583.75 4,418.40 4,171.91 249.29 17.925 10,498.83 6,212.60 10,425.00 6,237.47 29.64 50.63 98.46 -7,253.90 1,586.55 4,423.43 4,176.50 249.73 17.914 10,514.40 6,213.53 10,450.00 6,257.28 29.69 50.74 98.21 -7,268.90 1,589.32 4,428.50 4,181.14 250.17 17.903 10,530.14 6,214.47 10,475.00 6,276.99 29.75 50.86 97.97 -7,284.05 1,591.94 4,433.53 4,185.74 250.62 17.892 10,546.14 6,215.43 10,500.00 6,296.53 29.81 50.98 97.73 -7,299.45 1,594.35 4,438.47 4,190.24 251.07 17.880 10,562.45 6,216.40 10,525.00 6,315.89 29.87 51.10 97.49 -7,315.13 1,596.51 4,443.27 4,194.59 251.54 17.868 10,578.94 6,217.38 10,550.00 6,335.12 29.93 51.17 97.26 -7,330.97 1,598.47 4,447.97 4,198.95 251.99 17.862 10,595.44 6,218.37 10,575.00 6,354.36 29.99 51.23 97.03 -7,346.82 1,600.41 4,452.73 4,203.42 252.43 17.860 10,611.94 6,219.35 10,600.00 6,373.59 30.06 51.29 96.79 -7,362.67 1,602.36 4,457.57 4,207.96 252.87 17.858 10,628.44 6,220.34 10,625.00 6,392.83 30.12 51.36 96.56 -7,378.52 1,604.30 4,462.48 4,212.58 253.31 17.857 10,644.94 6,221.32 10,650.00 6,412.06 30.18 51.42 96.33 -7,394.37 1,606.25 4,467.47 4,217.27 253.76 17.856 10,661.44 6,222.30 10,675.00 6,431.30 30.24 51.48 96.10 -7,410.22 1,608.20 4,472.52 4,222.04 254.20 17.855 10,671.34 6,222.90 10,690.00 6,442.84 30.28 51.51 95.96 -7,419.73 1,609.36 4,475.59 4,224.94 254.46 17.855 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 812812013 2:24:56PM Page 4 of 5 COMPASS 2003.16 Build 69 Schlumberger 01 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 2E Pad Site Error: 0.00ft Reference Well: Plan: 2E-04 Well Error: 0.00ft Reference Wellbore Plan: 2E-04 Reference Design: 2E-04wp06 Reference Depths are relative to Plan: 105.9+28 @ 133.90ft (Doyon 14Coordinates are relative to: Plan: 2E-04 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1983, Alaska Zone 4 Central Meridian is 150° 0'0.000 W ° Grid Convergence at Surface is: 0.23° Schlumberger Anticollision Report ConocoPhillips Local Co-ordinate Reference: Well Plan: 2E-04 TVD Reference: Plan: 105.9+28 @ 133.90ft (Doyon 141) MD Reference: Plan: 105.9+28 @ 133.90ft (Doyon 141) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: EDM v16 Prod Offset ND Reference: Offset Datum Reference Depths are relative to Plan: 105.9+28 @ 133.90ft (Doyon 14Coordinates are relative to: Plan: 2E-04 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1983, Alaska Zone 4 Central Meridian is 150° 0'0.000 W ° Grid Convergence at Surface is: 0.23° CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 8/28/2013 2:24:55PM Page 5 of 5 COMPASS 2003.46 Build 69 Ladder Plot I i I I 1 I I I I I I I 1 I I 1 I I i I 1 i I I i I I i I i I I I I I I I I I I I I i i I I i I I I I I 1 I I I i 1 1 i I 1 i i I I 1 I I I I I I I I I I I I I 6000 � •� I I I I I i I I I 1 I I i 1 I i 1 i I 1 I I I I i I I i i i I i i I I __ I I I I I I I __ I I I I i I I __ i I i I _ I i I 1 i i I 1 I I I I I I I I 1 I I 1 I I I I I I I I I I I I I I I 1 I I I I i I 1 1 I 1 1 I 4500 O .O O U] Q1 3000- 0 0 N C 4) U 1500 0 0 2000 4000 6000 8000 10000 12000 Measured Depth LEGEND 2 E-H.2E•06,2 E-06 V1 CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 8/28/2013 2:24:55PM Page 5 of 5 COMPASS 2003.46 Build 69 I i I I 1 I I I I I I I 1 I I 1 I I i I 1 i I I i I I i I i I I I I I I I I I I I I i i I I i I I I I I 1 I I I i 1 1 i I 1 i i I I 1 I I I I I I I I I I I I I 1 I I 1 I I I I � •� I I I I I i I I I 1 I I i 1 I i 1 i I 1 I I I I i I I i i i I i i I I __ I I I I I I I __ I I I I i I I __ i I i I _ I i I 1 i i I 1 I I I I I I I I 1 I I 1 I I I I I I I I I I I I I I I 1 I I I I i I 1 1 I 1 1 I CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 8/28/2013 2:24:55PM Page 5 of 5 COMPASS 2003.46 Build 69 2E-04 Drilling Risks Summary 13-1/2" Hole / 10-3/4" Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously ing interval. Gas Hydrates Low If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, Additions of Lecithin. Anti -collision Low Run Gyro as needed. Drill with great care at the depth higher MW's required where Clearance Factor close to 1.5. Gravel / Sand Sloughing Low Increase mud weight / viscosity, High viscosity sweeps. Lost circulation Low Monitor fill on connections Hole Swabbing / Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill (use of Trips Moderate trip sheets), Pumping out of hole as needed. Lost circulation Low Prevent by keeping hole clean. If losses occur - reduce pump rates and mud rheology, use LCM Unsuccessful cement job Moderate Use lower density cement slurry. Add proper LCM. Adjust the mud properties prior pump cement. Use proper pump rate. Install stage collar at 1000' prepare for Abnormal Reservoir Pressure Moderate secondary cement job. 9-7/8" Hole / 7-5/8" Casing Interval Event Risk Level Mitigation Strategy Shale stability Moderate For the unstable HRZ and Kalubik shales with high higher MW's required inclination control with higher MW and proper trapping speed to avoid surging or swabbing. High ECD and swabbing with Low Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Lost circulation Low Use PWD and TAD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision Lost Circulation Moderate tree. Hole cleaning Low Use PWD and TAD to monitor hole cleaning. Control the ROP and use the best hole cleaning practice. Stuck pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, proper mud weight, PWD monitorECD. Abnormal Reservoir Pressure Moderate Reservoir pore pressure is estimated from 9.0 to 10.8 ppg. Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. 6-1/2" Hole / 4-1/2" Liner Interval Event Risk Level Mitigation Strategy High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Abnormal Reservoir Pressure Moderate Reservoir pore pressure is estimated from 9.0 to 10.8 ppg. This interval may across over pressured zone and under pressure zone. Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling ay interyal. Lost Circulation Moderate Use PWD and Torque And Drag to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Prepared by Haibin Guo 0 Prepared by Haibin Guo Use GKA LC decision tree. Stuck pipe Moderate Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, proper mud weight to minimize differential stuck, PWD monitor ECD. Hole swabbing on trips Moderate Control trip speeds, monitor proper hole fill while tripping, good hole cleaning. Pump or backream out if necessary. Prepared by Haibin Guo 2E-4 PRODUCER (No Pre -Produce) FMC wellhead w/ 4-1/2" Tubing Hanger / Tree 16" Conductor to 107' 3-%11 DS Landing Nipple 10-%" Stage Collar -1000 ftMD 3'/:" MMG GLM x 1.5" OD 3%"MMG GLMx1.5"OD 10-3/4" 45.5# L-80 Hydri1563 Surface Casing @ 3900' MD / 3290' TVD cemented to surface ► 3-1/2" 9.3 # L-80 EUE Tubing Top Kuparuk C 5970' TVDSS / 70- Top A5 Sand , 6040' TVDSS / 75-85° 3-1/2" MMG GLM x 1.5" OD Planned TOC @ 7000' MD/5420' TVD 7-5/8" ZXP Liner Hanger/ iiii 3-%" 2.813" X Nipple Top Packer @ 65 deg J� 5.75" x 4-%" Swell Packer -2)ts, below Drillable Frac Sleeve (Drop Balt System) 6-1/2" Hole TD @ 14738' MD / 6282' TVD 7-5/8" 39# TN-11OSS Hydril563 Casing 4-1/2" 12.6# L-80 Hydril-563 Liner @ 8600' MD / 6174' TVD (86° ) 7-5/8" 29.7# L-80 Hydril563 Casing @ 8100' MD / 6111' TVD (74°) 6000 ft Hzl Section Pre -pert Pups 4-%" Orange Peel Shoe • Ferguson, Victoria L (DOA) From: Guo, Haibin <Haibin.Guo@conocophillips.com> Sent: Thursday, November 07, 2013 11:21 AM To: Ferguson, Victoria L (DOA) Cc: Bettis, Patricia K (DOA); Schwartz, Guy L (DOA) Subject: RE: 2E-04 (PTD 213-168) Victoria, Good catch. Well 2E-04 is located in a block isolated with faults as shown below. There is no production or injection in this block. The estimated BHP is around 9.Oppg. 3400psi(10.8ppg) is BHP of its closest offset well 2E-09, which is faulted away from 2E- 04. Even if the faults are not well sealed the maximum possible pressure on 2E-4 is estimated not higher than 10.8ppg. As the drilling program states we are planning to drill the hole PB1 first with 10.5-11.Oppg mud and penetrate the reservoir sand (A5) with 11.0ppg Coring fluid. The formation pressure survey will be conducted with SLB SethoScope tool. So we can know the exact reservoir pressure before we drill the 2E-04 intermediate and production hole. If the survey shows the pressure is higher than estimated 9.Oppg, we'll add 0.3-0.5ppg safety margin on that as the drilling fluid weight. If the survey shows lower or equal to 9.Oppg, we'll use 9.5-10ppg as the drilling fluid. If want me to add a note in the drilling program or more question let me know. Thanks. 2E-03104 location Map: A1.04 horizontal sections Kc>N�11 GLOP/ Cil//Ai10N1 AND �•V•LOI�M•Ni Haibin Guo Senior Drilling Engineer ConocoPhillips Alaska Office: 907.265.1487 Cell: 907.227.6048 From: Ferguson, Victoria L (DOA) [niaiIto: victoria.ferguson alaska.gov] Sent: Thursday, November 07, 2013 9:28 AM To: Guo, Haibin Cc: Bettis, Patricia K (DOA); Schwartz, Guy L (DOA) Subject: [EXTERNAL]2E-04 (PTD 213-168) Haibin, 2 ZF-W 27-15 2F-10 cLC-l� �cc-w ccc-.a • • Horizontal sec'ns 2000' from TD-af 2F-12 2F -u M13 26.16 �-10 2E-15 2E-10 . 2F- 2F-11 planned CTD IlatS FAM • 6000' horiz sec'ns r • 2F-18 2F-1@ 2F-19 2E-03 wp04 2E-04PB1_wp03 2F -19A11 m 2E-04_wp03 1 Z 2E IRevised faults from wk3D '*- If 21 Open Baffle Seal 26.17 ftp_Flts trines layer.lyr KRU STATE t Haibin Guo Senior Drilling Engineer ConocoPhillips Alaska Office: 907.265.1487 Cell: 907.227.6048 From: Ferguson, Victoria L (DOA) [niaiIto: victoria.ferguson alaska.gov] Sent: Thursday, November 07, 2013 9:28 AM To: Guo, Haibin Cc: Bettis, Patricia K (DOA); Schwartz, Guy L (DOA) Subject: [EXTERNAL]2E-04 (PTD 213-168) Haibin, 2 c: • In your drilling hazards section you quote a maximum reservoir pressure of 3400 psi at 6040' TVD which equates to 10.8 ppg. In your drilling fluid program you list drilling with a 9.5-10.0 ppg EMW. Please explain. Tha nx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793-1247 victoria.ferguson@alaska.00v • .7 TRANSMITTAL LETTER CHECKLIST WELL NAME: K `qE — C� y PTD: 'Q13103 ✓ Development _ Service Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: :;,. � %VEJ POOL: ► EJ' �t/E� ��/ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) 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 Pilot Hole name ( 1� lP, h 0, E -OPH)) and API number (50-0P,9- dl �3 S ©S - 70 - zm records, Ufa 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 conservation Spacing Exception 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 5/2013 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 18 Well Name: KUPARUK RIV UNIT 2E-04 Program DEVWell bore seg ❑ PTD#:2131680 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV/PEND GeoArea 890 Unit 11160 _ _ On/Off Shore On Annular Disposal Administration 17 Nonconven.. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) NA Yes 1 Permit fee attached NA CMT_ vol adequate_ to circulate -on conductor & surf_csg 2 Lease number appropriate Yes ADL0025658, Surf Loc; ADL0025665, Top Prod Intery & TD 3 Unique well name and number Yes KRU 2E-04 4 Well located in a defined pool Yes KUPARUK RIVER, KUPARUK RIV OIL - 490100, governed by Conservation Order 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 interwell spacing_ restrictions I7 Sufficient acreage available in drilling unit Yes 25 8 If deviated, is wellbore plat included Yes _ i9 Adequate wellbore separation proposed - - - - - - - - - - - - - - - - - - - - - - - Operator only affected party Yes Wellbore will be more than 500' from an external property line where ownership or landownership changes. 110 If diverter required, does it meet regulations- - - - _ _ _ - - - _ - - - - - - - - - - - Operator has appropriate bond in force Yes Appr Date 11 Permit can be issued without conservation order_ Yes Max formation pressure is_3400 psi(6040' TVD)EMW_ 10 8_ppg; will drill w/ 8.8-11.0 ppg EMW _if_needed . 12 Permit can be issued without administrative approval Yes - - - - - - Yes - - - PKB 11/6/2013 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 31 Choke_ manifold complies w/API_ RP -53 (May 84) - ------ - - - - ------- 15 All wells within 1/4 mile area of review identified (For service well only) NA - - _ - - Work will occur without operation shutdown- - - - - - - - - - - - - - - - - - - - - - - 16 Pre -produced injector:. duration of pre -production Less than 3 months (For service well only) NA 33 Geologic Engineering Pu is Date Commissioner: Date: Commissioner: Date om r • • 18 _Conductor string_ provided - - Yes Cnductor set to _ _• _ Engineering 19 Surface casingprotects all known LJSDWs Yes Surface casing set to 3290' TVD 20 CMT_ vol adequate_ to circulate -on conductor & surf_csg - - - Yes - 177Wexcess planned --- - - - - - - - 21 CMT_ vol adequate to tie-in long string to surf csg_ - - - - - - - - - - - _ - - - _ _ No - - - - - - _ TOC 7000'MD - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 22 CMT will cover all known_ productive horizons_ No- - - - _ Productive interval completed with_open hole liner w/ frac sleeves - - - - - - - - - - - - - - - - - - - 23 Casing designs adequate for CJ, B &- permafrost_ --- - _ Yes - - - - - - - - _ - _ - - - - - - - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 24 Adequate -tankage or reserve pit - - - - - - - - - - - - - -- - - - - - - - - - - - - - Yes - - Rig has steel tanks, allwaste_to approved disposal wells_ - - - - - - - - - - - - - - 25 If_a_re-drill, has -a 10-403 for abandonment been approved - - - - - - - - - - - - - - - - NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 26 Adequate wellbore separation proposed - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ - Antkccoliision report generated; no major failures - - - - - - - - - - - - - 27 If diverter required, does it meet regulations- - - - _ _ _ - - - _ - - - - - - - - - - - - - - Yes _ - - - _ _ - - _ _ - - _ _ _ - - - - - - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - 28 Drilling fluid_ program schematic & equip list adequate_ - - - - - - . - - - - - Yes Max formation pressure is_3400 psi(6040' TVD)EMW_ 10 8_ppg; will drill w/ 8.8-11.0 ppg EMW _if_needed . Appr Date VLF 11/8/2013 29 BOPEs,_do they meet regulation - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - l30BOPE_press rating appropriate; test to (put prig in comments)_ - - - _ _ - - Yes MPSP 2796 psi; will testBOPs_to 3500_psi_ - - - - - - - _ . - - - _ - - - - - - - - 31 Choke_ manifold complies w/API_ RP -53 (May 84) - ------ - - - - ------- - - - - - -- Yes - - - - - - ---------- - - - - ---- - - - - -- - --- - - -- ----- - - - - --------- - - - - - -- - 32 Work will occur without operation shutdown- - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 33 Is presence of H2S gas probable- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ - - - - _ _ 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_ - - - _ - - Wells_on 2E -Pad are_H2S-bearing. H2S measures required. _ _ _ _ - - - - - - - _ _ - - - - - _ _ _ _ - _ - Geology 36 Data -presented on potential overpressure zones - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - . - - - Expected reservoirpressure 9.0 pi EMW, but may range up to 10.8 pi EMW; pilot hole will be drilled_using - - - 37 Seismic analysis of shallow gas _zones - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -N_A_ _ _ _ - - _ _ 8.8-11.0 ppg mud. _Fm_ pressure sunray_ will be conducted in pilothole_prior_to drilling horizontal. Appr Date PKB 11/7/2013 38 Seabed condition surve-(ifoff_-shore -------------------NA---------------------------------------------------------------------------- 39 Contact name/phone for weekly -progress reports [exploratory only] _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ - - _ _ - - Onshore development well._ _ _ - - _ _ _ - - - _ _ - - - _ _ _ - - _ _ _ - - _ _ _ _ _ - - _ _ _ _ _ _ - - - - - - - - - - - - - Geologic Engineering Pu is Date Commissioner: Date: Commissioner: Date om r • •
