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Home My WebLink About216-058 • STATE OF ALASKA S s ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Full Tubing r Operations shutdown r Performed: Suspend Perforate Other Stimulate Alter r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: PROD to WAG 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p Explorator r 216-0580 3.Address: Alaska 99510 Stratigraphic r Service 6.API Number: r P. O. Box 100360, Anchorage, 50-029-21483-60 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25643, 25632 KRU 3F-12L1 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 9350 feet Plugs(measured) None true vertical 5891 feet Junk(measured) None Effective Depth measured 9350 feet Packer(measured) 0 true vertical 5891 feet (true vertical) 0 Casing Length Size MD TVD Burst Collapse SLOTTED LINER 1690' 2 3/8 9350' 5892' RECEIVED JAN 1 1 2017 Perforation depth: Measured depth: 7660'-9350' True Vertical Depth: 5835 AO GGC Tubing(size,grade,MD,and TVD) 3 1/2 ,L-80, 7036 MD, 5790 TVD Packers&SSSV(type,MD,and TVD) SSSV=None 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: CANNED °ark ' 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 3155 1200 1239 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Exploratory r Development r Service P. Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-623 Contact Scott Pessetto Email: SCOtt.t.peSSetto(C�Cop.COm Printed Name Scott Pessetto Title: Petroleum Engineer Signature .�_,..) Phone:263-4146 Date i / 1 of 17, 4-ri 3124 l / q-- 1, ,,-// r7 Form 10-404 Revised 5/2015 Submit Original Only RBDMS ),L1 JAN 2 5 2017 . • 3F-12L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/14/16 PUMP 2OBBL METH DOWN FL AND TBG 12/27/16 Open well to injection service 01/08/17 (ISW) INITIAL STATE WITNESSED (Chuck Scheve) MITIA PASSED TO 2080 PSI DATA SUBMITTAL COMPLIANCE REPORT 2/17/2017 Permit to Drill 2160580 Well Name/No. KUPARUK RIV UNIT 3F-121-1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21483-60-00 MD 9350 TVD 5891 Completion Date 9/30/2016 Completion Status WAGIN Current Status WAGIN UIC No REQUIRED INFORMATION Mud Log No 11", Samples Nov-,, Directional Survey Yes ✓ DATA INFORMATION Types Electric or Other Logs Run: GR/Res (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start StopReceived CH Comments ED C 27641 Digital Data 10/14/2016 Electronic File: 3F-121-1 EOW - NAD27.pdf ED C 27641 Digital Data 10/14/2016 Electronic File: 3F-121-1 EOW - NAD27.txt Log C 27641 Log Header Scans 0 0 2160580 KUPARUK RIV UNIT 3F-121-1 LOG HEADERS ED C 27734 Digital Data 11/11/2016 Electronic File: 3F-121-1 2MD Final Log.cgm ED C 27734 Digital Data 11/11/2016 Electronic File: 3F-121-1 5MD Final Log.cgm . ED C 27734 Digital Data 11/11/2016 Electronic File: 3F-121-1 5TVDSS Final Log.cgm . ED C 27734 Digital Data Q 11/11/2016 Electronic File: 3F-121-1 2MD Final.pdf , ED C 27734 Digital Data 11/11/2016 Electronic File: 3F-121-1 5MD Final.pdf • ED C 27734 Digital Data 11/11/2016 Electronic File: 3F-121-1 5TVDSS Final.pdf' l ED C 27734 k v Digital Data P 11/11/2016 Electronic File: 3F-121-1 EOW - NAD27.pdf t ED C 27734 Digital Data 11/11/2016 Electronic File: 3F-121-1 EOW - NAD27.txt ED C 27734 Digital Data 11/11/2016 Electronic File: 3F-121-1 Final Surveys 9350.csv . ED C 27734 Digital Data 11/11/2016 Electronic File: 3F-121-1 Survey Listing.txt ED C 27734 Digital Data 11/11/2016 Electronic File: 3F-121-1 Surveys.txt ED C 27734 Digital Data 11/11/2016 Electronic File: 3F - 12L 1 _25_tapescan_BH I_CTK.txt ED C 27734 Digital Data 11/11/2016 Electronic File: 3F - F- 12t -15 tapescan_B 12L15tapescan_B H I_CTK.txt ED C 27734 Digital Data 11/11/2016 Electronic File: 3F-12L1_output.tap' ED C 27734 Digital Data 11/11/2016 Electronic File: 3F-121-1 2MD Final Log.tif ED C 27734 Digital Data 11/11/2016 Electronic File: 3F-121-1 5MD Final Log.tif ' AOGCC Page] oF2 Friday, February 17, 2017 DATA SUBMITTAL COMPLIANCE REPORT 2/17/2017 Permit to Drill 2160580 Well Name/No. KUPARUK RIV UNIT 317-121-1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21483-60-00 MD 9350 TVD 5891 Completion Date 9/30/2016 Completion Status WAGIN Current Status WAGIN UIC No ED C 27734 Digital Data 11/11/2016 Electronic File: 3F-121-1 5TVDSS Final Log.tif . Log C 27734 Log Header Scans 0 0 2160580 KUPARUK RIV UNIT 3F-121-1 LOG HEADERS Well Cores/Samples Information: Name INFORMATION RECEIVED Completion Report 0 Production Test Informatiotly NA Geologic Markers/Tops IIJJ_ COMPLIANCE HISTORY Completion Date: 9/30/2016 Release Date: 4/15/2016 Description Comments: Sample Interval Set Start Stop Sent Received Number Comments Directional / Inclination Data (D Mud Logs, Image Files, Digital Data Y {GN41 Core Chips Y / Mechanical Integrity Test Information Y' V Composite Logs, Image, Data Files (9`/ Core Photographs Y Daily Operations Summary 0 Cuttings Samples Y Ib Laboratory Analyses Y1 A Date Comments Compliance Reviewed By: Date: C) AOGCC Page 2 of 2 Friday, February 17, 2017 THE STATE Alaska ®i1 and Gas Qf L A K A Conservation COrnanlssiOn GOVERNOR BILL WALKER Scott Pessetto Petroleum Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3 F -12L 1 Permit to Drill Number: 216-058 Sundry Number: 316-623 Dear Mr. Pessetto: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov 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. Sincerely, Cathy Pf. Foerster Chair 5 - DATED this day of December, 2016. R13DMS U DEC 2 2 2016 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ECEIV D DEC 15 2016 07"1 Z �Z 0116 r" 1. Type of Request: Abandon Plug Perforations I— Fracture Stimulate Repair Well r Operations shutdown T— Suspend r Perforate i— Other Stimulate Pull Tubing (— Change Approved Program F Plug for Redrill r Perforate New Pool r Re-enter Susp Well Alter Casing Other: PROD to WAG W 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. ' Exploratory Development r Stratigraphic j— Service 216-0580 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21483-60 " 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require spacing exception? Yes r— No % KRU 3F-121-1 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25643, 25632 Kuparuk River Field / Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9350 5891 9350' 5891' 3000 None None Casing Length Size MD TVD Burst Collapse SLOTTED LINER 1690' 23/8 9350' 5892' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7660' - 9350' • 5835 31/2 L-80 7036 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) SSSV=NONE PACKER= 2RH ZXP PACKER w/ HD Liner Top Packer MD= 6990 TVD= 5653 12. Attachments: Proposal Summary rV— Wel]Bore Schematic (y 13. Well Class after proposed work: Detailed Operations Program F BOP Sketch p Exploratory r'" Stratigraphic Development" Service ly- 14. Estimated Date for 12/18/16 15. Well Status after proposed work: Commencing Operations: OIL r WINJ r WIDSPL Suspended T- GAS WAG r + GSTOR SPLUG 16. 16. Verbal Approval: Date: Commission Representative: GINJ Op Shutdown j ` Abandoned 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact: Scott Pessetto Printed Name Scott Pessetto Phone: 263-4146 Email: scott.t.pessetto(d)cop.cornl Title: Petroleum Engineer Signature -t- Date: Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity r BOP Test j— Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ,?,,4 /;,N/x VTL1Z/zoJ 1�, Form 10-403 Revised 11/2015 App//��R.J is ttN; f r 12 months from the date of approval. Submit Form and Attachments in Duplicate RIBMIS � a 0L7C 2 2 2016 3F -12L1 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 3F-12 and its associated laterals L1, L1- 01, 1-1-02, L1-03 (PTD# 185-2730, 216-0580, 216-0590, 216-0600, 216-0610) from Oil Production service to Water Alternating Gas Injection service as the pre -production period has been completed. Area of Review: Kuparuk well 3F-12 and its associated laterals was completed as an injector on 9/30/16 to provide enhanced recovery injection into the reservoir to increase the u ima e recovery of oil. This well will support existing p oducers 3F-17, 3G-06, and 3G-08. The top of the A sand was found at 7231' MD / 5835 TVD Area Map with'/4 mile radius around target injection zone (see attached): The map attached shows that, with the exception of the offset injector 3F-15, there are no production/injection wells located within a 1/4 mile radius of the 3F-12, 3F -12L1, 31F-121-1-01, 3F-121-1-02, 3F-121-1-03 penetrations of the Kuparuk interval. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 3F-12 and its associated laterals is good and is classified as a "CTD horizontal quad -lateral" well. The injection tubing/casing annulus is isolated via a Baker ZXP packer located at 6990' MD (5653' TVD). A State -witnessed MIT -IA will be performed once well 3F-12 is converted to water injection, online, and stabilized. CBL and interpretation of the cement quality: See attached AOR Detail The 4-1/2" liner was cemented in place with 97 sx of class "G" cement. The 16" Conductor was cemented with 316 sx AS ll. The 9-5/8" Surface casing was cemented with 925 sx PF 'E' and 410 sx PF 'C'. The 7" Production casing was cemented with 150 sx Class "G" and 175 sx PF "C". o eplvej �Q✓� eti/ ��v.Yed VVwl M/g1 G"` ills' h9 �1� An i/Ij �i ,�/� , 3F-121-1 AREA OF REVIEW PTD API WELL NAME STATUS Top of A -sand Oil Pool (MD) Top of A -Sand Oil Pool(TVDSS) Top of Cement (MD) Top of Cement (TVDSS) Top of Cement Determined By Reservoir Status Zonal Isolation Cement Operations Summary Mechanical integrity The 4-1/2" liner was cemented in place with 97 sx of class "G" Packer @ 6,990' MD and 4-1/2" scab cement. The 16" Conductor was MIT -IA passed to 2,500 psi 185-273 50-029-21483-00 3F-12 Converting to 7231' 5835' 6275' 5099' liner cemented up to packer at cemented with 316 sx A511. The on 4/16/16. Rig tested Injector CBL Slotted Liner 6,990'. (171' from top of slotted 9-5/8" Surface casing was tubing to 3,500 psi for 15 liner) cemented with 925 sx PF 'E' and minutes on 4/10/16 before 410 sx PF'C'. The 7" Production rigging off. casing was cemented with 150 sx Class "G" and 175 sx PF "C. The 16" Conductor was cemented with 274 sx AS 11. The 185-293 50-029-21501-00 3F-15 Injector 7146' 5847' 5877' 4942' Calculated Perforated Baker FHL Retrievable Packer @ 9-5/8" Surface casing was IA DDT passed on 9/22/15. OA DDT passed on 9/22/15. 6,901' MD cemented with 910 sx PF 'E' and 400 sx Class V. The 7' MIT -IA to 2,000 psi passed Production casing was on 8/18/15. cemented with 200 sx Class 'G' ADL025547 M i 5548 TL 3F -12L1-01 3F-121-1 3F -12L1-03 3F-12 3F -12L1-02 30 Well Pad Wells within Radii 3F-12 Open Interval � 3F-121-1 Open Interval �31`-121-1-01 Open Interval 3F-121-1-02 Open Interval 3F-1211-03 Open Interval Q 1/4 Mile Radius 3F-12 1/4 Mile Radius 3F -12L1 1/4 Mile Radius 3F-121-1-01 1/4 Mile Radius 3F-1211-02 Q 1/4 Mile Radius 3F-121-1-03 Kuparuk PA Tabasco PA 0 500 3F T12NR9E ADL025643 I ConocoPhillips I i N Alaska, Inc. Injection SwapAnalysis Feet Y 1,000 3F-12 Wells I Date: 12/15/2016 Document Path. \\conoco.net\ak_sharedWNC\Longterm\GKA Geoscience\geotech_projects\GKA Wells\3F_12\well_3F_12_map_new.mxd :UP SVC 3F -12L1 r` LonOComillipsJWWell Attributes Max Angle & MD TD Ajaska, InC.Wellbore APIIUWI Field Name 500292148360 KUPARUK RIVER UNIT Wellbore Status SVC ncl (°) 98.19 MD (ftKB) Act Elm (ftKB) 9,320.11 9,350.0 Comment H2S (ppm) I Date SSSV: NIPPLE Annotation End Date Last WO: KB-Grd IN) Rig Release Date 41.88 12/12/1985 3F-1211, 10111/2016 4:00:44 PM Venicalschematic acne Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason: ADD LATERALS Iehallf 10/11/2016 ....... ........... ....._....._. __. _...._. HANGER; 32.7 a -s I n--g-SFrings Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (ND)... WtlLen (I... Grade Top Thread LINER. L1 2 3/8 1.992 7,659.8 9,350.0 5,890.6 4.60 L-80 ST L Liner Details Nominal ID Top (ftKB) I Top (TVD) (ftKB) Top Incl (°) Item Des Com (in) 7,659.8 5,864.5 88.30 1 BILLET I Aluminum Liner Top Billet 0.000 Perforations & Slots Shot ITTop en De- Top(TVD) (TVD) Bt. (TVD) (shotsM Top (ftKB) Bt. (ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,660.0 9,350.0 5,864.5 5,890.6 A-2, 3F-12 9/21/2016 SLOTS Alternating solid/slotted CONDUCTOR; 38.0-115.0 pipe - 0.125' x 2.5" IT 4 circumferential adjacent rows Notes: General & Safety End Date Annotation NOTE: SURFACE; 37 0-3,292.4 GAS LIFT, 6,884.6 NIPPLE, 6,945.6 LOCATOR; 6995.2 SEAL ASSY; 6 996 4 - (PERF, 7,116.0-7,146.0— PRODUCTION; 35.0.7,539 .9 LINER; 6,990.9-7,425 5 Liner Cement, 6,991.0 ftKB SLOTS, 7,162.0-9,400.0— LINER, L1-03; 7,161 7-9,4000 SLOTS; 7,370,0-9,350,0 LINER, Lt -01; 7,369.5-9.350.0 SLOTS; 7,660.0-9,3500 LINER, L1; 7.659.8-9.3500 ri.a BAKER HUGHES PRINT DISTRIBUTION LIST COMPANY ConocoPhillips Alaska, Inc. WELL NAME 3F -12L1 FIELD Prudhoe Bay Unit COUNTY North Slope Borough (digital/image) BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider(a)bakerhughes.com STATUS Final Replacement COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BO* PERSON ATTENTION O 21 6658 27 73 4 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp DATA LOGGED 700 G Street. 1\/Z'k/2016 M K BENDER Anchorage, Alaska 99510 Ito acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE September 29, 2016 TODAYS DATE November 7, 2016 Revision No Details: Requested by: --- FIELD FINALCD 0 CD LOGS LOGS (digital/image) Surveys (Final Surveys) # OF PRINTS 9 OF PKIN 16 # OF COPIES # OF COPIES # OF CORE 4 4 4 4 4 4 1 BP North Slope 0 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids Agatha Rutka & Barbara Glassmaker '900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 0 Attn: Ricky Elgaricio ATO 3-344 700 G Street (Anchorage, AK 99510 3 ExxonMobil, Alaska 0 0 0 Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 ,Anchorage, AK 99503 4 State of Alaska - AOGCC 1 1 1 Attn: Makana Bender 333 W. 7th Ave, Suite 100 (Anchorage, Alaska 99501 51DNR - Division of Oil & Gas *** 0 1 1 Attn: Sean Clifton 550 West 7th Avenue, Suite 802 horage, Alaska 99501 ***-Stamp "confidential" on all material deliver to DNR J 6'BP Exploration (Alaska) Inc. 1 1 1 Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 0 TOTALS FOR ALL PAGES: 0 2 3 3 0 0 'V' ConocoPh i I I i ps ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 3F Pad 3F -12L1 50-029-21483-60 Baker Hughes INTEQ Definitive Survey Report 05 October, 2016 WE a I BAKER HUGHES - ConocoPhillips //FAI BAKER ConocoPhillips Definitive Survey ReportHUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 3F Pad Well: 3F-12 Wellbore: 3F-12 Design: 3F-12 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well 3F-12 Local Co-ordinate Reference: Well 3F-12 TVD Reference: 3F-12 @ 93.00usft (3F-12) MD Reference: 3F-12 @ 93.00usft (3F-12) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM Alaska NSK Sandbox Well Position +N/ -S 0.00 usft Northing: Tie On Depth: 7,100.00 +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 3F-121-1 Direction Magnetics Model Name Sample Date (usft) BGGM2016 10/1/2016 Design 3F-121-1 93.00 Audit Notes: 0.00 45.00 Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,985,865.19 usft Latitude: 508,364.05 usft Longitude: usft Ground Level: Declination Dip Angle V) V) 17.93 80.96 700 22' 21.370 N 149° 55 55.273 W 0.00 usft Field Strength (nT) 57,547 Version: 1.0 Phase: ACTUAL Tie On Depth: 7,100.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (I 93.00 0.00 0.00 45.00 Survey Program Date From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 100.00 7,100.00 3F-12 (3F-12) GCT -MS Schlumberger GCT multishot 8/18/2000 7,179.00 9,320.12 3F-121-1 (3F-121-1) MWD MWD - Standard 9/15/2016 9/22/2016 10/5/2016 1 50:41PM Page 2 COMPASS 5000.1 Build 74 Survey MD ConocoPhillips Azi ConocoPhillips TVDSS +N1 -S +E1 -W Definitive Survey Report Map Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Co-ordinate Reference: Well 3F-12 Project: Kuparuk River Unit TVD Reference: 3F-12 @ 93.00usft (3F-12) Site: Kuparuk 3F Pad MD Reference: 3F-12 @ 93.00usft (3F-12) Well: 3F-12 North Reference: True Wellbore: 3F-12 Survey Calculation Method: Minimum Curvature Design: 3F-12 Database: EDM Alaska NSK Sandbox Survey MD Inc Azi TVD TVDSS +N1 -S +E1 -W Map Map DLS Vertical (waft) (I (°) (usft (waft) (usft) (usft) Northing Easting Section Survey Tool Name (ft) (ft) (ft) 7,100.00 40.72 242.85 5,735.68 5,642.68 -1,388.49 -3,216.77 5,984,473.25 505,149.16 0.42 -3,256.41 MWD (2) 7,179.00 40.67 242.78 5,795.57 5,702.57 -1,412.02 -3,262.59 5,984,449.66 505,103.37 0.09 -3,305.45 MWD (2) 7,210.19 47.90 245.50 5,817.89 5,724.89 -1,421.48 -3,282.18 5,984,440.18 505,083.78 23.96 -3,325.99 MWD (2) 7,240.59 57.61 257.00 5,836.31 5,743.31 -1,429.08 -3,305.06 5,984,432.56 505,060.92 43.82 -3,347.54 MWD (2) 7,270.45 70.18 263.10 5,849.43 5,756.43 -1,433.63 -3,331.41 5,984,427.99 505,034.58 45.89 -3,369.39 MWD (2) 7,300.42 82.18 266.44 5,856.58 5,763.58 -1.436.25 -3,360.34 5,984,425.33 505,005.66 41.47 -3,391.70 MWD (2) 7,330.63 86.28 279.64 5,859.63 5,766.63 -1,434.65 -3,390.28 5,984,426.90 504,975.72 45.53 -3,411.74 MWD (2) 7,360.61 86.99 293.27 5,861.39 5,768.39 -1,426.19 -3,418.91 5,984,435.32 504,947.08 45.45 -3,426.00 MWD (2) 7,390.61 86.87 307.02 5,863.01 5,770.01 -1,411.18 -3,444.75 5,984,450.30 504,921.22 45.77 -3,433.66 MWD (2) 7,420.53 88.80 320.94 5,864.14 5,771.14 -1,390.47 -3,466.21 5,984,470.98 504,899.74 46.93 -3,434.19 MWD (2) 7,450.43 90.52 335.35 5,864.32 5,771.32 -1,365.14 -3,481.95 5,984,496.29 504,883.98 48.53 -3,427.41 MWD (2) 7,480.56 89.36 348.05 5,864.35 5,771.35 -1,336.60 -3,491.39 5,984,524.83 504,874.50 42.33 -3,413.90 MWD (2) 7,500.25 90.28 357.35 5,864.42 5,771.42 -1,317.09 -3,493.89 5,984,544.33 504,871.98 47.46 -3,401.87 MWD (2) 7,530.65 92.18 10.80 5,863.76 5,770.76 -1,286.84 -3,491.74 5,984,574.58 504,874.10 44.67 -3,378.96 MWD (2) 7,560.99 90.68 12.93 5,863.00 5,770.00 -1,257.16 -3,485.50 5,984,604.26 504,880.30 8.58 -3,353.57 MWD (2) 7,591.17 89.63 15.17 5,862.92 5,769.92 -1,227.89 -3,478.17 5,984,633.54 504,887.60 8.20 -3,327.69 MWD (2) 7,620.71 88.47 17.74 5,863,41 5,770.41 -1,199.56 -3,469.81 5,984,661.87 504,895.93 9.54 -3,301.74 MWD (2) 7,651.23 88.34 20.57 5,864.26 5,771.26 -1,170.75 -3,459.80 5,984,690.69 504,905.91 9.28 -3,274.29 MWD (2) 7,681.28 88.19 22.44 5,865.17 5,772.17 -1,142.80 -3,448.79 5,984,718.65 504,916.88 6.24 -3,246.75 MWD (2) 7,711.11 88.62 24.02 5,866.00 5,773.00 -1,115.40 -3,437.03 5,984,746.06 504,928.61 5.49 -3,219.06 MWD (2) 7,741.26 87.85 21.08 5,866.93 5,773.93 -1,087.58 -3,425.47 5,984,773.90 504,940.14 10.08 -3,191.21 MWD (2) 7,771.34 87.48 18.28 5,868.16 5,775.16 -1,059.28 -3,415.35 5,984,802.20 504,950.22 9.38 -3,164.04 MWD (2) 7,801.73 87.58 16.83 5,869.47 5,776.47 -1,030.33 -3,406.19 5,984,831.16 504,959.35 4.78 -3,137.10 MWD (2) 7,832.59 87.88 18.82 5,870.69 5,777.69 -1,000.98 -3,396.76 5,984,860.52 504,968.75 6.52 -3,109.67 MWD (2) 7,861.01 88.40 22.28 5,871.61 5,778.61 -974.38 -3,386.79 5,984,887.12 504,978.69 12.30 -3,083.81 MWD (2) 7,891.49 88.77 24.94 5,872.36 5,779.36 -946.47 -3,374.58 5,984,915.05 504,990.86 8.81 -3,055.44 MWD (2) 7,922.06 88.96 28.16 5,872.97 5,779.97 -919.13 -3,360.92 5,984,942.40 505,004.49 10.55 -3,026.45 MWD (2) 7,951.21 89.08 30.34 5,873.47 5,780.47 -893.70 -3,346.68 5,984,967.84 505,018.70 7.49 -2,998.41 MWD (2) 7,980.35 89.20 32.60 5,873.91 5,780.91 -868.85 -3,331.47 5,984,992.70 505,033.88 7.77 -2,970.08 MWD (2) 8,011.07 88.19 34.94 5,874.61 5,781.61 -843.32 -3,314.40 5,985,018.25 505,050.92 8.29 -2,939.96 MWD (2) Annotation TIP KOP FIAP.9 BAKER HUGHES 10/5/2016 1:50:41PM Page 3 COMPASS 5000.1 Build 74 V" ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Co-ordinate Reference: Well 3F-12 Project: Kuparuk River Unit TVD Reference: 3F-12 @ 93.00usft (3F-12) Site: Kuparuk 3F Pad MD Reference: 3F-12 @ 93.00usft (3F-12) Well: 3F-12 North Reference: True Wellbore: 3F-12 Survey Calculation Method: Minimum Curvature Design: 3F-12 Database: EDM Alaska NSK Sandbox Survey Annotation roil BAKER HUGHES 10/5/2016 1:50,41PM Page 4 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W DLS Northing Easting Section Survey Tool Name (usft) (I (I (usft) (usft) (usft) (usft) (°/100') (ft) (ft) (ft) 8,040.63 86.56 36.73 5,875.96 5,782.96 -819.39 -3,297.12 5,985,042.20 505,068.18 8.19 -2,910.81 MWD (2) 8,071.33 85.08 38.73 5,878.20 5,785.20 -795.17 -3,278.38 5,985.066.43 505,086.89 8.09 -2,880.44 MWD (2) 8,100.13 83.97 41.21 5,880.95 5.787.95 -773.20 -3,259.97 5,985,088.42 505,105.27 9.40 -2,851.88 MWD (2) 8,130.73 85.02 43.15 5,883.88 5,790.88 -750.63 -3,239.52 5,985.111.01 505,125.70 7.18 -2,821.46 MWD (2) 8,160.56 86.25 44.99 5,886.15 5,793.15 -729.26 -3,218.83 5,985,132.40 505,146.36 7.40 -2,791.72 MWD (2) 8,190.79 86.13 47.81 5,888.16 5,795.16 -708.47 -3,196.99 5,985,153.22 505,168.17 9.32 -2,761.57 MWD (2) 8,220.66 85.14 50.96 5,890.43 5,797.44 -689.08 -3,174.38 5,985,172.63 505,190.75 11.02 -2,731.88 MWD (2) 8,250.71 85.33 53.74 5,892.93 5,799.93 -670.79 -3,150.68 5,985,190.95 505,214.44 9.24 -2,702.18 MWD (2) 8,280.84 85.27 56.34 5,895.40 5,802.40 -653.58 -3,126.07 5,985,208.18 505,239.03 8.60 -2.672.62 MWD (2) 8,310.85 87.36 57.21 5,897.33 5,804.33 -637.18 -3,101.02 5,985,224.61 505,264.06 7.54 -2,643.30 MWD (2) 8,339.63 88.77 58.02 5,898.30 5,805.30 -621.77 -3,076.73 5.985,240.04 505,288.32 5.65 -2,615.23 MWD (2) 8,370.20 88.71 60.03 5,898.97 5,805.97 -606.04 -3,050.53 5,985.255.80 505,314.51 6.58 -2,585.58 MWD (2) 8,400.65 88.16 62.45 5,899.81 5,806.81 -591.40 -3,023.84 5.985.270.47 505,341.17 8.15 -2,556.36 MWD (2) 8,430.95 86.44 63.55 5,901.23 5,808.23 -577.66 -2,996.88 5,985,284.24 505,368.12 6.74 -2,527.58 MWD (2) 8,460.79 86.28 66.81 5,903.13 5,810.13 -565.16 -2,969.85 5,985,296.77 505,395.13 10.92 -2,499.63 MWD (2) 8,490.65 85.67 69.35 5,905.22 5,812.22 -554.04 -2,942.22 5,985.307.92 505,422.74 8.73 -2,472.23 MWD (2) 8,520.04 85.76 72.10 5,907.42 5,814.42 -544.37 -2,914.56 5,985,317.62 505,450.39 9.34 -2,445.83 MWD (2) 8,550.51 85.79 74.79 5,909.67 5,816.67 -535.71 -2,885.44 5.985.326.31 505,479.50 8,80 -2,419.11 MWD (2) 8,580.65 86.22 77.17 5,911.77 5,818.77 -528.43 -2,856.27 5,985,333.63 505,508.66 8.01 -2,393.34 MWD (2) 8,610.55 86.25 79.51 5,913.73 5,820.73 -522.40 -2,827.05 5,985,339.69 505,537.87 7.81 -2,368.41 MWD (2) 8,640.36 85.95 82.01 5,915.76 5.822.76 -517.62 -2,797.70 5,985.344.50 505,567.21 8.43 -2,344.28 MWD (2) 8,670.48 85.67 81.84 5,917.96 5,824.96 -513.40 -2,767.95 5,985.348.75 505,596.95 1.09 -2,320.27 MWD (2) 8,700.03 85.79 79.07 5,920.16 5,827.16 -508.51 -2,738.90 5,985,353.67 505,626.00 9.36 -2,296.27 MWD (2) 8,730.60 85.85 77.28 5,922.39 5,829.39 -502.27 -2,709.06 5,985.359.95 505,655.83 5.84 -2,270.75 MWD (2) 8,760.20 86.01 76.01 5,924.49 5,831.49 -495.45 -2,680.33 5,985,366.80 505,684.54 4.31 -2,245.61 MWD (2) 8,790.58 88.62 76.24 5,925.91 5.832.91 -488.17 -2,650.87 5,985.374.11 505,713.99 8.62 -2,219.64 MWD (2) 8,820.68 90.89 77.33 5,926.04 5,833.04 1481.29 -2,621.57 5,985,381.02 505,743.28 8.37 -2,194.05 MWD (2) 8,850.45 92.58 77.21 5,925.14 5,832.14 -474.73 -2,592.55 5,985.387.61 505,772.29 5.69 -2,168.90 MWD (2) 8,880.51 93.01 76.27 5,923.67 5,830.67 467.85 -2,563.32 5,985,394.53 505,801.51 3.44 -2,143.36 MWD (2) 8,910.56 92.70 75.19 5,922.18 5,829.18 -460.45 -2,534.24 5,985,401.95 505,830.58 3.73 -2,117.56 MWD (2) 81940.72 91.69 74.61 5,921.02 5,828.02 452.60 -2,505.14 5.985,409.84 505,859.67 3.86 -2,091.44 MWD (2) Annotation roil BAKER HUGHES 10/5/2016 1:50,41PM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Site: Kuparuk 3F Pad Well: 3F-12 Wellbore: 3F-12 Design: 3F-12 Survey MD Inc Azi TVD TVDSS +N/ -S (usft) (I M (usft) (usft) (usft) 8,970.42 91.84 73.66 5,920.11 5,827.11 -444.46 8,995.52 91.97 72.30 5,919.27 5,826.27 -437.14 9,025.53 91.60 71.53 5,918.34 5,825.34 -427.83 9,049.26 92.46 69.36 5,917.50 5,824.50 -419.89 9,080.68 94.06 68.78 5,915.71 5,822.71 408.69 9,110.27 94.70 67.31 5,913.45 5,820.45 -397.66 9,140.04 94.42 66.04 5,911.08 5,818.08 -385.91 9,170.14 93.81 64.60 5,908.92 5,815.92 -373.37 9,200.12 94.18 63.11 5,906.83 5,813.83 -360.19 9,230.24 95.32 61.82 5,904.34 5,811.34 -346.32 9,260.29 95.84 60.12 5,901.42 5,808.42 -331.81 9,290.96 95.69 59.13 5,898.34 5,805.34 -316.38 9,320.12 98.19 58.98 5,894.81 5,801.81 -301.49 9,350.00 98.19 58.98 5,890.56 5,797.56 -286.25 10/5/2016 1:50:41 PM ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3F-12 3F-12 @ 93.00usft (3F-12) 3F-12 @ 93.00usft (3F-12) True Minimum Curvature EDM Alaska NSK Sandbox ON as BAKER HUGHES Page 5 COMPASS 5000.1 Build 74 Map Map Vertical +E/.WNorthing (usft) Easting DLS (°1100') Section Survey Tool Name Annotation (ft) (ft), (ft) -2,476.59 5,985,417.98 505,888.21 3.24 -2,065.51 MWD (2) -2,452.60 5,985,425.35 505,912.18 5.44 -2,043.36 MWD (2) -2,424.09 5,985,434.69 505,940.68 2.85 -2,016.61 MWD (2) -2,401.74 5,985,442.66 505,963.02 9.83 -1,995.20 MWD (2) -2,372.44 5,985,453.89 505,992.30 5.42 -1,966.56 MWD (2) -2,345.08 5,985,464.95 506,019.65 5.40 -1,939.41 MWD (2) -2,317.83 5,985,476.73 506,046.88 4.36 -1,911.83 MWD (2) -2,290.55 5,985,489.30 506,074.15 5.18 -1,883.68 MWD (2) -2,263.70 5,985,502.50 506,100.98 5.11 -1,855.38 MWD (2) -2,237.09 5,985,516.41 506,127.57 5.70 -1,826.74 MWD (2) -2,210.94 5,985,530.95 506,153.70 5.89 -1,797.99 MWD (2) -2,184.61 5,985,546.41 506,180.01 3.25 -1,768.47 MWD (2) -2,159.79 5,985,561.31 506,204.81 8.59 -1,740.39 MWD (2) -2,134.44 5,985,576.58 506,230.14 0.00 -1,711.69 PROJECTED to TD Page 5 COMPASS 5000.1 Build 74 STATE OF ALASKA ALA_ OIL AND GAS CONSERVATION COMM_ION REPORT OF SUNDRY WELL OPERATIONS 1. operations Abandon f— Plug Perforations [_ Fracture Stimulate F Pull Tubing Operations shutdown F Performed: Suspend Perforate F_ Other Stimulate F Alter Casing 9 Change Approved Program Plug for Redrill Perforate New Pool Repair Well F Re-enter Susp Well F Other: PROD > 30 Days (✓ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory F_ Stratigraphic F_ Service 216-0580 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21483-60 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25643, 25632 KRU 3F-121_1 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 9350 feet Plugs (measured) None true vertical 5891 feet Junk (measured) None Effective Depth measured 9350 feet Packer (measured) 6995, 6996 true vertical 5891 feet (true vertical) 5657, 5657 Casing Length Size MD TVD Burst Collapse LINER, L1 1690' 23/8 9350' 5892' Ga ECEI ®I Perforation depth: Measured depth: Slotted Liner 7660-9350 , , True Vertical Depth: Slotted Liner 5864-5890 NOV 0 8 2016 AGIGICC Tubing (size, grade, MD, and TVD) 2 7/8 ,J-55, 7172 MD, 5790 TVD Packers & SSSV (type, MD, and TVD) SSSV = None LOCATOR = LOCATOR SUB @ 6995 MD and 5657 TVD SEAL ASSY = BAKER 80/40 SEAL ASSEMBLY W/ 7 FT SPACE OUT @ 6996 MD and 5657 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 340 1403 3011 1350 282 14. Attachments (required per 20 AAC 25.070, 25.071, &25.283) 15. Well Class after work: Daily Report of Well Operations f4_0 Exploratory F Development Fv_ Service F Stratigraphic r Copies of Logs and Surveys Run 16. Well Status after work: Oil Fv- Gas F WDSPL F Printed and Electronic Fracture Stimulation Data GSTOR F WINJ F WAG F GINJ I— SUSP F SPLUG F 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: N/A Contact Darrell Humphrey Email: n1139�aiconocophillips.com Printed Name Darrell Hum hre Title: NSK Production Engineering Specialist Signature Phone: 659-7535 Date Gj -- S— J J2 For Submit Or*eonal Only ,4K�6>r1 Vl-` 7 / /6 / � 7- RBDMS I,v NOV 1 0 2016 3F-121-1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/07/161 Convert to Producer (pre- produced water injector for > 30 days) .I KUP SVC 3F -12L1 1-onocornimps Well Attributes I Max Angle & MD ITD Alaska. Inc. -(°) MD(ftKB) ActBtm(ftKB) WellboreAPI/UWI Field Name Wellbore Status 500292148360 KUPARUK RIVER UNIT SVC 98.19 9,320.11 9,350.0 Comment H25 (ppm) Date SSSV: NIPPLE Annotation End Dat¢ Last WO: KB-Grd (ft) Rig Release Date 41.88 12/12/1985 3F-1211, 10111 2 01 6 4:00:44 PM Vertical schematic actual Annotation Depth (ftKB) End Dale Annotation Last ey End1Data Last Tag: Rev Reason: ADD LATERALS llf lehallf 10/11/2016 MANGER; 32.] .. —7 Casing Strings Casing Description IOU (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... Wt/Len (I... Grade Top Thread LINER, L1 2 3/8 1.992 7,659.8 9,350.0 5,890.6 4.60 L-80 ST L Liner Details Top (ftKB) Top (TVD) (ftKB) I Top Incl (°) Item Des Com Nominal lD (in) 7,659.8 5,864.5 88.30 1 BILLET Aluminum Liner Top Billet 0.000 Perforations & Slots Shot Den Top (TVD) Sun, (TVD) (shot fl Top (ftKB) St. (ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,660.0 9,350.0 5,864.5 5,890.6 A-2,317-12 9/21/2016 SLOTS Altemating solid/slotted coNDucroR; 38.0-115.0 pipe -0.125'x2.5"@4 circumferential adjacent rows Notes: General & Safety End Date Annotation NOTE: SURFACE; 37.0-3,292.4 GAS LIFT; 6,864.6 NIPPLE; 6,945:6 LOCATOR; 6,995.2 SEAL ASSY: 6,996.4 IPERF; 7,116.0-7,146.0— PRODUCTION; 35.0-7,539.9 LINER; 6,990.9-],425.5 Liner Cement; 6,991.0 ftKB SLOTS; 7,162.0-9,400.0—:�' LINER, L 7,161.0-9,400.0 1 SLOTS: 7,370.0-9,350.0i LINER, 11-01; 7,369.5-9,350.0 `— SLOTS; 7,660.0-9,350.0 LINER, L1; 7,659.8-9,350.0-- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED OCT 26 2016 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ [I WAG(] - WDSPL ❑ No. of Completions: 1b. Well Class: Development ❑ Exploratory ❑ Service El • Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Aband.: 9/30/2016 14. Permit to Drill Number / Sundry: 216-058/ ' 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 9/17/2016 15. API Number: 50-029-21483-60-00 4a. Location of Well (Governmental Section): Surface: 5238' FNL, 136' FEL, Sec 19, T12N, R9E, UM Top of Productive Interval: 1388' FNL, 3448' FEL, Sec 30, T12N, R9E, UM Total Depth: 244' FNL, 2271' FEL, Sec 30, T12N, R9E, UM 8. Date TD Reached: 9/20/2016 16. Well Name and Number: KRU 3F -12L1 . 9. Ref Elevations: KB:93 GL: 42 BF:56 17. Field / Pool(s): Kuparuk River Field/Kuparuk Oil Pool 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ADL 25643, ADL 25632 ' 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 508364 y- 5985865 Zone- 4 TPI: x- 505059 y- 5984432 Zone- 4 Total Depth: x- 506230 y- 5985577 Zone- 4 11. Total Depth MD/TVD: 9350/5891 • 19. Land Use Permit: 2574 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1593/1593 5. Directional or Inclination Survey: Yes • 0 (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 7179/5796 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 62.5 H-40 38 115 38 115 18 316 sx AS 11 95/8 36 J-55 37 3292 37 3033 11 5/8 925 SX PF E & 410 sx PF C 7 26 J-55 35 7539 35 6071 9 150 sx Class G & 175 sx PF C 23/8 4.6 L-80 1 7660 19350 15865 5891 3 Liner 24. Open to production or injection? Yes No ❑ If Yes, list each interval open (MDfTVD of Top and Bottom; Perforation Size and Number): SLOTTED LINER @ 7660 - 9350 MD and 5865 -5891 TVD COMPLETION DATE VERIFIED L �- 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3 1/2 7036 6991/5653 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No I] Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 10/7/2016 Method of Operation (Flowing, gas lift, etc.): FLOWING Date of Test: 10/12/2016 Hours Tested: 8.5 hrs. Production for Test Period Oil -Bbl: 137 Gas -MCF: 340 Water -Bbl: 1254 Choke Size: 176 Gas -Oil Ratio: 2488 Flow Tubing Press. 240psi Casinq Press: Calculated 24 -Hour Rate Oil -Bbl: 386 Gas -MCF: 961 Water -Bbl: 3542 Oil Gravity - API (corr): Form 10-407 Revised 11/2015 V%L �l<J�l L CONTINUED ON PAGE 2 RBDMS Lu' OCT2 U, r Submit ORIGINIAL On 28. CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No D If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1593 1593 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 7243 5838 information, including reports, per 20 AAC 25.071. TD( Kuparuk A Sand) 9350 5890 Formation at total depth: Ku aruk A K 2 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematics Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, r d ion or well test results, r 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Keith Herrin 263-4321 Email: Keith. E. Herrin co .com Printed Name: G. Eller Title: CTD Team Lead Signature: Phone: 263-4172 Date: \O- - INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled 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. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: 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 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange 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 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only Conoco'hillips AIwka. Inc, KUP PROD 500292148360 NIPPLE RIVER UNIT [PROD I act wr) 3F -12L1 / TD aro�a senemaao aow Annotation Depth (HKB) Entl Date Annotation Last Mod By End Date Last Tag: Rev Reason: ADD LATERALS lehallf 10/11/2016 HANGER, 32.7 casing strings Casing Description OD (in) ID (in) Top (HKB) Set Depth (HKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread LINER, Ll 2 3/8 1.992 7,659.8 9,350.0 5,890.6 4.60 L-80 ST L Liner Details Top (HKB) Top (TVD) (HKB) Top Incl (°) Item Des Com Nominal ID (jn) 7,659.81 5,864.51 88.30 1 BILLET Aluminum Liner Top Billet 0.000 Perforations & Slots Shot Den Top (ftKB) atm (HKB) Top (TVD) (HKB) Bum (TVD) (HKB) Zone Date (shots/ H) Type Co. 7,660.0 9,350.0 5,864.5 5,890.6 A-2, 3F-12 9/21/2016 SLOTS Alternating solid/slotted CONDUCTOR, 38.0-1150 pipe - 0.125' x 25' @ 4 circumferential adjacent rows Notes: General & Safety End Date Annotation NOTE: SURFACE; 37 0-3,292 4 GAS LIFT: 6,884.6 NIPPLE, 6,945.6 LOCATOR, 6,995.2 SEAL ASSY', 6,996.4 C r:. IPERF', 7,116.0-7,146.0^ 4 PRODUCTION, 35.0-7,539.9 LINER, 6,990.9-7,425.5 Liner Cement, 6,991.0 ftKB SLOTS, 7,162.0-9.4000 LINER, L1-03;7,161.7-9,4000 SLOTS; 7,370.0-9,350.0 LINER, L1-01; 7,369.59,350.0 T—f SLOTS, 7,660.0-9,350.0 LINER, Li; 7,659.8-9,350.0 — 3F-12 CTD Schematic 116" 62# H-40 shoe at 115' MD 3292' M D C -sand perfs (sgz'd) 7116'-7146' MD 3F-121-1-02, TO = 9250' MD 2%" slotted liner with aluminum billet TOL =751VMD, BOL =9250'MD TOWS at7179'MD 3F -12L1-03, TO = 9400' MD 2'/." slotted liner Mth deployment sleeve TOL = 7162' MD, BOL = 9400' MD 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" MMG SOV RKP latch @ 6885' RKB (6891' PDC) 3-1/2" X -nipple @ 6946' RKB (6952' PDC) (2.813" min ID) Baker 80/40 seal assembly @ 6997' RKB (7003' PDC) Baker ZXP packer @ 6991' RKB (6997' PDC) Baker Flexlock liner hanger at 7011' RKB (7017' PDC) Baker type 1 landing collar @ 7338' RKB (7344' PDC) 41/2", scab liner cemented in place Two KO joints 7131'- 7213' RKB (7137'- 7219' PDC) No centralizers on these 2 kickout joints. All other 4%" joints to be centralized. A-sand7246' - 280'erfs (sgz'd) 7246' - 7280' MD A -sand reperf 7243' - 7250' MD 7" 26# J-55 shoe at 7540' MD 3F-121-1-01, TO = 9352' MD 2%" slotted liner with aluminumbillet TOL = 7370' MD, BOL = 9350' MD 3F-121-1, TO = 9350' MD 2'/." slotted liner with aluminum billet TOL = 7660' MD, BOL = 9350' MD Operations Summary (with Timelog Depths) 3F-12 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (WB) 9/14/2016 9/14/2016 4.40 PROD1 WHPST SVRG P Rig Commissioned and Accepted at 0.0 0.0 00:00 04:24 00:00, Commissioned and function tested rig equip; McCoy Power Tongs, Little Jerks and Tubing Cutters. 9/14/2016 9/14/2016 4.25 PROD1 WHPST PULD P PJSM, Make up and PD window 0.0 76.8 04:24 08:39 milling BHA#1, 2.80" DSM on Weatherford 1' fixed bend motor, make Crew change, continue to PD BHA. 9/14/2016 9/14/2016 2.02 PROD1 WHPST TRIP P Test Baker Tools, wait on BHI town, 76.8 100.0 08:39 10:40 RIH to 100 ft to test HOT. Crew torqued pillow blocks on reel. 9/14/2016 9/14/2016 4.50 PROD1 WHPST TRIP P RIH, tie-in to K1 marker, +6 ft, 100.0 7,182.0 10:40 15:10 circulate hole over to 8.6 ppg (lite) Flo Pro mud, close EDC, dry tag TOW at 7180 ft. 9/14/2016 9/14/2016 1.83 PROD1 WHPST WPST P Pick up 10 ft, establish parameters, 7,182.0 7,183.0 15:10 17:00 8.1 K CWT, 0 WOB, 3700 psi CP, 540 psi dP, see pinch point at 7182 ft, 0.5K WOB, 620 psi dP, milling at 1 fph 9/14/2016 9/14/2016 1.75 PROD1 WHPST TRIP T Orienenting tool failure, start BHI NPT 7,183.0 101.0 17:00 18:45 9/14/2016 9/14/2016 3.25 PROD1 WHPST PULD T PJSM, PUD BHA#1, Lay down and 101.0 0.0 18:45 22:00 trouble shoot 9/14/2016 9/14/2016 1.50 PROD1 WHPST SVRG P Inspect reel hub bolts and reel saddle 0.0 0.0 22:00 23:30 clamps 9/14/2016 9/15/2016 0.50 PROD1 WHPST PULD T PJSM, PD BHA #2 window milling bha 0.0 76.9 23:30 00:00 with 1° AKO Weatherford fixed bend motor, 2.79 string reamer and 2.80 Dimond window mill 9/15/2016 9/15/2016 2.00 PROD1 WHPST PULD T Continue PD BHA #2, Surface test 0.0 76.9 00:00 02:00 tool - Good test, Strip on well, Tag up and reset counters 9/15/2016 9/15/2016 1.40 PROD1 WHPST TRIP T Trip in hole, EDC is open, Pumping 76.9 7,045.0 02:00 03:24 point 3 9/15/2016 9/15/2016 0.30 PROD1 WHPST DLOG T Log K1 for +6 foot correction, Shut 7,045.0 7,070.0 03:24 03:42 EDC, PUW=29K 9/15/2016 9/15/2016 0.30 PROD1 WHPST TRIP T RIH to whipstock and dry tag, PUH, 7,070.0 7,182.0 03:42 04:00 PUW=33K 9/15/2016 9/15/2016 10.20 PROD1 WHPST WPST P End BHI NPT, Pumps on 1.4 BPM @ 7,182.0 7,189.0 04:00 14:12 3500 PSI FS, BHP=3475, Call pinch point @ 7181.6 ft. OB milling window, 9/15/2016 9/15/2016 2.60 PROD1 WHPST WPST P 7189', Call WM 4 1/2' exit. String 7,189.0 7,192.0 14:12 16:48 reamer exit @ 7190 ft 9/15/2016 9/15/2016 2.30 PROD1 WHPST WPST P Drilling rathole, Geo has confirmed 7,192.0 7,205.0 16:48 19:06 formation in sample. 9/15/2016 9/15/2016 4.00 PROD1 WHPST REAM P TD rathole begin reaming passes, saw 7,205.0 7,205.0 19:06 23:06 motor work on initial pass as drilled down @ 7182 ft and each time going past. Got less at each pass. Back ream 30° left and right from as drilled then 180° from as drilled all in up direction. As drilled @ 24° moving down. Dry drift window clean 9/15/2016 0.90 PROD1 WHPST TRIP P POOH with EDC open, Pumping 1.4 7,205.0 3,783.0 23:06 19/16/2016 00:00 1 1 BPM @ 3104 Circ pressure Page 1/13 Report Printed: 10/3/2016 Operations Summary (with Timelog Depths) 3F-12 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dar (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 9/16/2016 9/16/2016 1.00 PROD1 WHPST TRIP P Continue out of well 3,783.0 97.0 00:00 01:00 9/16/2016 9/16/2016 1.50 PROD1 WHPST PULD P At surface, PJSM, PUD BHA #3, 97.0 0.0 01:00 02:30 window milling BHA with 1' Weatherford motor 9/16/2016 9/16/2016 1.00 PROD1 WHPST PULD P Lay down BHI tools and motor. 0.0 0.0 02:30 03:30 Gauged mill out @ 2.80" Go, 2.79" No go 9/16/2016 9/16/2016 1.00 PROD1 WHDBOP RURD P Make up nozzle and jet stack - roll coil 0.0 0.0 03:30 04:30 to water for BOPE test 9/16/2016 9/16/2016 10.50 PROD1 WHDBOP BOPE P PJSM, Start AOGCC required weekly 0.0 0.0 04:30 15:00 full BOPE test, Test witness waived by Jeff Jones, AOGCC. Shell test to 500 psi, back on MP at 11:50, 890 psi WHIP, Finished BOPE test at 15:00 hrs, no failures. Inspect injector sump, looks good, Blowdown choke, displace coil from FW to usedFloPro mud. 9/16/2016 9/16/2016 2.00 PROD1 DRILL SVRG P Inspect injector sump, looks good, 0.0 0.0 15:00 17:00 Blowdown choke, displace coil from FW to used FloPro mud. 9/16/2016 9/16/2016 1.00 PROD1 DRILL PULD P PJSM, Install checks in UQC 0.0 0.0 17:00 18:00 9/16/2016 9/16/2016 3.90 PROD1 DRILL PULD P PJSM on M/U BHA and load in PDL. 0.0 72.2 18:00 21:54 PD build section BHA #3 with 2.2° motor bend and RR Hughes Bi - Center, Make up to coil and surface test 9/16/2016 9/16/2016 1.70 PROD1 DRILL TRIP P RIH, EDC open, stop at 7023 and 72.2 7,025.0 21:54 23:36 trouble shoot HOT for lack of motion. Told it might be due to high motor bend 9/16/2016 9/16/2016 0.30 PROD1 DRILL DLOG P Log K1 for +6'correction, PUW=32K, 7,025.0 7,063.0 23:36 23:54 Closed EDC and trip 9/16/2016 9/17/2016 0.10 PROD1 DRILL TRIP P RIH to drill 7,063.0 7,135.0 23:54 00:00 9/17/2016 9/17/2016 0.30 PROD1 DRILL TRIP P Continue in to drill, Clean pass 7,135.0 7,205.0 00:00 00:18 through window, Bring on pumps, Orientor will not turn, Amps up 9/17/2016 9/17/2016 1.70 PROD1 DRILL TRIP T Unable to do anything with orientor, 7,205.0 85.3 00:18 02:00 Trip out of well, Open EDC, Begin BHI NPT 9/17/2016 9/17/2016 2.00 PROD1 DRILL PULD T PJSM, PUD BHA #3, Swap out HOT 85.3 0.0 02:00 04:00 and DGS 9/17/2016 9/17/2016 2.50 PROD1 DRILL PULD T PJSM, PD BHA #4, Build section BHA 0.0 85.3 04:00 06:30 with 2.2° AKO motor and RR HCC Bi center 9/17/2016 9/17/2016 2.00 PROD1 DRILL TRIP T RIH, EDC open, End BHI NPT at 85.3 7,205.0 06:30 08:30 08:30 9/17/2016 9/17/2016 0.25 PROD1 DRILL DLOG P Log K1 for +6 ft correction, close ECD, 7,205.0 7,205.0 08:30 08:45 dry drift window to 7197 ft, clean, bring pumps to 1.8 bpm, slowed pump rate to 1.6 BPM, running over shakers, PUW 30K, 3840 psi FS, 404 psi dP 9/17/2016 9/17/2016 0.75 PROD1 DRILL DRLG P OBD at 7205 ft w/ 2.2° AKO motor, 7,205.0 7,224.0 08:45 09:30 new mud at bit 09:30 am, drill build section at 1.6 BPM, 4045 psi, 3720 psi BHP. Page 2/13 Report Printed: 10/3/2016 Operations Summary (with Timelog Depths) 3F-12 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 9/17/2016 9/17/2016 7.30 PROM DRILL DRLG P 7224', Drill, 1.6 BPM @ 3875 PSI FS, 7,224.0 7,530.0 09:30 16:48 BHP=3690 9/17/2016 9/17/2016 0.40 PROM DRILL WPRT P TD Build section @ 7530, Wipe 7,530.0 7,040.0 16:48 17:12 uphole to log K1 9/17/2016 9/17/2016 0.20 PROM DRILL DLOG P Log K1 for 1.5' correction 7,040.0 7,060.0 17:12 17:24 9/17/2016 9/17/2016 0.10 PROD1 DRILL WPRT P RIH to log RA and tie in whipstock 7,060.0 7,200.0 17:24 17:30 9/17/2016 9/17/2016 0.10 PROM DRILL DLOG P Log RA @ 7186.5, TOWS=7179, 7,200.0 7,218.0 17:30 17:36 BOWS=7192 9/17/2016 9/17/2016 1.40 FROM DRILL TRIP P Start trip out of well, Open EDC and 7,218.0 144.0 17:36 19:00 jog 4 1/2 below tubing tail @ 7036 9/17/2016 9/17/2016 2.00 PROM DRILL PULD P At surface, PJSM, PUD BHA # 4 144.0 0.0 19:00 21:00 9/17/2016 9/17/2016 2.40 PROD1 DRILL PULD P PJSM, PD BHA #5, lateral section 0.0 72.0 21:00 23:24 with .5° motor and re run HCC bi center. Surface test tool 9/17/2016 9/18/2016 0.60 PROM DRILL TRIP P RIH with BHA#5, EDC open 72.0 2,357.0 23:24 00:00 9/18/2016 9/18/2016 0.90 PROM DRILL TRIP P Continue tripping in hole to drill 2,357.0 7,035.0 00:00 00:54 9/18/2016 9/18/2016 0.20 PROM DRILL DLOG P Log K1 for +5' correction, Close EDC, 7,035.0 7,051.0 00:54 01:06 PUW=33K 9/18/2016 9/18/2016 0.30 FROM DRILL TRIP P Continue in well, Clean pass through 7,051.0 7,530.0 01:06 01:24 window and high gamma area, Tag up at 7530 9/18/2016 9/18/2016 2.80 PROM DRILL DRLG P 7530', Drill ahead L1 lateral @ 1.73 7,530.0 7,960.0 01:24 04:12 BPM @ 4000 PSI FS, BHP=3629, WHP=575 9/18/2016 9/18/2016 0.50 PROM DRILL WPRT P Wiper trip to 7230', PUW=35K, Clean 7,960.0 7,960.0 04:12 04:42 trip up and down 9/18/2016 9/18/2016 3.05 PROM DRILL DRLG P 7960', Drill, 1.72 BPM @ 4150 PSI 7,960.0 8,360.0 04:42 07:45 FS, BHP=3686, WHP=470, RIW=9K, pump 5 x 5 BBL Hi/Lo vis sweep 9/18/2016 9/18/2016 0.75 PROM DRILL WPRT P Wiper trip to 7640'(720 ft), PUW=35K, 8,360.0 8,360.0 07:45 08:30 Clean trip up and down, no hole problems observed. 9/18/2016 9/18/2016 4.75 PROM DRILL DRLG P 8360' Drill ahead, 1.72 BPM @ 4250 8,360.0 8,747.0 08:30 13:15 PSI FS, BHP=3686, WHP=440, RIW=9K, pump 5 x 5 BBL Hi/Lo vis sweep, sweep at nozzel. 9/18/2016 9/18/2016 1.00 FROM DRILL WPRT P Lost communication with LWD tools, 8,747.0 7,180.0 13:15 14:15 tool face at 90° LOHS, when tool went short. Line to collector tested good, Continue with long wiper trip to window, perform jog at tubing tail. 9/18/2016 9/18/2016 2.00 PROM DRILL TRIP T Check cable from collector to 7,180.0 74.0 14:15 16:15 pressure bulkhead, indicates downhole short POOH. 9/18/2016 9/18/2016 0.75 PROM DRILL PULD T PJSM, PUD BHA#5, Break off injector 74.0 74.0 16:15 17:00 and test tool, All good with tool, 9/18/2016 9/18/2016 2.40 FROM DRILL CTOP T Test E -line - shorted out, remove UQC 74.0 74.0 17:00 19:24 and test - no good, Found bad section of wire above CTC. Prep for slack mgmt. Plan to cut 100' of wire. Cut off CTC connector and find debris (Washer) in connector. Confer with town Page 3/13 Report Printed: 10/3/2016 Operations Summary (with Timelog Depths) 3F-12 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (WB) End Depth (ftKB) 9/18/2016 9/18/2016 1.00 PROD1 DRILL PULD T Complete PUD BHA #5 74.0 0.0 19:24 20:24 9/18/2016 9/19/2016 3.60 PROM DRILL CTOP T Boot E -Line, Stab on and reverse 0.0 0.0 20:24 00:00 circulate coil, Cut 56' pipe and find wire. Wire still not testing @ 4.0 Mohmes. make two more cuts, 12' wire. Now at 3.9 Mohmes 9/19/2016 9/19/2016 0.60 PROM DRILL CTOP T PJSM, Lock out CT storage reel and 0.0 0.0 00:00 00:36 remove pressure bulk head for inspection. All good, reinstall 9/19/2016 9/19/2016 2.70 PROM DRILL CTOP T Cut 40' coil / E -line and test. 0.0 0.0 00:36 03:18 9.7MOhms, Cut 50' Coil / E -line test @ 10.3 MOhms, Cut 50' coil E -line. Test @ 10.4 MOhmes 50.9 Ohms continuity. Cut totals 250' coil, 195' E - line 9/19/2016 9/19/2016 1.20 PROM DRILL CTOP T PJSM, Prep coil for CTC and install 0.0 0.0 03:18 04:30 9/19/2016 9/19/2016 0.20 PROM DRILL CTOP T Pull Test CTC to 35K - Good test 0.0 0.0 04:30 04:42 9/19/2016 9/19/2016 0.75 PROD1 DRILL CTOP T Head up a line 0.0 0.0 04:42 05:27 9/19/2016 9/19/2016 6.55 PROM DRILL CTOP T PJSM. Repair parted SL wire in the 0.0 0.0 05:27 12:00 ODS PDL, dissassemble entire PDL back to the stuffing box to find the wire, cut 1' of wire, re -tie rope socket, MU SL tool string, reassemble PDL, pull test to 700 psi. 9/19/2016 9/19/2016 1.50 PROM DRILL PULD T PJSM, PD BHA #6, lateral section 0.0 72.0 12:00 13:30 with .5° motor and re run HCC bi center. Surface test tool 9/19/2016 9/19/2016 2.00 PROM DRILL TRIP T RIH, EDC open, pumping MP, End 72.0 7,025.0 13:30 15:30 NPT @15:00 9/19/2016 9/19/2016 0.25 PROM DRILL DLOG P Log K1 for +5 ft correction, close ECD. 7,025.0 7,056.0 15:30 15:45 9/19/2016 9/19/2016 2.25 PROM DRILL TRIP P Dry drift thru window was clean, bring 7,065.0 8,720.0 15:45 18:00 pumps to 0.5 BPM, 2025 psi, 669 psi WH, Had to work pipe at 8355' to 8385', wiper up hole to 8250', max pull 42K, work down to 8394', work pipe to 8422', work pipe to 8410', able to get coil moving down, pump 5 x 5 Lo/Hi vis sweep. 9/19/2016 9/19/2016 1.25 PROM DRILL WPRT P Chase sweep at 1.7 bpm thru tight 8,720.0 7,040.0 18:00 19:15 area from 8400' to 8340', max 42K, pull back to TT, circulate BU. 9/19/2016 9/19/2016 0.25 PROM DRILL DLOG P Log K1 for+0.5' correction. 7,040.0 7,050.0 19:15 19:30 9/19/2016 9/19/2016 0.75 PROM DRILL TRIP P RIH to drill, saw slight bobbles from 7,050.0 8,747.0 19:30 20:15 8340' to 8430', PUW= 36K at 8700'. 9/19/2016 9/19/2016 3.50 PROM DRILL DRLG P 8747', Drill L1 lateral, geo steer to 92° 8,747.0 9,020.0 20:15 23:45 @ 1.43 BPM, 3450 psi, 340 psi Diff, 471 psi WH free spin. 8792' bring rate to 1.8 bpm, 4260 psi FS, 459 psi dP 9/19/2016 9/20/2016 0.25 PROM DRILL WPRT P Begin short wiper trip 9,020.0 8,500.0 23:45 00:00 9/20/2016 9/20/2016 0.25 PROM DRILL WPRT P Finish short wiper to bottom, slight 8,500.0 9,020.0 00:00 00:15 stacking in problem area 8340 to 8430 RIH @ 35FPM @ 1.2 BPM. No setdowns Page 4/13 Report Printed: 10/3/2016 Operations Summary (with Timelog Depths) 3F-12 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth. (ftKB) 9/20/2016 9/20/2016 0.75 PROD1 DRILL DRLG P 9020', Drill ahead, 1.8 BPM @ 4400 9,020.0 9,093.0 00:15 01:00 PSI FS, BHP=3865 9/20/2016 9/20/2016 0.50 PROD1 DRILL TRIP T Orienter has become unresponsive, 9,093.0 8,800.0 01:00 01:30 Surface trouble shoot - No good, Pump 5 X 5 Sweeps 9/20/2016 9/20/2016 2.50 PROD1 DRILL TRIP T Trip out for orienter, Slight overpull 8,800.0 79.0 01:30 04:00 and motor work @ 8386 to 8380, Open EDC @ 7134 9/20/2016 9/20/2016 2.30 PROD1 DRILL PULD T At surface, PJSM PUD BHA #6. 79.0 0.0 04:00 06:18 Unstab and injector and test BHA. Orinter will not test, Test wire, Meg down to 2.3 MOhms. Continue PUD 9/20/2016 9/20/2016 0.80 PROD1 DRILL PULD T Reconfigure BHA 0.0 0.0 06:18 07:06 9/20/2016 9/20/2016 0.60 PROD1 DRILL SVRG P PT ODS PDL to 2500 PSI 0.0 0.0 07:06 07:42 9/20/2016 9/20/2016 1.90 PROD1 DRILL PULD T PJSM, M/U BHA #7 lateral drilling 0.0 72.2 07:42 09:36 BHA with .5° motor and re run bit, PD, make up to coil and surface test HOT and BHA 9/20/2016 9/20/2016 1.50 PROD1 DRILL TRIP T Trip in hole, EDC open Pumping 72.2 7,035.0 09:36 11:06 9/20/2016 9/20/2016 0.20 PROD1 DRILL DLOG T Log K1 for+5', Close EDC 7,035.0 7,057.0 11:06 11:18 9/20/2016 9/20/2016 1.00 PROD1 DRILL TRIP T Continue trip in hole, clean pass 7,057.0 9,093.0 11:18 12:18 through window Tag up @ 7257, PU run through clean, Tag up @ 8369', PU RIH at reduced pump rate go through clean 9/20/2016 9/20/2016 0.60 PROD1 DRILL DRLG P 9093', Drill, 1.76 BPM @ 4350 PSI 9,093.0 9,110.0 12:18 12:54 FS, BHP=3830, RIW=1K END BHI NPT=10 Hrs 9/20/2016 9/20/2016 0.30 PROD1 DRILL WPRT P Pull 200' wiper for poor weight 9,110.0 9,110.0 12:54 13:12 transfer, PUW=36K 9/20/2016 9/20/2016 1.20 PROD1 DRILL DRLG P 9110% Drill, 1.8 BPM @ 4295 PSI FS, 9,110.0 9,180.0 13:12 14:24 BHP=3790 9/20/2016 9/20/2016 0.50 PROD1 DRILL WPRT P 300' wiper for weight transfer, 9,180.0 9,180.0 14:24 14:54 PUW=43K, RIW=-1K 9/20/2016 9/20/2016 1.90 PROD1 DRILL DRLG P 9180', Drill, 1.45 BPM @ 3760 PSI 9,180.0 9,320.0 14:54 16:48 FS, BHP=3765, Increased coil surface weight with reduction in pump rate 9/20/2016 9/20/2016 0.20 PROD1 DRILL WPRT P BHA wiper, PUW=43k 9,320.0 9,320.0 16:48 17:00 9/20/2016 9/20/2016 0.25 PROD1 DRILL DRLG P BOBD, 1.49 BPM @ 3880 psi FS, 9,320.0 9,321.0 17:00 17:15 BHP 3905 psi, ROP 5 9/20/2016 9/20/2016 0.25 PROD1 DRILL WPRT P 300' wiper for weight transfer, 9,321.0 9,321.0 17:15 17:30 PUW=46k 9/20/2016 9/20/2016 0.50 PROD1 DRILL DRLG P BOBD, 1.5 BPM @ 3880 psi FS, BHP 9,321.0 9,350.0 17:30 18:00 3905 psi, ROP 72, WOB 1 k. Drilled to TD of 9,350'. 9/20/2016 9/20/2016 0.10 PROD1 DRILL WPRT P PUH for swab wiper slowly to allow 9,350.0 9,330.0 18:00 18:06 sweep time to reach the bit, PUW=38k 9/20/2016 9/20/2016 0.90 PROD1 DRILL CIRC P Differentially stuck, work pipe, pump 9,330.0 9,320.0 18:06 19:00 sweep around @ 1.8 BPM, 4500 psi pump pressure, coil in tension with CTSW=55k. Relax coil, 0 BPM, drop BHP from 3855 psi target to 3420 psi, pulled free. Max CTSW=65k. Page 5/13 Report Printed: 10/3/2016 Operations Summary (with Timelog Depths) K>f 3F-12 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth. (ftKB) 9/20/2016 9/20/2016 1.75 PROD1 DRILL WPRT P Swab wiper trip. Jogged above 4-1/2" 9,320.0 2,994.0 19:00 20:45 scab liner. Opened EDC @ 7082' MD. Cont. POOH for swab wiper pumping 1.8 BPM following MP schedule. 9/20/2016 9/20/2016 0.75 PROD1 DRILL WPRT P Injector stopped when speed was 2,994.0 2,994.0 20:45 21:30 decreased from 120 FPM to 110 FPM. Suspect injector torque limit was exceeded. Inspected injector and coil tubing. 9/20/2016 9/20/2016 1.20 PROD1 DRILL WPRT P Cont POOH following MP schedule. 2,994.0 72.0 21:30 22:42 Jogged @ 360' MD. Tagged up. Reset depth. 9/20/2016 9/21/2016 1.30 PROD1 DRILL WPRT P RBIH to confirm TD. 72.0 5,861.0 22:42 00:00 9/21/2016 9/21/2016 0.25 PROD1 DRILL WPRT P Cont RIH with open EDC. 5,861.0 7,040.0 00:00 00:15 9/21/2016 9/21/2016 0.25 PROD1 DRILL DLOG P K1 tie-in, +5' correction. Close EDC. 7,040.0 7,056.0 00:15 00:30 9/21/2016 9/21/2016 1.00 PROD1 DRILL WPRT P Cont RIH. Tagged up @ 8,370'. 7,056.0 9,350.0 00:30 01:30 Lowered pump rate to 0.3 BPM, passed through. Cont RIH. Confirmed TD @ 9,350'. 9/21/2016 9/21/2016 2.90 PROD1 DRILL DISP P POOH laying in 36 bbl liner running 9,350.0 78.0 01:30 04:24 pill followed by 12.0 ppg NaBr KWF. Paint TD flag PINK @ 7,500'. Cont POOH. Paint WINDOW flag WHITE @ 5,300'. 9/21/2016 9/21/2016 0.50 PROD1 DRILL OWFF P Tag up, perform 30 minute no flow 78.0 78.0 04:24 04:54 9/21/2016 9/21/2016 1.50 PROD1 DRILL PULD P PJSM, Lay down BHA #7 (HCC bi- 78.0 0.0 04:54 06:24 center bit graded 1-1 out) 9/21/2016 9/21/2016 2.00 COMPZI CASING PUTB P Prep floor to run liner, Inspect top 0.0 0.0 06:24 08:24 drive and injector 9/21/2016 9/21/2016 1.60 COMPZ1 CASING PUTB P Prep and inspect new tongs, Practice 0.0 0.0 08:24 10:00 working with safety joint 9/21/2016 9/21/2016 4.20 COMPZ1 CASING PUTB P M/U BHA#8, L1 liner with non ported 0.0 1,690.2 10:00 14:12 bullnose, 10' pup, 54 Jts slotted liner and liner top aluminum billet 9/21/2016 9/21/2016 1.80 COMPZ1 CASING PULD P PJSM, Replace checks, M/U liner to 1,690.2 1,734.4 14:12 16:00 coil track, M/U to injector and surface test 9/21/2016 9/21/2016 2.50 COMPZ1 CASING RUNL P RIH, BHA#8 L1 Liner with non ported 1,734.4 9,350.0 16:00 18:30 bullnose, 1 x 10' pup, 54 Jts slotted 2 3/8" liner, and aluminum liner top billet. Set depth to flag, +2.8' correction. Cont RIH to bottom. 9/21/2016 9/21/2016 1.50 COMPZ1 CASING TRIP P Weight check, PUW=42k. Release 9,350.0 57.0 18:30 20:00 liner at planned depth (TOL @ 7,660'). POOH. 9/21/2016 9/21/2016 0.50 COMPZ1 CASING OWFF P Tag -up, flow check for 30 mins. Dead 57.0 57.0 20:00 20:30 well. 9/21/2016 9/21/2016 0.70 COMPZ1 CASING PULD P PJSM, LD BHA #8. Pull floats from 57.0 0.0 20:30 21:12 UQC. SIMOPS: Valve crew greased/functioned swab & wing valves. Page 6113 Report Printed: 10/3/2016 F;. Operations Summary (with Timelog Depths) 3F-12 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time our (hr) Phase Op Code Activity. Code Time P=T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/21/2016 9/21/2016 0.80 PROD2 WHDBOP RURD P Swap coil to fresh water, jet BOP 57.0 0.0 21:12 22:00 stack. 9/21/2016 9/21/2016 1.50 PROD2 WHDBOP PRTS P Test inner reel valve & stripper to 0.0 0.0 22:00 23:30 250 / 4000 psi. 9/21/2016 9/22/2016 0.50 PROD2 WHDBOP BOPE P PJSM, full BOP test. Perform 0.0 0.0 23:30 00:00 successful shell test to 250 / 4000 psi. Test witness waived by Lou Grimaldi, AOGCC 9/22/2016 9/22/2016 7.60 PROD2 WHDBOP BOPE P Performed full BOPE testing to 250 / 0.0 0.0 00:00 07:36 4000 psi (annular 2500 psi). **AOGCC inspector, Lou Grimaldi, waived witness via phone @ 19:20 on 9/21/2016.** 9/22/2016 9/22/2016 1.00 PROD2 WHDBOP RURD P Displace CT back to 8.6 Flo Pro 0.0 0.0 07:36 08:36 9/22/2016 9/22/2016 1.00 PROD2 WHDBOP SVRG P Perform emergency lighting system 0.0 0.0 08:36 09:36 check around rig 9/22/2016 9/22/2016 0.90 PROD2 WHDBOP RURD P Secure inner reel iron 0.0 0.0 09:36 10:30 9/22/2016 9/22/2016 1.30 PROD2 STK PULD P PJSM, M/U BHA #9 with .8° motor and 0.0 72.2 10:30 11:48 RB Hyc bit, Install checks in UQC. Make up injector and test tool 9/22/2016 9/22/2016 1.40 PROD2 STK TRIP P Tag up, set counters, Trip in well, EDC 72.2 7,035.0 11:48 13:12 open, Pumping 9/22/2016 9/22/2016 0.10 PROD2 STK DLOG P Log K1 for +45 correction 7,035.0 7,061.0 13:12 13:18 9/22/2016 9/22/2016 0.10 PROD2 STK TRIP P Trip into just above window 7,061.0 7,158.0 13:18 13:24 9/22/2016 9/22/2016 0.70 PROD2 STK DISP P Displace 12PPG brine to used 7,158.0 7,158.0 13:24 14:06 8.6PPG FloPro, Shut EDC 9/22/2016 9/22/2016 0.40 PROD2 STK TRIP P Trip into hole, Clean pass through 7,158.0 7,660.0 14:06 14:30 window, Tag billet @ 7660', PUW=33K 9/22/2016 9/22/2016 1.40 PROD2 STK KOST P Mill kick off liner top billet, 7659.2 start 7,660.0 7,663.0 14:30 15:54 milling off liner top billet. 1.7 BPM @ 4150 PSI FS, BHP=3670 9/22/2016 9/22/2016 0.80 PROD2 DRILL DRLG P 7663', Drill, 1.7 BPM @ 4150 PSI FS, 7,663.0 7,700.0 15:54 16:42 BHP=3670, RIW=12.4K with 1.5K DHWOB 9/22/2016 9/22/2016 0.20 PROD2 DRILL WPRT P Dry drift billet area, clean trip up and 7,700.0 7,700.0 16:42 16:54 down past billet, NEW MUD AT BIT 7700'. 9/22/2016 9/22/2016 3.30 PROD2 DRILL DRLG P 7700', Drill, 1.7 BPM @ 3870 PSI FS, 7,700.0 8,060.0 16:54 20:12 BHP=3814. Couple stalls @ 7,949'. 9/22/2016 9/22/2016 0.60 PROD2 DRILL WPRT P Wiper trip to 7250'. PUW=37k. Clean 8,060.0 8,060.0 20:12 20:48 up & down. 9/22/2016 9/22/2016 3.00 PROD2 DRILL DRLG P BOBD, 1.8 BPM @ 4235 psi FS, BHP 8,060.0 8,460.0 20:48 23:48 3710 psi, CTSW 8k, WOB 1.5k, ROP 133 9/22/2016 9/23/2016 0.20 PROD2 DRILL WPRT P Wiper to window to perform annular 8,460.0 8,195.0 23:48 00:00 friction calibration with mud system #2 and tie-in. PUW=37k. 9/23/2016 9/23/2016 0.90 PROD2 DRILL WPRT P Cont wiper trip up from 8,165' up to 8,165.0 7,040.0 00:00 00:54 7,040'. Jog back in above the 4-1/2" scab liner. 9/23/2016 9/23/2016 0.20 PROD2 DRILL DLOG P Log K1, +1' correction. 7,040.0 7,058.0 00:54 01:06 Page 7/13 Report Printed: 10/3/2016 Operations Summary (with Timelog Depths) 3F-12 ._ . Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start TimeEnd Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 9/23/2016f05:18 /23/2016 0.50 PROD2 DRILL WPRT P Wiper back down. Measure annular 7,058.0 8,460.0 01:06 1:36 friction with mud system #2. RIW=9.9k 9/23/2016/23/2016 3.70 PROD2 DRILL DRLG P BOBD, 1.8 BPM @ 4215 psi FS, BHP 8,460.0 8,860.0 01:36 3946 psi, CTSW 7.7k WOB 1.3k, ROP 118 9/23/2016 9/23/2016 0.70 PROD2 DRILL WPRT P Wiper trip to 7860', PUW=37K 8,860.0 8,860.0 05:18 06:00 9/23/2016 9/23/2016 3.50 PROD2 DRILL DRLG P 8860, Drill, 1.8 BPM @ 4315 PSI FS, 8,860.0 9,129.0 06:00 09:30 BHP=3765 9/23/2016 9/23/2016 0.10 PROD2 DRILL WPRT P 9129 Stacking, pull BHA wiper, 9,129.0 9,129.0 09:30 09:36 PUW=36K 9/23/2016 9/23/2016 1.50 PROD2 DRILL DRLG P 9129', Drill, 1.7 BPM @ 419OPSI FS, 9,129.0 9,260.0 09:36 11:06 BHP=3895 9/23/2016 9/23/2016 0.70 PROD2 DRILL WPRT P 9260', 1000' wiper, PUW=39K 9,260.0 9,260.0 11:06 11:48 9/23/2016 9/23/2016 1.10 PROD2 DRILL DRLG P 9260', Drill, 1.62 BPM @3960 PSI FS, 9,260.0 9,350.0 11:48 12:54 BHP=3848 9/23/2016 9/23/2016 2.70 PROD2 DRILL WPRT P 9350', Reached TD, Pump 10 X 10 9,350.0 72.2 12:54 15:36 Sweeps, Chase to swab 9/23/2016 9/23/2016 3.00 PROD2 DRILL WPRT P At surface, Reset counters, Trip in to 72.2 7,040.0 15:36 18:36 tie in and confirm TD. ARP making injector adjustments while RIH. 9/23/2016 9/23/2016 0.20 PROD2 DRILL DLOG P Tie in to K1, +8' correction. PUW=30k. 7,040.0 7,061.0 18:36 18:48 Close EDC. 9/23/2016 9/23/2016 0.90 PROD2 DRILL WPRT P Cont RIH. Tag TD @ 9,352'. 7,061.0 9,352.0 18:48 19:42 9/23/2016 9/23/2016 1.30 PROD2 DRILL TRIP P PUH while mixing liner pill and 9,352.0 8,227.0 19:42 21:00 weighting up KWF. PUW=32k. 9/23/2016 9/23/2016 2.25 PROD2 DRILL DISP P RBIH to TD and POOH pumping 37 8,227.0 72.2 21:00 23:15 bbl liner running pill (with 2 Ib/bbl beads) following by 12.0 ppg NaBr KWF. Paint YELLOW TD flag @ 7,200'. Cont POOH. Paint WHITE WINDOW flag @ 5,100'. Cont POOH with L1-01 lateral drilling BHA #9. 9/23/2016 9/23/2016 0.50 PROD2 DRILL OWFF P Flow check well. 72.2 72.2 23:15 23:45 9/23/2016 9/24/2016 0.25 PROD2 DRILL PULD P PJSM, LD BHA #9. 72.2 0.0 23:45 00:00 9/24/2016 9/24/2016 1.50 PROD2 DRILL PULD P LD BHA #9 (HYC Duraforce Edge Bi 72.2 0.0 00:00 01:30 center Bit 3-1). 9/24/2016 9/24/2016 2.50 COMPZ2 CASING PUTB P Remove checks from UQC. Mega test 0.0 0.0 01:30 04:00 insulation of coil line (0.66 Mohms). Prep floor to run L1-01 liner. Troubleshoot skate controls. Practice picking up safety joint. 9/24/2016 9/24/2016 6.80 COMPZ2 CASING PUTB P P/U L1-01 liner, Non ported bullnose, 0.0 2,024.0 04:00 10:48 6' Pup, 64 Jts slotted liner, aluminum liner top billet, M/U to coil track (BHA #10). Stab on injector and surface test tool, Tag up and set counters 9/24/2016 9/24/2016 1.40 COMPZ2 CASING RUNL P Trip in well, EDC shut. Pumping min 2,024.0 7,121.0 10:48 12:12 rate 9/24/2016 9/24/2016 0.10 COMPZ2 CASING DLOG P Tie into flag for+4.2' correction, 7,121.0 7,125.0 12:12 12:18 1 PUW=34K Page 8/13 Report Printed: 10/3/2016 Operations Summary (with Timelog Depths) 3F-12 ..E.Z , , , Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 9/24/2016 9/24/2016 1.40 COMPZ2 CASING RUNL P Continue in with liner, clean pass 7,125.0 9,352.0 12:18 13:42 through window, No stacking in build section, Had to work through 8940 to 9000 then hard push from 9150 to TD 9/24/2016 9/24/2016 1.60 COMPZ2 CASING TRIP P Pumps on 1.5 BPM release from liner, 9,352.0 50.0 13:42 15:18 PUW=33K, Remove liner length left in hole, Trip out 9/24/2016 9/24/2016 0.50 COMPZ2 CASING OWFF P Perform 30 Min Flow check 50.0 50.0 15:18 15:48 9/24/2016 9/24/2016 0.70 COMPZ2 CASING PULD P PJSM, Lay down BHA #10 L1-01 liner 50.0 0.0 15:48 16:30 running tools 9/24/2016 9/24/2016 1.75 PROD3 STK PULD P PJSM, P/U BHA #11 L1-02 Build turn 0.0 72.2 16:30 18:15 section BHA with 1.2° AKO Motor and RR Hughes Bi Center. Surface test tool. Open EDC. 9/24/2016 9/24/2016 1.50 PROD3 STK TRIP P RIH BHA #11. 72.2 7,040.0 18:15 19:45 9/24/2016 9/24/2016 0.10 PROD3 STK DLOG P Tie in @ K1, +3.5' correction. 7,040.0 7,062.0 19:45 19:51 9/24/2016 9/24/2016 1.10 PROD3 STK TRIP P Cont RIH. Displace 12.0 ppg KWF 7,062.0 7,370.0 19:51 20:57 with 8.6 ppg FloPro. Close EDC. Check weight, PUW=31 k. Cont. RIH through window. Dry tag @ 7,370'. PUH, swap flow path through Choke B due to fluctuating Choke A. 9/24/2016 9/24/2016 0.80 PROD3 STK KOST P Start pumps, RBIH. Time drill 1 ft/hr, 7,370.0 7,371.5 20:57 21:45 RIH 0.3', auto drill 1-2 ft/hr. 9/24/2016 9/24/2016 0.75 PROD3 STK KOST P Time drill 2-3 ft/hr. 7,371.5 7,373.5 21:45 22:30 9/24/2016 9/24/2016 0.20 PRODS STK KOST P Time drill 4-5 ft/hr. 7,373.5 7,374.2 22:30 22:42 9/24/2016 9/24/2016 0.30 PROD3 STK KOST P Controlled drill with WOB 1 k. 7,374.2 7,384.0 22:42 23:00 9/24/2016 9/24/2016 0.25 PROD3 DRILL DRLG P Drilling ahead, 1.8 BPM @ 4158 psi 7,384.0 7,412.0 23:00 23:15 FS, BHP 3636 psi, WOB 1.7k, ROP 129 9/24/2016 9/24/2016 0.20 PROD3 DRILL WPRT P PU for dry drift to 7,343' and RBIH. No 7,412.0 7,412.0 23:15 23:27 issues across billet. 9/24/2016 9/25/2016 0.55 PROD3 DRILL DRLG P BOBD, 1.8 BPM @ 4300 psi FS, BHP 7,412.0 7,494.0 23:27 00:00 3662 psi, WOB 2k, ROP 140 9/25/2016 9/25/2016 1.70 PROD3 DRILL DRLG P Drill L1-02 lateral build section to TD 7,494.0 7,650.0 00:00 01:42 of 7,650'. 1.8 BPM @ 4300 psi FS, BHP 3684 psi, WOB 2.2k, ROP 92. 9/25/2016 9/25/2016 1.55 PROD3 DRILL TRIP P POOH. Jogged above 4-1/2" scab 7,650.0 250.0 01:42 03:15 liner. Opened EDC. Cont POOH. 9/25/2016 9/25/2016 0.25 PROD3 DRILL TRIP P Slow down, check injector hydraulics. 250.0 73.4 03:15 03:30 Small leak from right angle drive. Tag - up. Space out +1.2'. WHP 1014 psi. 9/25/2016 9/25/2016 2.50 PROD3 DRILL PULD P PJSM, PUD BHA #11. 73.4 73.0 03:30 06:00 9/25/2016 9/25/2016 1.00 PROD3 DRILL PULD P Crew change, Cont. laying down BHA 73.0 0.0 06:00 07:00 #11, M/U BHA# 12 into PDL 9/25/2016 9/25/2016 8.00 PROD3 DRILL RGRP T Leaking seal on right angle drive, RR 0.0 0.0 07:00 15:00 angle drive to access seal and repair 8 Hrs repair time 9/25/2016 9/25/2016 2.25 PRODS DRILL PULD Repairs complete, PJSM to put motor 0.0 72.2 15:00 17:15 IP in well and PD BHA #12, M/U to coil and surface test Page 9/13 Report Printed: 10/3/2016 Operations Summary (with Timelog Uepths) 3F-12 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (W) 9/25/2016 9/25/2016 1.60 PRODS DRILL TRIP P RIH BHA #12, EDC open and 72.2 7,040.0 17:15 18:51 pumping 9/25/2016 9/25/2016 0.20 PRODS DRILL DLOG P Tie-in @ K1, +2.5' correction. Check 7,040.0 7,058.0 18:51 19:03 weight, PUW=29k. Close EDC. 9/25/2016 9/25/2016 0.30 PRODS DRILL TRIP P Cont RIH. 7,058.0 7,650.0 19:03 19:21 9/25/2016 9/25/2016 4.50 PRODS DRILL DRLG P Drilling ahead, 1.8 BPM @ 4358 psi 7,650.0 8,060.0 19:21 23:51 FS, BHP 3606 psi, WOB 1.6k, ROP 80-100. 9/25/2016 9/26/2016 0.15 PRODS DRILL WPRT P Short wiper to 7,260'. PUW=31 k. 8,060.0 7,657.0 23:51 00:00 9/26/2016 9/26/2016 0.40 PRODS DRILL WPRT P Cont. wiper trip up to 7,260'. 7,657.0 8,060.0 00:00 00:24 9/26/2016 9/26/2016 4.70 PRODS DRILL DRLG P Drill ahead. New mud (system #3) at 8,060.0 8,460.0 00:24 05:06 bit @ 8,224'. 9/26/2016 9/26/2016 0.60 PRODS DRILL WPRT P Wiper to window with tie in 8,460.0 7,199.0 05:06 05:42 9/26/2016 9/26/2016 0.10 PRODS DRILL DLOG P Log RA for +2' correction 7,199.0 7,217.0 05:42 05:48 9/26/2016 9/26/2016 0.50 PRODS DRILL WPRT P Continue wiper back in hole 7,217.0 8,460.0 05:48 06:18 9/26/2016 9/26/2016 1.70 PRODS DRILL DRLG P 8460', Drill, 1.8 BPM @ 4200 PSI FS, 8,460.0 8,598.0 06:18 08:00 BHP=3770, WHP=577 9/26/2016 9/26/2016 0.10 PRODS DRILL WPRT P 8598', Pull BHA Wiper, stacking and 8,598.0 8,598.0 08:00 08:06 reduced surface weight, PUW=34K 9/26/2016 9/26/2016 2.20 PRODS DRILL DRLG P 8598', Drill Ahead, 1.8 BPM @ 4250 8,598.0 8,792.0 08:06 10:18 PSi FS, BHP=3890, RIW=-4 with 2.1 K DHWOB 9/26/2016 9/26/2016 0.10 PRODS DRILL WPRT P 8792, BHA Wiper, PUW=34K, Low 8,792.0 8,792.0 10:18 10:24 surface weight, -4K 9/26/2016 9/26/2016 0.90 PRODS DRILL DRLG P 8792', Drill, 1.8 BPM @ 4015 PSI FS, 8,792.0 8,860.0 10:24 11:18 BHP=3850 9/26/2016 9/26/2016 0.60 PRODS DRILL WPRT P 8860 perform 100' Wiper, PUW=34K, 8,860.0 8,860.0 11:18 11:54 Good trip up and down 9/26/2016 9/26/2016 5.00 PRODS DRILL DRLG P 8860', Drill, 1.8 BPM @ 4315 PSI FS, 8,860.0 9,250.0 11:54 16:54 BHP=3860 9/26/2016 9/26/2016 3.10 PRODS DRILL WPRT P 9250', Reach TD, Pump 10 x 10 9,250.0 72.0 16:54 20:00 sweeps, Chase to swab Jet 4 1/2 up to Tubing Tail, RBIH to get static pressure. Last reading 3596 PSI - 5 minutes. Continue out. 9/26/2016 9/26/2016 2.40 PRODS DRILL WPRT P Tag surface, reset counters, trip back 72.0 7,040.0 20:00 22:24 in hole, Stop and check fluid level on right angle drives. 9/26/2016 9/26/2016 0.20 PRODS DRILL DLOG P Log K1 for +3'correction, PUW=27K, 7,040.0 7,057.0 22:24 22:36 Shut EDC 9/26/2016 9/26/2016 1.15 PRODS DRILL WPRT P Continue in well, Clean pass through 7,057.0 9,250.0 22:36 23:45 window, Trouble area 8,585 to 8,640, Back ream up through area at max rate. Then, RIH clean with normal circulation. Confirm TD @ 9,250'. 9/26/2016 9/27/2016 0.25 PRODS DRILL DISP P PUH, begin circulating beaded liner 9,250.0 9,024.0 23:45 00:00 pill. 9/27/2016 9/27/2016 3.00 PRODS DRILL DISP P RBIH to 9,248', POOH laying in 9,024.0 73.4 00:00 03:00 beaded liner pill followed by KWF. Paint YELLOW EOP flag @7,460'. Paint WHITE EOP flag @ 5,300'. Cont POOH. Page 10/13 Report Printed: 10/3/2016 Operations Summary (with Timelog Depths) ;a 3F-12 AA 0 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Cade Time P -T -X Operation (MB) End Depth (ftKB) 9/27/2016 9/27/2016 0.50 PROD3 DRILL OWFF P Flow check well / 30 mins. Dead well. 73.4 73.4 03:00 03:30 9/27/2016 9/27/2016 1.00 PROD3 DRILL PULD P PJSM, LD BHA #12. 73.4 0.0 03:30 04:30 9/27/2016 9/27/2016 0.75 COMPZ3 CASING PUTB P Prep floor to run liner. Paint end of 0.0 0.0 04:30 05:15 bails red - highlighting pinch points. 9/27/2016 9/27/2016 3.50 COMPZ3 CASING PUTB P PJSM, MU bull nose, 6' pup int, 54jnts 0.0 1,723.0 05:15 08:45 slotted liner. MU safety joint drill. SIMOPS: Work on cooling system for injector right angle drives. 9/27/2016 9/27/2016 1.75 COMPZ3 CASING PUTB P PJSM, MU BHA to liner and coil to 1,723.0 1,783.0 08:45 10:30 BHA 9/27/2016 9/27/2016 2.50 COMPZ3 CASING RUNL P RIH L1-02 liner. Stacked out @ 8,998'. 1,783.0 7,511.0 10:30 13:00 PUH (PUW=41k), RBIH and through to TD. Set down 8k WOB, brought pumps up to 1.5 BPM, let rate stabilize. TOB @ 7,511'. PUH (PUW=29k). Remove liner from BHA depth. 9/27/2016 9/27/2016 1.50 COMPZ3 CASING TRIP P POOH with L1-02 liner running BHA 7,511.0 45.4 13:00 14:30 #13. 9/27/2016 9/27/2016 0.50 COMPZ3 CASING OWFF P Flow check / 30 mins. Dead well. 45.4 45.4 14:30 15:00 PJSM 9/27/2016 9/27/2016 1.00 COMPZ3 CASING PULD P LD BHA #13 45.4 0.0 15:00 16:00 9/27/2016 9/27/2016 0.70 PROD4 STK PULD P PJSM, PU BHA #14, surface test 0.0 72.2 16:00 16:42 MWD, stab injector, open ECD 9/27/2016 9/27/2016 1.40 PROD4 STK TRIP P RIH displacing 12 ppg KWF w 8.6 ppg 72.0 7,057.1 16:42 18:06 Flow Pro. Tie in @ K1 cmarker ( correction plus 1.5 ft) 9/27/2016 9/27/2016 1.50 PROD4 STK TRIP P RIH, Circulate out remaining KWF W 7,057.1 7,497.0 18:06 19:36 8.6 Flow Pro, Close ECD 9/27/2016 9/27/2016 0.50 PROD4 STK KOST P Dry tag liner top billet @ 7510', PU, 7,497.0 7,510.0 19:36 20:06 Start pumps, RIH, Stall, Restart, Time Drill 1 ft/hr, 1.80 bpm , CT 4377 psi, WH 385 psi 9/27/2016 9/27/2016 2.40 PROD4 DRILL DRLG P Drilling formation, 69 fph, 1.7k WOB, 7,510.0 7,540.0 20:06 22:30 CT 4651 psi, WH 458 psi. PU wt 29k lbs. Dry drift liner top billet, Good. 9/27/2016 9/28/2016 1.50 PROD4 DRILL DRLG P Drilling formation, 75 fph, 1.86 k WOB, 7,540.0 7,631.0 22:30 00:00 1.78 bpm, CT 4650 psi, WH 408 psi. 9/28/2016 9/28/2016 2.75 PROD4 DRILL DRLG P Drilling formation, 165 fph, 1.4 k WOB, 7,631.0 7,908.0 00:00 02:45 1.75 bpm, CT 4735 psi, WH 381 psi. Started stacking weight @ 7801' CTMD. ROP down to 20 fph suspect we encountered fault #2. ROP 100 fph @ 7845'. 9/28/2016 9/28/2016 0.50 PROD4 DRILL WPRT P Magnetic interference suspected, two 7,908.0 7,200.0 02:45 03:15 bad surveys, drilled 60' total from last good survey. Pulled wiper trip to the window to shelter waiting on Sperry Sun while they correct our data. 31 k lbs off bottom. Confirm W CDR2 same issues. 9/28/2016 9/28/2016 0.75 PROD4 DRILL WPRT P RBIH, coil wt 12k, Data cleaned up 7,200.0 7,908.0 03:15 04:00 while running back in hole. Page 11/13 Report Printed: 10/3/2016 Operations Summary (with Timelog Depths) 3F-12 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 9/28/2016 9/28/2016 3.45 PROD4 DRILL DRLG P Drilling, CT wt 9.24k lbs, WOB 1.1 k 7,908.0 8,310.0 04:00 07:27 lbs, ROP 80 fph, Coil 4645 psi, WH 299 psi @ 1.78 bpm. 9/28/2016 9/28/2016 0.55 PROD4 DRILL WPRT P Wiper trip, PUW=34k. PUH to 7,520'. 8,310.0 8,310.0 07:27 08:00 RBIH, CTSW=5k. Clean. 9/28/2016 9/28/2016 3.10 PROD4 DRILL DRLG P BOBD, 1.8 BPM @ 4612 psi FS, BHP 8,310.0 8,710.0 08:00 11:06 3690 psi, WOB 2.4k, ROP 100. 9/28/2016 9/28/2016 0.50 PROD4 DRILL WPRT P Wiper trip #2 PUW= 33k lbs, PUH to 8,710.0 8,710.0 11:06 11:36 7910' 9/28/2016 9/28/2016 0.50 PROD4 DRILL DRLG P BOBD, 1.8 BPM @ 46150 psi FS, Coil 8,710.0 8,768.0 11:36 12:06 4830 psi on bottom, BHP 3720 psi, WOB 1.5 k. 9/28/2016 9/28/2016 3.30 PROD4 DRILLDRLG P ' New mud at the bit 8768'. 2284' 8,768.0 9,110.0 12:06 15:24 drilled on system #3 CT 4853 psi @ 1.8 bpm. CT wt, 1.5k lbs WOB 2k lbs. ROP 101. 9/28/2016 9/28/2016 1.00 PROD4 DRILL WPRT P Wiper trip to TT, #3 PUW= 34k lbs, 9,110.0 7,035.0 15:24 16:24 PUH to 7035 9/28/2016 9/28/2016 0.90 PROD4 DRILL WPRT P Tie in @ K1 for +4'correction. RBIH 7,035.0 9,110.0 16:24 17:18 9/28/2016 9/28/2016 2.50 PROD4 DRILL DRLG P BOBD, Coil 4850 psi, WH 478 psi @ 9,110.0 9,400.0 17:18 19:48 1.8 BPM, CT wt 3.6k lbs, WOB 2.3 k lbs, ROP 114 fph, Start 10 x 10 sweeps in anticipation of TD. 9/28/2016 9/28/2016 1.00 PROD4 DRILL WPRT P *'TD 9400' Wiper trip to TT, PUW= 9,400.0 7,050.0 19:48 20:48 30k lbs, PUH to 7050 9/28/2016 9/28/2016 0.40 PROD4 DRILL WPRT P Jog from 7050 to 7150', Park @ 7158' 7,050.0 7,050.0 20:48 21:12 for static pressure check, pressure dropping, 12 ppg KW good. 9/28/2016 9/28/2016 1.20 PROD4 DRILL WPRT P Continue wiper trip to swab. 7,050.0 72.0 21:12 22:24 9/28/2016 9/29/2016 1.60 PROD4 DRILL WPRT P RBIH to lay in liner running pill. 72.0 7,171.0 22:24 00:00 9/29/2016 9/29/2016 0.70 PROD4 DRILL DISP P RBIH to lay in liner running pill, tag 7,171.0 9,400.0 00:00 00:42 9400'. 9/29/2016 9/29/2016 2.60 PROD4 DRILL DISP P Pump liner running pill and KWF, 40 9,400.0 72.0 00:42 03:18 bbls dirty vol of 12 ppb NaBr w lubes and 2 ppb Alpine beads, lay in from 9370'. Paint EOP TD flag 7110', Yellow, Paint EOP Window Flag 4800'. POOH. 9/29/2016 9/29/2016 1.40 PROD4 DRILL PULD P At surface, Monitor hole 30 minutes, 72.0 0.0 03:18 04:42 Good, PJSM, lay down L1-03 drilling assembly BHA #14. 9/29/2016 9/29/2016 1.00 COMPZ4 CASING PUTB P Prep floor to run liner 0.0 0.0 04:42 05:42 9/29/2016 9/29/2016 5.10 COMPZ4 CASING PUTB P PJSM, MU liner - non -ported bullnose, 0.0 2,238.3 05:42 10:48 73 jnts slotted liner, and shorty deployment sleeve. After 50 jnts in hole, performed well control drill. Cont MU slotted liner. 9/29/2016 9/29/2016 2.00 COMPZ4 CASING PUTB P PJSM, clean-up rig floor, PU/MU BHA 2,238.3 2,282.5 10:48 12:48 #15. 9/29/2016 9/29/2016 1.00 COMPZ4 CASING RUNL P RIH. Correct to flag depth, +1.11' 2,282.5 7,081.0 12:48 13:48 correction. Weight check, PUW=34k. 9/29/2016 9/29/2016 2.20 COMPZ4 CASING RUNL P Cont RIH. Work pipe from 8,980'- 7,081.0 9,400.0 13:48 16:00 9,070' and 9,320' to TD. 9/29/2016 9/29/2016 0.05 COMPZ4 CASING RUNL P Bring pumps on, release liner. 9,400.0 7,143.0 16:00 16:03 PUW=29k. Correct depth by removing liner length. Page 12/13 Report Printed: 10/3/2016 Operations Summary (with Timelog Depths) t< 3F-12 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) :End Depth (ftKB) 9/29/2016 9/29/2016 2.80 COMPZ4 CASING DISP P Walk around observed one reel hub 9,400.0 2,500.0 16:03 18:51 bolt loose, Inspected, fount three total loose, re -torque same. Swap well to seawater,open EDC, POOH to FP point, 2500' 9/29/2016 9/29/2016 1.70 COMPZ4 CASING DISP P LRS on location, spot up, RU, PJSM, 2,500.0 45.0 18:51 20:33 PT 4k psi good, online 1 bpm @ 2400 psi, pump 30 bbls diesel, SD. 9/29/2016 9/30/2016 3.45 COMPZ4 CASING PULD P At surface, PJSM, pressure un deploy 45.0 0.0 20:33 00:00 liner running BHA # 15. Break down safety joint and pull checks. Crew Change. 9/30/2016 9/30/2016 2.50 DEMOB WHDBOP MPSP P PJSM, RU and lubricate in BPV, RD 0.0 0.0 00:00 02:30 lubricator. 9/30/2016 9/30/2016 3.50 DEMOB WHDBOP RURD P Flush stack, blow down lines. Start ND 0.0 0.0 02:30 06:00 BOP signifying Rig Release @ 0600. 9/30/2016 9/30/2016 6.00 DEMOB WHDBOP RURD P Finish ND and secure BOP. Methanol 0.0 0.0 06:00 12:00 in XMT, function valves. Check WH bolts. Disconnect PUTZ. Prepare rig for move. Page 13/13 Report Printed: 10/3/2016 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 3F Pad 3F -12L1 50-029-21483-60 Baker Hughes INTEQ Definitive Survey Report 05 October, 2016 FSM BAKER HUGHES - ConocoPhillips //ls ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupt Local Coordinate Reference: Well 3F-12 Project: Kuparuk River Unit TVD Reference: 3F-12 @ 93.00usft (3F-12) Site: Kuparuk 3F Pad MD Reference: 3F-12 @ 93.00usft (3F-12) Well: 3F-12 North Reference: True Wellbore: 3F-12 Survey Calculation Method: Minimum Curvature Design: 3F-12 Database: EDM Alaska NSK Sandbox Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 3F-12 , Well Position -N/-S 0.00 usft Northing: 5,985,865.19usft Latitude: 70° 22'21.370 N +EI -W 0.00 usft Easting: 508,364.05usft Longitude: 149° 55'55.273 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 3F-121-1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 0 (°i W) BGGM2016 10/1/2016 17.93 80.96 57,547 Design 3F-1211 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,100.00 Vertical Section: Depth From (TVD) +NI -S 'EJ -W Direction (usft) (usft) (usft) (I 93.00 0.00 0.00 45.00 Survey Program Date From To Survey Survey {usft) (usft) Survey (Wellbore) Toot Name Description Start Data End Date 100.00 7,100.00 3F-12 (3F-12) GCT -MS Schlumberger GCT multishot 8/18/2000 7,179.00 9,320.12 3F-1211 (3F-121-1) MWD MWD -Standard 9/15/2016 9/22/2016 1015r2016 1;50:41PM Page 2 COMPASS 5000.9 Build 74 ConocoPhillips FIANI'd ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 3F-12 Project Kuparuk River Unit TVD Reference: 3F-12 @ 93.00usft (3F-12) Site: Kuparuk 3F Pad MD Reference: 3F-12 @ 93.00usft (3F-12) Well: 3F-12 North Reference: True Wellbore: 3F-12 Survey Calculation Method: Minimum Curvature Design: 3F-12 Database: EDM Alaska NSK Sandbox Survey MD Inc Azt ND TVDSS +NIS *'El-SAt Map Map DLS Vertical (usft) (°) (°) (usft) (usft) (usft) (11aft) Northing Eastm9 /100,00 Section Survey Tool Name 00 7,100.00 40.72 242.85 5,735.68 5,642.68 -1,388.49 -3,216.77 5,984,473.25 505,149.16 0.42 -3,256.41 MWD (2) 7,179.00 40.67 242.78 5,795.57 5,702.57 -1,412.02 -3,262.59 5,984,449.66 505,103.37 0.09 -3,305.45 MWD (2) 7,210.19 47.90 245.50 5,817.89 5,724.89 -1,421.48 -3,282.18 5,984,440.18 505,083.78 23.96 -3,325.99 MWD (2) 7,240.59 57.61 257.00 5,836.31 5,743.31 -1,429.08 -3,305.06 5,984,432.56 505,060.92 43.82 -3,347.54 MWD (2) 7,270.45 70.18 263.10 5,849.43 5,756.43 -1,433.63 -3,331.41 5,984,427.99 505,034.58 45.89 -3,369.39 MWD (2) 7,300.42 82.18 266.44 5,856.58 5,763.58 -1,436.25 -3,360.34 5,984,425.33 505,005.66 41.47 -3,391.70 MWD (2) 7,330.63 86.28 279.64 5,859.63 5,766.63 -1,434.65 -3,390.28 5,984,426.90 504,975.72 45.53 -3,411.74 MWD (2) 7,360.61 86.99 293.27 5,861.39 5,768.39 -1,426.19 -3,418.91 5,984,435.32 504,947.08 45.45 -3,426.00 MWD (2) 7,390.61 86.87 307.02 5,863.01 5,770.01 -1,411.18 -3,444.75 5,984,450.30 504,921.22 45.77 -3,433.66 MWD (2) 7,420.53 88.80 320.94 5,864.14 5,771.14 -1,390.47 -3,466.21 5,984,470.98 504,899.74 46.93 -3,434.19 MWD (2) 7,450.43 90.52 335.35 5,864.32 5,771.32 -1,365.14 -3,481.95 5,984,496.29 504,883.98 48.53 -3,427.41 MWD(2) 7,480.56 89.36 348.05 5,864.35 5,771.35 -1,33660 -3,491.39 5,984,524.83 504,874.50 42.33 -3,413.90 MWD (2) 7,500.25 90.28 357.35 5,864.42 5,771.42 -1,317.09 -3,493.89 5,984,544.33 504,871.98 47.46 -3,401.87 MWD (2) 7,530.65 92.18 10.80 5,863.76 5,770.76 -1,286.84 -3,491.74 5,984,574.58 504,874.10 44.67 -3,378.96 MWD (2) 7,560.99 90.68 12.93 5,863.00 5,770.00 -1,257.16 -3,485.50 5,984,604.26 504,880.30 8.58 -3,353.57 MWD (2) 7,591.17 89.63 15.17 5,862.92 5,769.92 -1,227.89 -3,478.17 5,984,633.54 504,887.60 8.20 -3,327.69 MWD (2) 7,620.71 88.47 17.74 5,863.41 5,770.41 -1,199.56 -3,469.81 5,984,661.87 504,895.93 9.54 -3,301.74 MWD (2) 7,651.23 88.34 20.57 5,864.26 5,771.26 -1,170.75 -3,459.80 5,984,690.69 504,905.91 9.28 -3,274.29 MWD(2) 7,681.28 88.19 22.44 5,865.17 5,772.17 -1,142.80 -3,448.79 5,984,718.65 504,916.88 6.24 -3,246.75 MWD (2) 7,711.11 88.62 24.02 5,866.00 5,773.00 -1,115.40 -3,437.03 5,984,746.06 504,928.61 5.49 -3,219.06 MWD (2) 7,741.26 87.85 21.08 5,866.93 5,773.93 -1,087.58 -3,425.47 5,984,773.90 504,940.14 10.08 -3,191.21 MWD(2) 7,771.34 87.48 18.28 5,868.16 5,775.16 -1,059.28 -3,415.35 5,984,802.20 504,950.22 9.38 -3,164.04 MWD (2) 7,801.73 87.58 16.83 5,869.47 5,776.47 -1,030.33 -3,406.19 5,984,831.16 504,959.35 4.78 -3,137.10 MWD (2) 7,832.59 87.88 18.82 5,870.69 5,777.69 -1,000.98 -3,396.76 5,984,860.52 504,968.75 6.52 -3,109.67 MWD (2) 7,861.01 88.40 22.28 5,871.61 5,778.61 -974.38 -3,386.79 5,984,887.12 504,978.69 12.30 -3,083.81 MWD (2) 7,891.49 88.77 24.94 5,872.36 5,779.36 -946.47 -3,374.58 5,984,915.05 504,990.86 8.81 -3,055.44 MWD (2) 7,922.06 88.96 28.16 5,872.97 5,779.97 -919.13 -3,360.92 5,984,942.40 505,004.49 10.55 -3,026.45 MWD(2) 7,951.21 89.08 30.34 5,873.47 5,780.47 -893.70 -3,346.68 5,984,967.84 505,018.70 7.49 -2,998.41 MWD (2) 7,980.35 89.20 32.60 5,873.91 5,780.91 -868.85 -3,331.47 5,984,992.70 505,033.88 7.77 -2,970.08 MWD (2) 8,011.07 88.19 34.94 5,87461 5,781.61 -843.32 -3,314.40 5,985,018.25 505,050.92 8.29 -2,939.96 MWD (2) Annotation TIP KOP 10/52016 1:50:41 PM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips RUN ConocoPhillips Definitive Survey Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Co-ordinate Reference: Well 3F-12 Project: Kuparuk River Unit TVD Reference: 3F-12 @ 93.00usft (3F-12) Site: Kuparuk 3F Pad MD Reference: 3F-12 @ 93.00usft (3F-12) Well: 3F-12 North Reference: True Wellbore: 3F-12 Survey Calculation Method: Minimum Curvature Design: 3F-12 Database: EDM Alaska NSK Sandbox Survey MD Inc Azi TVD TVDSS +N/ -S +E/ -W Map Map DLS Vertical (usft) (") (°) (usft) (usft) (usft) (usft) Northing East) (°1100') Section Survey Tool Name A MOtBtIOn (ft) (ft) (ft) 8,040.63 86.56 36.73 5,875.96 5,782.96 -819.39 -3,29712 5,985,042.20 505,068.18 8.19 -2,910.81 MWD (2) 8,071.33 85.08 38.73 5,878.20 5,785.20 -795.17 -3,278.38 5,985,066.43 505,086.89 8.09 -2,880.44 MWD (2) 8,100.13 83.97 41.21 5,880.95 5,787.95 -773.20 -3,259.97 5,985,088.42 505,105.27 9.40 -2,851.88 MWD (2) 8,130.73 85.02 43.15 5,883.88 5,790.88 -750.63 -3,239.52 5,985,111.01 505,125.70 7.18 -2,821.46 MWD (2) 8,160.56 86.25 44.99 5,886.15 5,793.15 -729.26 -3,218.83 5,985,132.40 505,146.36 7.40 -2,791.72 MWD (2) 8,190.79 86.13 47.81 5,888.16 5,795.16 -708.47 -3,196.99 5,985,153.22 505,168.17 9.32 -2,761.57 MWD (2) 8,220.66 85.14 50.96 5,890.43 5,797.44 189.08 -3,174.38 5,985,172.63 505,190.75 11.02 -2,731.88 MWD (2) 8,250.71 85.33 53.74 5,892.93 5,799.93 170.79 -3,150.68 5,985,190.95 505,214.44 9.24 -2,702.18 MWD (2) 8,280.84 85.27 56.34 5,895.40 5,802.40 153.58 -3,126.07 5,9&5,208.18 505,239.03 8.60 -2,672.62 MWD (2) 8,310.85 87.36 57.21 5,897.33 5,804.33 137.18 -3,101.02 5,985,224.61 505,264.06 7.54 -2,643.30 MWD (2) 8,339.63 88.77 58.02 5,898.30 5,805.30 -621.77 -3,076.73 5,985,240.04 505,288.32 5.65 -2,615.23 MWD (2) 8,370.20 88.71 60.03 5,898.97 5,805.97 -606.04 -3,050.53 5,985,255.80 505,314.51 6.58 -2,585.58 MWD (2) 8,400.65 88.16 62.45 5,899.81 5,806.81 -591.40 -3,023.84 5,985,270.47 505,341,17 8.15 -2,556.36 MWD (2) 8,430.95 E 86.44 63.55 5,901.23 5,808.23 -577.66 -2,996.88 5,985,284.24 505,368.12 6.74 -2,52758 MWD (2) 8,460.79 86.28 66.81 5,903.13 5,810.13 -565.16 -2,969.85 5,985,296.77 505,395.13 10.92 -2,499.63 MWD(2) 8,490.65 85.67 69.35 5,905.22 5,812.22 -554.04 -2,942.22 5,985,307.92 505,422.74 8.73 -2,472.23 MWD (2) 8,520.04 85.76 72.10 5,907.42 5,814.42 -544.37 -2,914.56 5,985,317.62 505,450.39 9.34 -2,445.83 MWD (2) 8,550.51 85.79 74.79 5,909.67 5,816.67 -535.71 -2,885.44 5,985,326.31 505,479.50 8.80 -2,419.11 MWD (2) , 8,580.65 86.22 77.17 5,911.77 5,818.77 -528.43 -2,856.27 5,985,333.63 505,508.66 8.01 -2,393.34 MWD (2) 8,610.55 86.25 79.51 5,913.73 5,820.73 -522.40 -2,827.05 5,985,339.69 505,537.87 7.81 -2,368.41 MWD(2) 8,640.36 85.95 82.01 5,915.76 5,822.76 -51762 -2,797.70 5,985,344.50 505,567.21 8.43 -2,344.28 MWD (2) 8,670.48 85.67 81.84 5,917.96 5,824.96 -513.40 -2,767.95 5,985,348.75 505,596.95 1.09 -2,320.27 MWD (2) . 8,700.03 85.79 79.07 5,920.16 5,827.16 -508.51 -2,738.90 5,985,353.67 505,626.00 9.36 -2296.27 MWD (2) 8,730.60 85.85 77.28 5,922.39 5,829.39 -502.27 -2,709.06 5,985,359.95 505,655.83 5.84 -2,270.75 MWD (2) 8,760.20 86.01 76.01 5,924.49 5,831.49 -495.45 -2,680.33 5,985,366.80 505,664.54 4.31 -2,245.61 MWD (2) 8,790.58 88.62 76.24 5,925.91 5,832.91 -488.17 -2,650.87 5,985,374.11 505,713.99 8.62 -2,219.64 MWD (2) 8,820.68 90.89 77.33 5,926.04 5,833.04 -481.29 -2,621.57 5,985,381.02 505,743.28 8.37 -2,194.05 MWD (2) 8,850.45 92.58 77.21 5,925.14 5,832.14 -474.73 -2,592.55 5,985,387.61 505,772.29 5.69 -2,168.90 MWO(2) 8,880.51 93.01 76.27 5,923.67 5,630.67 -467.85 -2,563.32 5,985,394.53 505,801.51 3.44 -2,143.36 MWD (2) 8,910.56 92.70 75.19 5,922.18 5,829.18 -460.45 -2,534.24 5,985,401.95 505,830.58 3.73 -2,117.56 MWD (2) 8,940.72 91.69 74.615,921.02 5,828.02 1152.60 -2,505.14 5,985,409.84 505,859.67 3.86 -2,091.44 MWD(2) 10/52016 1:50:41 PM Page 4 COMPASS 5000.1 Build 74 1075/2010 1:50:41PM Page 5 COMPASS 5000.1 Build 74 ConocoPhillips was ConocoPhillips BAKER Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 3F-12 Project J Ku aruk River P Unit TVD Reference: 3F-12 @ 93.00usft (3F-12) Site: Kuparuk 3F Pad MD Reference: 3F-12 @ 93.00usft (3F-12) i Well: 3F-12 North Reference: True i Wellbore: 3F-12 Survey Calculation Method: Minimum Curvature Design: 31F-12 Database: EDM Alaska NSK Sandbox Survey_.. .... .,. _.._. .... .. ,.,...,.. ,.,..,,,.,,.�... ..__. _..._. .... MD tnc Azl TVD TVDSS -NI-S +E/ -W �� DLS. Veirtleal (usft) (I V) (usft) (usft) (usft) Northing (usft) E g ('/'100') Section Survey Taal Name Annotation 8,970.42 91.84 73.66 5,920.11 5,827.11 -444.48 Ift).� -2,476.59 5,985,417.98 (ft) 505,888.21 3.24 (ft) -2,065.51 MWD (2) 8,995.52 91.97 72.30 5,919.27 5,826.27 437.14 -2,452.60 5,985,425.35 505,912.18 5.44 -2,043.36 MWD (2) 9,025.53 91.60 71.53 5,918.34 5,825.34 -427.83 -2,424.09 5,985,434.69 505,940.68 2.85 -2,016.61 MWD (2) 9,049.26 92.46 69.36 5,917.50 5,824.50 419.89 -2,401.74 5,985,442.66 505,963.02 9.83 -1,995.20 MWD (2) 9,080.68 94.06 68.78 5,915.71 5,822.71 -408.69 -2,372.44 5,985,453.89 505,992.30 5.42 -1,966.56 MWD (2) 9,110.27 94.70 67.31 5,913.45 5,820.45 -397.66 -2,345.08 5,985,464.95 506,019.65 5.40 -1,939.41 MWD (2) 9,140.04 94.42 66.04 5,911.08 5,818.08 -385.91 -2,317.83 5,985,476.73 506,046.88 4.36 -1,911.83 MWD (2) 9,170.14 93.81 64.60 5,908.92 5,815.92 -373.37 -2,290.55 5,985,489.30 506,074.15 5.18 -1,883.68 MWD (2) 9,200.12 94.18 63.11 5,906.83 5,813.83 -360.19 -2,263.70 5,985,502.50 506,100.98 5.11 -1,855.38 MWD(2) 9,230.24 95.32 61.82 5,904.34 5,811.34 -346.32 -2,237.09 5,985,516.41 506,127.57 5.70 -1,826.74 MWD (2) 9,260.29 95.84 60.12 5,901.42 5,808.42 -331.81 -2,210.94 5,985,530.95 506,153.70 5.89 -1,797.99 MWD (2) 9,290.96 95.69 59.13 5,898.34 5,805.34 -316.38 -2,184.61 5,985,546.41 506,180.01 3.25 -1,768.47 MWD (2) 9,320.12 98.19 58.98 5,894.81 5,801.81 -301.49 -2,159.79 5,985,561.31 506,204.81 8.59 -1,740.39 MWD (2) 9,350.00 98.19 58.98 5,890.56 5,797.56 -286.25 -2,134.44 5,985,576.58 506,230.14 0.00 -1,711.69 PROJECTED to TD 1075/2010 1:50:41PM Page 5 COMPASS 5000.1 Build 74 BAKER HUGHES To: IECEIV UCT 14 2016 Letter of Transmittal AOGGG Date: DATA LOGGED October 13, 2016 \-0 ^'1 1201 Co M. K. BENDER Makana Bender AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 From: Yosha Ragbirsingh / Michael Soper Baker Hughes INTEQ 795 East 94th Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 3F -12L1 2 1 6 0 5 8 27 64 1 3F-12L1-01?� 1 6 0 5 9 27 64 2 3F -12L1-02 1 6 0 60 27 64 3 3F -12L1-03 2 1 6 0 6 1 27 6 4 4 (4) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael. Soper@BakerHughes.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsingh@BakerHughes.com ConocoPhilli s p UCT 14 2�1� ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 3F Pad 3F -12L1 50-029-21483-60 Baker Hughes INTEQ Definitive Survey Report 05 October, 2016 27 64 1 Few FA 2 BAKER NIl6NE5 Audit Notes: `.- ConocoPhillips Version: 1.0 FICA aI ConocoPhillips Survey Depth From (TVD) Start Date sHUGHES (usft) MWD - Standard Definitive Survey Report 93.00 Survey Program Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 3F-12 (usft) (usft) Project: Kuparuk River Unit TVD Reference: 3F-12 @ 93.00usft (3F-12) 7,179.00 9,320.12 Site: Kuparuk 3F Pad MD Reference: 3F-12 @ 93.00usft (3F-12) Well: 3F-12 North Reference: True Wellbore: 3F-12 Survey Calculation Method: Minimum Curvature Design: 3F-12 Database: EDM Alaska NSK Sandbox " Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 3F-12 :. . Well Position +N/ -S 0.00 usft Northing: 5,985,865.19usft Latitude: 70° 22'21.370 N I +E/ -W 0.00 usft Easting: 508,364.05 usft Longitude: 1490 55'55.273 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 3F-121-1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1) (1) (nT) B G G M 2016 10/1/2016 17.93 80.96 57,547 Design 3F-121-1 Audit Notes: Direction (usft) Version: 1.0 Phase: ACTUAL Vertical Section: Survey Depth From (TVD) Start Date Schlumberger GCT multishot (usft) MWD - Standard 9/15/2016 93.00 Survey Program Date From To (usft) (usft) Survey (Wellbore) 100.00 7,100.00 3F-12 (3F-12) 7,179.00 9,320.12 3F-121-1 (3F -12L1) 10/5/2016 1: 50:41 PM Tie On Depth: 7,100.00 +N/ -S (usft) 0.00 Tool Name GCT -MS MWD Page 2 +E/ -W Direction (usft) (1) 0.00 45.00 Survey Description Start Date Schlumberger GCT multishot 8/18/2000 MWD - Standard 9/15/2016 Survey End Date 9/22/2016 COMPASS 5000.1 Build 74 ConocoPhillips NAkI ConocoPhillips Definitive Survey Report BHUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 3F-12 Project: Kuparuk River Unit TVD Reference: 3F-12 @ 93.00usft (3F-12) Site: Kuparuk 3F Pad MD Reference: 3F-12 @ 93.00usft (3F-12) Well: 3F-12 North Reference: True Wellbore: 3F-12 Survey Calculation Method: Minimum Curvature Design: 3F-12 Database: EDM Alaska NSK Sandbox w Survey i 2 Map Map Vertical DInc Azi TVD TVDSS +N/ -S +E/ -W DLS (usft) V) (1) (usft) (usft) (usft) (usft) Northing Easting (°/1001) Section Survey Tool Name Annotation (ft) (ft) (ft) 7,100.00 40.72 242.85 5,735.68 5,642.68 -1,388.49 -3,216.77 5,984,473.25 505,149.16 0.42 -3,256.41 MWD (2) TIP 7,179.00 40.67 242.78 5,795.57 5,702.57 -1,412.02 -3,262.59 5,984,449.66 505,103.37 0.09 -3,305.45 MWD (2) KOP E 7,210.19 i 47.90 245.50 5,817.89 5,724.89 -1,421.48 -3,282.18 5,984,440.18 505,083.78 23.96 -3,325.99 MWD (2) 7,240.59 57.61 257.00 5,836.31 5,743.31 -1,429.08 -3,305.06 5,984,432.56 505,060.92 43.82 -3,347.54 MWD (2) 7,270.45 70.16 263.10 5,849.43 5,756.43 -1,433.63 -3,331.41 5,984,427.99 505,034.58 45.89 -3,369.39 MWD (2) 7,300.42 82.18 266.44 5,856.58 5,763.58 -1,436.25 -3,360.34 5,984,425.33 505,005.66 41.47 -3,391.70 MWD (2) 7,330.63 86.28 279.64 5,859.63 5,766.63 -1,434.65 -3,390.28 5,984,426.90 504,975.72 45.53 -3,411.74 MWD (2) 7,360.61 86.99 293.27 5,861.39 5,768.39 -1,426.19 -3,418.91 5,984,435.32 504,947.08 45.45 -3,426.00 MWD (2) 7,390.61 86.87 307.02 5,863.01 5,770.01 -1,411.18 -3,444.75 5,984,450.30 504,921.22 45.77 -3,433.66 MWD (2) 7,420.53 88.80 320.94 5,864.14 5,771.14 -1,390.47 -3,466.21 5,984,470.98 504,899.74 46.93 -3,434.19 MWD (2) 7,450.43 90.52 335.35 5,864.32 5,771.32 -1,365.14 -3,481.95 5,984,496.29 504,663.96 46.53 -3,427.41 MWD (2) 7,480.56 89.36 348.05 5,864.35 5,771.35 -1,336.60 -3,491.39 5,984,524.83 504,874.50 42.33 -3,413.90 MWD (2) 7,500.25 90.28 357.35 5,864.42 5,771.42 -1,317.09 -3,493.89 5,984,544.33 504,671.98 47.46 -3,401.87 MWD (2) 7,530.65 92.18 10.80 5,863.76 5,770.76 -1,286.84 -3,491.74 5,984,574.58 504,674.10 44.67 -3,378.96 MWD (2) k 7,560.99 90.68 12.93 5,863.00 5,770.00 -1,257.16 -3,485.50 5,984,604.26 504,880.30 8.58 -3,353.57 MWD (2) 7,591.17 89.63 15.17 5,862.92 5,769.92 -1,227.89 -3,478.17 5,984,633.54 504,887.60 6.20 -3,327.69 MWD (2) 7,620.71 88.47 17.74 5,863.41 5,770.41 -1,199.56 -3,469.81 5,984,661.87 504,895.93 9.54 -3,301.74 MWD (2) 7,651.23 86.34 20.57 5,864.26 5,771.26 -1,170.75 -3,459.80 5,984,690.69 504,905.91 9.28 -3,274.29 MWD (2) 7,681.28 88.19 22.44 5,865.17 5,772.17 -1,142.80 -3,448.79 5,984,718.65 504,916.88 6.24 -3,246.75 MWD (2) 7,711.11 86.62 24.02 5,866.00 5,773.00 -1,115.40 -3,437.03 5,984,746.06 504,928.61 5.49 -3,219.06 MWD (2) 7,741.26 87.85 21.08 5,866.93 5,773.93 -1,087.58 -3,425.47 5,984,773.90 504,940.14 10.08 -3,191.21 MWD (2) 7,771.34 87.48 18.28 5,868.16 5,775.16 -1,059.28 -3,415.35 5,984,802.20 504,950.22 9.38 -3,164.04 MWD (2) 7,801.73 87.58 16.83 5,869.47 5,776.47 -1,030.33 -3,406.19 5,984,831.16 504,959.35 4.78 -3,137.10 MWD (2) 7,832.59 87.88 18.82 5,870.69 5,777.69 -1,000.98 -3,396.76 5,984,860.52 504,968.75 6.52 -3,109.67 MWD (2) 7,661.01 68.40 22.28 5,871.61 5,778.61 -974.38 -3,386.79 5,984,687.12 504,978.69 12.30 -3,083.81 MWD (2) 7,691.49 88.77 24.94 5,872.36 5,779.36 -946.47 -3,374.58 5,984,915.05 504,990.86 8.81 -3,055.44 MWD (2) 7,922.06 88.96 28.16 5,872.97 5,779.97 -919.13 -3,360.92 5,984,942.40 505,004.49 10.55 -3,026.45 MWD (2) 7,951.21 89.08 30.34 5,873.47 5,780.47 -893.70 -3,346.68 5,984,967.84 505,018.70 7.49 -2,998.41 MWD (2) 7,980.35 89.20 32.60 5,873.91 5,780.91 -868.85 -3,331.47 5,984,992.70 505,033.88 7.77 -2,970.08 MWD (2) 8,011.07 88.19 34.94 5,674.61 5,781.61 -843.32 -3,314.40 5,985,018.25 505,050.92 8.29 -2,939.96 MWD (2) 10/5/2016 1:50:41PM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips FfAii'l ConocoPhillips Definitive Survey Report BAKER Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 3F-12 Project: Kuparuk River Unit TVD Reference: 3F-12 @ 93.00usft (3F-12) Site: Kuparuk 3F Pad MD Reference: 3F-12 @ 93.00usft (3F-12) Well: 3F-12 North Reference: True Wellbore: 3F-12 Survey Calculation Method: Minimum Curvature Design: 3F-12 Database: EDM Alaska NSK Sandbox Survey MD Inc Azi TVD TVDSS +N/ -S +E/ -W Map Map Vertical (usft) (usft) (usft) (usft) (usft) Northing Easting (° � oo) Section Survey Tool Name Annotation (ft) (ft) (ft) 8,040.63 86.56 36.73 5,875.96 5,782.96 -819.39 -3,297.12 5,985,042.20 505,068.18 8.19 -2,910.81 MWD (2) 8,071.33 85.08 38.73 5,878.20 5,785.20 -795.17 -3,278.38 5,985,066.43 505,086.89 8.09 -2,880.44 MWD (2) 8,100.13 83.97 41.21 5,880.95 5,787.95 -773.20 -3,259.97 5,985,088.42 505,105.27 9.40 -2,851.88 MWD (2) 8,130.73 85.02 43.15 5,883.88 5,790.88 -750.63 -3,239.52 5,985,111.01 505,125.70 7.18 -2,821.46 MWD (2) 8,160.56 86.25 44.99 5,886.15 5,793.15 -729.26 -3,218.83 5,985,132.40 505,146.36 7.40 -2,791.72 MWD (2) 8,190.79 86.13 47.81 5,888.16 5,795.16 -708.47 -3,196.99 5,985,153.22 505,168.17 9.32 -2,761.57 MWD (2) @ 8,220.66 85.14 50.96 5,890.43 5,797.44 -689.D8 -3,174.38 5,985,172.63 505,190.75 11.02 -2,731.88 MWD (2) 8,250.71 85.33 53.74 5,892.93 5,799.93 -670.79 -3,150.68 5,985,190.95 505,214.44 9.24 -2,702.18 MWD (2) 8,280.84 85.27 56.34 5,895.40 5,802.40 -653.58 -3,126.07 5,985,208.18 505,239.03 8.60 -2,672.62 MWD (2) a 8,310.85 87.36 57.21 5,897.33 5,804.33 -637.18 -3,101.02 5,985,224.61 505,264.06 7.54 -2,643.30 MWD (2) 8,339.63 88.77 58.02 5,898.30 5,805.30 -621.77 -3,076.73 5,985,240.04 505,288.32 5.65 -2,615.23 MWD (2) I 8,370.20 88.71 60.03 5,898.97 5,805.97 -606.04 -3,050.53 5,985,255.80 505,314.51 6.58 -2,585.58 MWD (2) 8,400.65 88.16 62.45 5,899.81 5,806.81 -591.40 -3,023.84 5,985,270.47 505,341.17 8.15 -2,556.36 MWD (2) 8,430.95 86.44 63.55 5,901.23 5,808.23 -577.66 -2,996.88 5,985,284.24 505,368.12 6.74 -2,527.58 MWD (2) 8,460.79 86.28 66.81 5,903.13 5,810.13 -565.16 -2,969.85 5,985,296.77 505,395.13 10.92 -2,499.63 MWD (2) 8,490.65 85.67 69.35 5,905.22 5,812.22 -554.04 -2,942.22 5,985,307.92 505,422.74 8.73 -2,472.23 MWD (2) 8,520.04 85.76 72.10 5,907.42 5,814.42 -544.37 -2,914.56 5,985,317.62 505,450.39 9.34 -2,445.83 MWD (2) 8,550.51 85.79 74.79 5,909.67 5,816.67 -535.71 -2,885.44 5,985,326.31 505,479.50 8.80 -2,419.11 MWD (2) 8,580.65 86.22 77.17 5,911.77 5,818.77 -528.43 -2,856.27 5,985,333.63 505,508.66 8.01 -2,393.34 MWD (2) 8,610.55 86.25 79.51 5,913.73 5,820.73 -522.40 -2,827.05 5,985,339.69 505,537.87 7.81 -2,368.41 MWD (2) 8,640.36 85.95 82.01 5,915.76 5,822.76 -517.62 -2,797.70 5,985,344.50 505,567.21 8.43 -2,344.28 MWD (2) 8,670.48 85.67 81.84 5,917.96 5,824.96 -513.40 -2,767.95 5,985,348.75 505,596.95 1.09 -2,320.27 MWD (2) 8,700.03 85.79 79.07 5,920.16 5,827.16 -508.51 -2,738.90 5,985,353.67 505,626.00 9.36 -2,296.27 MWD (2) 8,730.60 85.85 77.28 5,922.39 5,829.39 -502.27 -2,709.06 5,985,359.95 505,655.83 5.84 -2,270.75 MWD (2) 8,760.20 86.01 76.01 5,924.49 5,831.49 -495.45 -2,680.33 5,985,366.80 505,684.54 4.31 -2,245.61 MWD (2) 8,790.58 88.62 76.24 5,925.91 5,832.91 -468.17 -2,650.87 5,985,374.11 505,713.99 8.62 -2,219.64 MWD (2) 8,820.68 90.69 77.33 5,926.04 5,833.04 -481.29 -2,621.57 5,985,381.02 505,743.28 8.37 -2,194.05 MWD (2) 8,850.45 92.58 77.21 5,925.14 5,832.14 -474.73 -2,592.55 5,985,387.61 505,772.29 5.69 -2,168.90 MWD (2) 8,880.51 93.01 76.27 5,923.67 5,830.67 -467.85 -2,563.32 5,985,394.53 505,801.51 3.44 -2,143.36 MWD (2) 8,910.56 92.70 75.19 5,922.18 5,829.18 -460.45 -2,534.24 5,985,401.95 505,830.58 3.73 -2,117.56 MWD (2) 8,940 72 91.69 74.61 5,921.02 5,828.02 -452.60 -2,505.14 5,985,409.84 505,859.67 3.86 -2,091.44 MWD (2) 10/5/2016 1: 5041 PM Page 4 COMPASS 5000.1 Build 74 10/5/2016 1:50.41PM Page 5 COMPASS 5000.1 Build 74 o - ConocoPhillips IGAI ConocoPhillips BAKER Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Co-ordinate Reference: Well 317-12 Project: Kuparuk River Unit TVD Reference: 3F-12 @ 93.00usft (3F-12) Site: Kuparuk 3F Pad MD Reference: 3F-12 @ 93.00usft (3F-12) Well: 3F-12 North Reference: True Wellbore: 3F-12 Survey Calculation Method: Minimum Curvature Design: 3F-12 Database: EDM Alaska NSK Sandbox Survey .. .......,.w, -_. _., MD Inc Azi TVD TVDSS +NIS Map +E/ -W Map DLS Vertical r (usft) (°) (°) (usft) (usft) (usft) Northing (usft) Easting (°1100') Section Survey Tool Name y Annotation S (ft) (ft) (ft) 8,970.42 91.84 73.66 5,920.11 5,827.11 -444.48 -2,476.59 5,985,417.98 505,888.21 3.24 -2,065.51 MWD (2) 8,995.52 91.97 72.30 5,919.27 5,826.27 -437.14 -2,452.60 5,985,425.35 505,912.18 5.44 -2,043.36 MWD (2) 9,025.53 91.60 71.53 5,918.34 5,825.34 -427.83 -2,424.09 5,985,434.69 505,940.68 2.85 -2,016.61 MWD (2) , 9,049.26 92.46 69.36 5,917.50 5,824.50 -419.89 -2,401.74 5,985,442.66 505,963.02 9.83 -1,995.20 MWD (2) 9,0B0.68 94.06 68.78 5,915.71 5,822.71 -408.69 -2,372.44 5,985,453.89 505,992.30 5.42 -1,966.56 MWD (2) 9,110.27 94.70 67.31 5,913.45 5,820.45 -397.66 -2,345.08 5,985,464.95 506,019.65 5.40 -1,939.41 MWD (2) 9,140.04 94.42 66.04 5,911.08 5,818.08 -385.91 -2,317.83 5,985,476.73 506,046.88 4.36 -1,911.83 MWD (2) 9,170.14 93.81 64.60 5,908.92 5,815.92 -373.37 -2,290.55 5,985,489.30 506,074.15 5.18 -1,883.68 MWD (2) 9,200.12 94.18 63.11 5,906.83 5,813.83 -360.19 -2,263.70 5,985,502.50 506,100.98 5.11 -1,855.38 MWD (2) 9,230.24 95.32 61.82 5,904.34 5,811.34 -346.32 -2,237.09 5,985,516.41 506,127.57 5.70 -1,826.74 MWD (2) 9,260.29 95.84 60.12 51901.42 5,808.42 -331.81 -2,210.94 5,985,530.95 506,153.70 5.B9 -1,797.99 MWD (2) 9,290.96 95.69 59.13 5,898.34 5,805.34 -316.38 -2,184.61 5,985,546.41 506,180.01 3.25 -1,768.47 MWD (2) 9,320.12 98.19 58.98 5,894.81 5,801.81 -301.49 -2,159.79 5,985,561.31 506,204.81 8.59 -1,740.39 MWD (2) 9,350.00 98.19 58.98 5,890.56 5,797.56 -286.25 -2,134.44 5,985,576.58 506,230.14 0.00 -1,711.69 PROJECTED to TD 10/5/2016 1:50.41PM Page 5 COMPASS 5000.1 Build 74 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Tuesday, September 13, 20161:28 PM To: Herring, Keith E (Keith.E.Herring@conocophiIIips.com) Cc: jason.burke@conocophillips.com; Eller, J Gary (J.Gary.Eller@conocophillips.com); Regg, James B (DOA) Subject: KRU 3F -12L1, -1-1-01, -1-1-02 &-L1-03(PTD 216-058, 216-059,216-060 & 216-061) CDR3-AC BOP Testing 7 day cycle Keith, The first well using the new coiled tubing drilling rig, Nabors CDR3-AC is scheduled to begin drilling soon. The approved permits were submitted and approved using Nabors CDR2-AC. Approval is granted to use the new rig. However, BOP testing for these approved permits will be on a 7 day cycle, not a 14 day cycle. Please include this approval and BOP testing requirement with the approved permits outlined above. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeppaalaska.gov 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 Victoria Loepp at (907)793-1247 or Victoria. Loepp@alaska.gov w THE STATE 01ALASKA GOVERNOR BILL WALKER J. Burke CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Alaska Oil and Gas 0-1 Conservation Co 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3F -12L1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-058 Surface Location: 5238' FNL, 136' FEL, SEC. 19, T12N, R9E, UM Bottomhole Location: 176' FNL, 2325' FEL, SEC. 30, T12N, R9E, UM Dear Mr. Burke: Enclosed is the approved application for permit to redrill the above referenced service well. The permit is for a new wellbore segment of existing well Permit No. 185-273, API No. 50-029- 21483-00-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, 142_�Z� Vt� Cathy P. 7oerster Chair DATED this � of April, 2016. STATE OF ALASKA AL <A OIL AND GAS CONSERVATION COMM. ON PERMIT TO DRILL 20 AAC 25.005 RECEIVED APR 11 2016, ')rr 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑✓ Service - Disp ❑ 1 c. Specify if well is proposed for: Drill ❑ Lateral. ❑� Stratigraphic Test ❑ Development - Oil ❑ Service - Winj ❑ Single Zone ❑' - Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑✓ - Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc , Bond No. 5952180 KRU 3F-121-1 " 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 9350' TVD: 5913' Kuparuk River Field / Kuparuk River Oil Pool , 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 5238' FNL, 136' FEL, Sec 19, T12N, R9E, UM - ADL 25643 ocs�o 3 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1371' FNL, 3404' FEL, Sec 30, T12N, R9E, UM ALK 2574 4/25/2016 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 176' FNL, 2325' FEL, Sec 30, T12N, R9E, UM 2 0 �WO 13400' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 93' - 15. Distance to Nearest Well Open Surface: x- 508364 y- 5985865 Zone- 4 - GL Elevation above MSL (ft): 42' to Same Pool: 1535', 3F-15 16. Deviated wells: Kickoff depth: 7180 feet � 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 92 degrees Downhole: 4030 • Surface: 3451 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.6# L-80 STL 1710' 7640' 5868' 9350' 5913' Slotted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 7571' 6095' None 7338' 5916' None Casing Length Size Cement Volume MD TVD Conductor 77' 16" 316 sx AS II 115' 115' Surface 3254' 9-5/8" 925 sx PF "E" & 410 sx PF "C" 3292' 3032' Production 7505' 7" 150 sx Class G & 175 sx PF "C" 7540' 6070' Scab Liner 435' 4-1/2" 97 sx Class G 7425' 5983' Perforation Depth MD (ft): Planned pre -rig Perforation Depth TVD (ft): Planned pre -rig 7246'-7280' 5846'-5872' 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program Q Time v. Depth Plot ❑ Shallow Hazard Analysis ❑� Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 20 AAC 25.050 requir ents09 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact K. Herring @ 263-4321 Email Keith. E. Herrinq@cop.com Printed Name J. Burke Title CTD Engineering Supervisor Signature Phone 265-6097 Date Commission Use Only Permit to D Q —QS API Number: 50- Q w Permit Approval Date: See cover letter for other requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other:80,0 fC$ f fid 411 a n pS,S Samples req'd: Yes ❑ No[/ Mud log req'd: Yes ❑ No[' %% rtLiCt ` / t l/rv, trr ¢�S t fa Z J o0 X75 lC9 HZS measures: Yes z No El Directional svy req'd: Yes [� No ❑ SpaGjd exception req'd: Yes ❑ Nov Inclination -only svy req'd: Yes ❑ jl-Z Post initial injection MIT req'd: Yes No ❑ Approved by: APPROVED BY COMMISSIONER THE COMMISSION Date: -401( �I11/ 01 G;lf( !\ �Submit Form and Form 10-401 (Revised 11/ 015) This permit is valid for t eI/�.C' nova (20 AAC 25.005(g)) Attachments in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 11, 2016 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill a quad -lateral out of the Kuparuk Well 3F-12 (PTD# 185-273) using the coiled tubing drilling rig, Nabors CDR2-AC:/ The work is scheduled to begin April 25, 2016. The CTD objective will be to drill four laterals (3F -12L1, 3F-121-1-01, 3F-121-1-02, & 3F-121-1- 03), targeting the Kuparuk A -sand intervals. The A and C sand perforationsWere cemented behind a 4-1/2" scab liner during the RWO in April 2016 and the A -sand will be re -perforated to allow for bottom hole pressure monitoring prior to CTD operations (Sundry# 316-167). Attached to this application are the following documents: — Permit to Drill Application Forms (10-401) for 3F-121-1, 3F-121-1-01, 3F -12L1-02, & 317-121-1-03 — Detailed Summary of Operations — Directional Plans for 3F-121-1, 3F-121-1-01, 3F-121-1-02, & 3F-121-1-03 — Current wellbore schematic — Proposed wellbore schematic If you have any questions or require additional information, please contact me at 907-263-4321. Sincerely, Keith Herring Coiled Tubing Drilling Engineer Kuparuk CTD Laterals NABOAS ALASKA 3F -12L1, L1-01, L1-02, & L1-03 Application for Permit to Drill Document .9AC 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b))................................................................................................................... 2 2. Location Summary.......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2)).................................................................................................................................................. 2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3))................................................................................................................................................. 2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4))................................................................................................................................................. 2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5)).................................................................................................................................................. 2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6)).................................................................................................................................................. 3 7. Diverter System Information.......................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(7)).................................................................................................................................................. 3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(8)).................................................................................................................................................. 3 9. Abnormally Pressured Formation Information............................................................................. 4 (Requirements of 20 AAC 25.005(c)(9)).................................................................................................................................................. 4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................ 4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................ 4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................ 4 13. Proposed Drilling Program............................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................ 4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................6 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 6 (Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 6 16. Quarter Mile Injection Review........................................................................................................ 6 (Requirements of 20 AAC 25.402).......................................................................................................................................................... 6 17. Attachments.................................................................................................................................... 8 Attachment 1: Directional Plans for 3F-121-1, 3F-121-1-01, 3F -12L1-02, & 3F -12L1-03 ..................................................8 Attachment 2: Current Well Schematic for 3F-12............................................................................................................7 Attachment 3: Proposed Well Schematic for 3F -12L1, 3F-121-1-01, 317-121-1-02, & 31F-121-1-03 ....................................7 Page 1 of 7 April 11, 2016 PTD Application: 3F-121-1, 1-1-01, 1-1-02, & L1-03 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 3F-121-1, L1-01, L1-02, & L1-03. All laterals will be classified as "Service — WAG" wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 3F-121-1, 1-1-01, 1-1-02, & 1-1-03. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 50 si to 40D1Z-psi. Using the maximum formation pressure in the area of 4030 psi in 3F-15 (i.e. 13.7 ppg EMW), the maximum potential surface pressure in 3F-12, assuming a gas gradient of 0.1 psi/ft, would be 3451 psi./ See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 3F-12 was measured to be 3536 psi (11.7 ppg EMW) on 3/18/2016. The maximum downhole pressure in the 3F-12 vicinity is directly north in the 3F-15 injector at 4030 psi (13.7 ppg EMW) measured in September 2015. The lowest downhole pressure in the 3F-12 vicinity is to the west in the 3G-08 producer at 2485 psi (8.3 ppg EMW) measured in January 2016. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) MI gas injection is prevalent at both 3F and 3G pads, there is the potential of encountering free gas while drilling the 3F-12 laterals. If significant gas is detected in the returns, the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 3F-12 laterals will be shale instability at large fault crossings. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with the fault crossing. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 317-12 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 7 April 11, 2016 PTD Application: 3F-121-1, 1-1-01, 1-1-02, & 1-1-03. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Top MD Name MD MD TVDSS TVDSS Liner Details 3F -12L1 7640' 9350' 5775' 5820' 2%", 4.7#, L-80, ST -L slotted liner; 0' 115' 1640 670 Surface aluminum billet on top 3F-121_1-01 7340' 9350' 5778' 5787' 2%", 4.7#, L-80, ST -L slotted liner; 3033' 3520 2020 Production 7" aluminum billet on top 3F-121_1-02 7550' 9150' 5773' 5772' 2%", 4.7#, L-80, ST -L slotted liner; 4980 4320 Tubing 3-1/2" 9.3 aluminum billet on to 31F-121_1-03 7175' 9200' 5699' 5726' 2'/", 4.7#, L-80, ST -L slotted liner; 10540 Scab Liner 4-1/2" 12.6 L-80 deployment sleeve on top Existing Casing/Liner Information Category OD Weight (ppf) Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 Welded 38' 115' 0' 115' 1640 670 Surface 9-5/8" 36.0 J-55 BTC 37' 3292' 0' 3033' 3520 2020 Production 7" 26.0 J-55 BTC 35' 7540' 0' 6071' 4980 4320 Tubing 3-1/2" 9.3 L-80 EUE 8rd33' 7037' 0' 5688' 10180 10540 Scab Liner 4-1/2" 12.6 L-80 BTC 6991' 7425' 5653' 5983' 1 8430 1 7500 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride -based FloVis mud (8.6 ppg) — Drilling operations: Chloride -based FloVis mud (8.6 ppg). z This mud weight will not hydrostatically overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The 3F-12 well will be loaded with 11.8 ppg NaBr completion fluid in order to provide formation over -balance and maintain wellbore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 3F-12 laterals we will target a constant BHP of 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be Page 3 of 7 April 11, 2016 PTD Application: ;3F -12L1, U-01, L1-02, & L1-03. employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 3F-12 Window (7180' MD, 5796' TVD) Usinci MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 3F-12 is a Kuparuk A-sand/C-sand injection (service) well equipped with 3'h" tubing and 7" production casing. The well was worked over by cementing a 4 ''/2" scab liner in place and completed with a new 3 '/2" completion. The scab liner covered the A -sand and C -sand perforations and was cemented in place. Four CTD laterals will be drilled from the 3F-12, two to the east and two to the south, with the laterals targeting the Kuparuk A2-sand/A3-sands. The 3F-12LI lateral will exit through the 4'/2" scab liner and 7" casing at 7180' MD and TD at 9350' MD, targeting the A2 sand. It will be completed with 23/8" slotted liner from TD up to 7640' MD with aluminum billet for kicking off the 317-121-1-01 lateral. The 3F -12L1-01 lateral will drill east to a TD of 9350' MD targeting the A3 sand. It will be completed with 23/8" slotted liner from TD up to 7340' MD with an aluminum billet for kicking off the 3F-121-1-02 lateral. Page 4 of 7 April 11, 2016 Pumps On (1.5 bpm) Pumps Off A -sand Formation Pressure 11.7p 3526 psi 3526 psi Mud Hydrostatic (8.6 2591 psi 2591 psi Annular friction i.e. ECD, 0.080psi/ft) 574 psi 0 psi Mud + ECD Combined (no choke pressure) 3165 psi (underbalanced -361 psi) 2591 psi (underbalanced -935psi) Target BHP at Window (11.8 p 3556 psi 3556 psi Choke Pressure Required to Maintain Target BHP 391 psi 965 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 3F-12 is a Kuparuk A-sand/C-sand injection (service) well equipped with 3'h" tubing and 7" production casing. The well was worked over by cementing a 4 ''/2" scab liner in place and completed with a new 3 '/2" completion. The scab liner covered the A -sand and C -sand perforations and was cemented in place. Four CTD laterals will be drilled from the 3F-12, two to the east and two to the south, with the laterals targeting the Kuparuk A2-sand/A3-sands. The 3F-12LI lateral will exit through the 4'/2" scab liner and 7" casing at 7180' MD and TD at 9350' MD, targeting the A2 sand. It will be completed with 23/8" slotted liner from TD up to 7640' MD with aluminum billet for kicking off the 317-121-1-01 lateral. The 3F -12L1-01 lateral will drill east to a TD of 9350' MD targeting the A3 sand. It will be completed with 23/8" slotted liner from TD up to 7340' MD with an aluminum billet for kicking off the 3F-121-1-02 lateral. Page 4 of 7 April 11, 2016 PTD Application: 3F -12L1, L1-01, L1-02, & L1-03. The 3F -012L1-02 lateral will drill south to a TD of 9150' MD targeting the A2 sand. It will be completed with 23/8" slotted liner from TD up to 7550' MD with an aluminum billet for kicking off the 3F -12L1-03 lateral. The 3F -12L1-03 lateral will drill south to a TD of 9200' MD targeting the A3 sand. It will be completed with 23/8" slotted liner from TD up to 7175' MD with a deployment sleeve just inside the 4'/2" scab liner, 5' above the top of whipstock. Pre -CTD Work 1. RU Slickline: Obtain an A -sand SBHP, drift a dummy whip -stock. 2. RU E -line: Perforate 4'/2" Scab liner for bottom hole pressure monitoring and set Baker Hughes 3'h" x 4'/2" thru-tubing whip -stock at 7180' MD 3. Prep site for Nabors CDR2-AC, including setting BPV. Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3F -12L1 Lateral (A2 sand - east) a. Mill 2.80" window at 7180' MD. b. Drill 3" bi-center lateral to TD of 9350' MD. c. Run 23/8" slotted liner with an aluminum billet from TD up to 7640' MD. 3. 3F -12L1-01 Lateral (A3 sand - east) a. Kick off of the aluminum billet at 7640' MD. b. Drill 3" bi-center lateral to TD of 9350' MD. c. Run 23/8" slotted liner from TD up to 7340' MD. 4. 3 F -12L 1-02 Lateral (A2 sand -south) a. Kick off of the aluminum billet at 7340' MD. b. Drill 3" bi-center lateral to TD of 9150' MD. c. Run 23/8" slotted liner from TD up to 7550' MD. 5. 3 F -12L 1-03 Lateral (A3 sand -south) a. Kick off of the aluminum billet at 7550' MD. b. Drill 3" bi-center lateral to TD of 9200' MD. c. Run 23/8" slotted liner from TD back into the 4 1/2" scab liner at 7175' MD. 6. Freeze protect. Set BPV, ND BOPE. RDMO Nabors CRD2-AC. Post -Rig Work 1. Pull BPV. ` 2. Pre -produce for less than 30 days 3. Return to injection. Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure, so installed in this well is a deployment valve. This valve, when closed using hydraulic control lines from surface, isolates the well pressure and allows long BHA's to be deployed/un-deployed without killing the well. Page 5 of 7 April 11, 2016 PTD Application: 3F -12L1, L1-01, L1-02, & L1-03. If the deployment valve fails, operations will continue using the standard pressure deployment process. A system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse Liner Running — The 3F-12 laterals will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. — While running 2%" slotted liner, a joint of 2%" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 23/" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plan — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section., — Distance to Nearest Property Line (measured to KPA boundary at closest point) Latecai Name IDistance Page 6 of 7 April 11, 2016 PTD Application: 3F -12L1, L1-01, L1-02, & L1-03. 3F-121_1 13400' 3F -12L1-01 13400' 3F-121_1-02 13200' 3F-121_1-03 13100' — Distance to Nearest Well within Pool Lateral Name Distance Well 3F-121_1 1535' 3F-15 3F -12L1-01 1535' 3F-15 3F-121-1-02 1945' 3F-11 3F-121_1-03 1945' 317-11 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) There are no wells within'/4-mile of the 3F -12L1, L1-01, U-02, and L1-03 laterals 3F-12 (mother bore) Injector • Classified as a "Normal Well" • The well is completed with 3.5" 9.3# L-80 tubing, 4.5" 12.6# L-80 scab liner, and 7" 26# J-55 production casing. • The scab liner was recently installed on a rig workover. The liner was cemented in place with 97 sx of class "G" cement and the A -sand will be re -perforated from 7246' to 7280' MD (Sundry# 316-167) to allow for bottom hole pressure monitoring. • The packer is located at 6991' MD which is more than 200' away from the A -sand re -perforations. However, the window exit for the laterals is planned to be 189' from the packer. • A -sand perforations (cemented): 7246'— 7280' MD • C -sand perforations (cemented): 7116'— 7146' MD • Production casing was cemented with 150 sx of class "G" cement and 175 sx of PF "C". 17. Attachments Attachment 1: Directional Plans for 3F -12L1, 3F -12L1-01, 3F -12L1-02, & 3F-121_1-03 Attachment 2: Current Well Schematic for 3F-12 Attachment 3: Proposed Well Schematic for 3F -12L1, 3F -12L1-01, 3F-121_1-02, & 3F -12L1-03 Page 7 of 7 April 11, 2016 ConocoPhillips Project: Kuparuk River Unit Site: Kuparuk 3F Pad Azimuths to True North Magnetic North. 18.27' WELLBORE DETAILS: 3F -12L1 REFERENCE INFORMATION Well: 3F-12 Magnetic Field Parent Wellbore: 3F-12 Coordinate (NfE) Reference: Well 3F-12, True North Wellbore: 3F-121-1 Strength: 67486.2snr Dip Tie on MD: 7100.00 Vertical (TVD) Reference: 3F-12 sg (3F-12) Plan: 3F-121-1 wp06 (3F -1213F-121-1) atAngle: 112016 Date: G 2016 Model: aGGM2016 O. ON, 0. Section (VS)Reference: Slot -(O.00N, O.00E) Measured Depth Reference: 3F-12 93.00usft 3F-12 P ( ) Calculafion Method: Minimum Curvature ri.1 BAKER HUGHES West( -)/East(+) (200 usft/in) ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3F Pad 3F-12 3F-121-1 Plan: 3F -12L1 wp06 Standard Planning Report 31 March, 2016 WON" I BAKER HUGHES ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3F-12 Mean Sea Level 3F-12 @ 93 00usft (3F-12) True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor WIN .I BAKER HUGHES Site Kuparuk 3F Pad Site Position: Northing: 5,985,734.46 usft Latitude: 70° 22'20.081 N From: Map Easting: 508,662.33 usft Longitude: 149° 55'46.550 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.07 I Well 3F-12 31F-121-1 ConocoPhillips Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3F Pad Well: 3F-12 Wellbore: 3F-121-1 Design: 3F-12L1_wp06 ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3F-12 Mean Sea Level 3F-12 @ 93 00usft (3F-12) True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor WIN .I BAKER HUGHES Site Kuparuk 3F Pad Site Position: Northing: 5,985,734.46 usft Latitude: 70° 22'20.081 N From: Map Easting: 508,662.33 usft Longitude: 149° 55'46.550 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.07 I Well 3F-12 31F-121-1 Well Position +N/ -S 0.00 usft Northing: 5,985,865.19 usft Latitude: 70° 22'21.370 N +E/ -W 0.00 usft Easting: 508,364.05 usft Longitude: 1490 55' 55.273 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 31F-121-1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 7/1/2016 18.27 80.98 57,486 Dogleg Build Turn Design 3F-12L1_wp06 Azimuth System Audit Notes: +E/ -W Rate Rate Version: Phase: PLAN Tie On Depth: 7,100.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (°/100ft) (usft) (usft) (usft) (I 7,100.00 0.00 0.00 0.00 45.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/ -S +E/ -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100ft) (°/100ft) (°/100ft) (°) Target 7,100.00 40.72 242.85 5,642.68 -1,388.49 -3,216.77 0.00 0.00 0.00 0.00 7,180.00 40.66 242.78 5,703.34 -1,412.32 -3,263.16 0.09 -0.07 -0.09 -142.77 7,200.00 44.34 245.78 5,718.08 -1,418.17 -3,275.34 21.00 18.39 15.02 30.00 7,308.39 84.00 265.97 5,764.76 -1,438.46 -3,368.11 40.00 36.59 18.63 30.00 7,379.13 84.72 294.40 5,771.85 -1,426.13 -3,436.68 40.00 1.02 40.19 90.00 7,450.00 90.06 322.28 5,775.14 -1,382.63 -3,491.61 40.00 7.54 39.34 80.00 7,570.00 90.04 10.28 5,775.03 -1,269.44 -3,519.25 40.00 -0.02 40.00 90.00 7,740.00 90.04 22.18 5,774.90 -1,106.51 -3,471.81 7.00 0.00 7.00 90.00 8,140.00 85.36 49.82 5,791.26 -786.29 -3,239.36 7.00 -1.17 6.91 100.00 8,540.00 86.37 77.87 5,820.68 -612.26 -2,884.83 7.00 0.25 7.01 89.00 8,800.00 90.27 60.09 5,828.35 -519.39 -2,643.28 7.00 1.50 -6.84 282.00 9,000.00 90.75 46.09 5,826.57 -399.58 -2,483.77 7.00 0.24 -7.00 272.00 9,350.00 91.51 70.59 5,819.58 -217.30 -2,188.19 7.00 0.22 7.00 88.00 3/31/2016 7: 59 09A Page 2 COMPASS 5000.1 Build 74 ConocoPhillips WGitI ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3F Pad Well: 3F-12 Wellbore: 3F-121-1 Design: 3F-12L1_wp06 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3F-12 Mean Sea Level 3F-12 @ 93.00usft (3F-12) True Minimum Curvature Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N1 -S +Ei-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°l100ft) (°) (usft) (usft) 7,100.00 40.72 242.85 5,642.68 -1,388.49 -3,216.77 -3,256.41 0.00 0.00 5,984,473.25 505,149.16 TIP 7,180.00 40.66 242.78 5,703.34 -1,412.32 -3,263.16 -3,306.07 0.09 -142.77 5,984,449.37 505,102.79 KOP 7,200.00 44.34 245.78 5,718.08 -1,418.17 -3,275.34 -3,318.81 21.00 30.00 5,984,443.51 505,090.63 End 21 dls, Start 40 dls 7,300.00 80.86 264.78 5,763.65 -1,437.79 -3,359.83 -3,392.43 40.00 30.00 5,984,423.79 505,006.17 7,308.39 84.00 265.97 5,764.76 -1,438.46 -3,368.11 -3,398.76 40.00 20.73 5,984,423.11 504,997.88 4 7,379.13 84.72 294.40 5,771.85 -1,426.13 -3,436.68 -3,438.53 40.00 90.00 5,984,435.36 504,929.31 5 7,400.00 86.22 302.64 5,773.51 -1,416.20 -3,454.94 -3,444.42 40.00 80.00 5,984,445.27 504,911.04 7,450.00 90.06 322.28 5,775.14 -1,382.63 -3,491.61 -3,446.61 40.00 79.35 5,984,478.79 504,874.33 6 7,500.00 90.06 342.28 5,775.09 -1,338.59 -3,514.75 -3,431.83 40.00 90.00 5,984,522.80 504,851.15 7,570.00 90.04 10.28 5,775.03 -1,269.44 -3,519.25 -3,386.11 40.00 90.02 5,984,591.95 504,846.57 End 40 dls, Start 7 dis 7,600.00 90.04 12.38 5,775.00 -1,240.02 -3,513.35 -3,361.14 7.00 90.00 5,984,621.37 504,852.44 7,700.00 90.04 19.38 5,774.93 -1,143.90 -3,486.00 -3,273.84 7.00 90.00 5,984,717.51 504,879.67 7,740.00 90.04 22.18 5,774.90 -1,106.51 -3,471.81 -3,237.36 7.00 90.01 5,984,754.92 504,893.82 8 7,800.00 89.31 26.32 5,775.24 -1,051.81 -3,447.18 -3,181.26 7.00 100.00 5,984,809.63 504,918.39 7,900.00 88.11 33.22 5,777.49 -965.08 -3,397.57 -3,084.86 7.00 99.98 5,984,896.41 504,967.89 8,000.00 86.93 40.12 5,781.83 -884.99 -3,337.95 -2,986.07 7.00 99.82 5,984,976.55 505,027.42 8,100.00 85.80 47.04 5,788.18 -812.75 -3,269.20 -2,886.37 7.00 99.52 5,985,048.87 505,096.09 8,140.00 85.36 49.82 5,791.26 -786.29 -3,239.36 -2,846.57 7.00 99.08 5,985,075.36 505,125.89 9 8,200.00 85.45 54.03 5,796.07 -749.41 -3,192.29 -2,787.21 7.00 89.00 5,985,112.29 505,172.92 8,300.00 85.64 61.05 5,803.85 -695.94 -3,108.22 -2,689.95 7.00 88.66 5,985,165.85 505,256.92 8,400.00 85.91 68.06 5,811.23 -653.12 -3,018.23 -2,596.03 7.00 88.12 5,985,208.76 505,346.86 8,500.00 86.23 75.07 5,818.10 -621.60 -2,923.64 -2,506.86 7.00 87.60 5,985,240.39 505,441.40 8,540.00 86.37 77.87 5,820.68 -612.26 -2,884.83 -2,472.82 7.00 87.12 5,985,249.77 505,480.19 10 8,600.00 87.26 73.76 5,824.01 -597.59 -2,826.76 -2,421.38 7.00 -78.00 5,985,264.51 505,538.24 8,700.00 88.75 66.92 5,827.50 -563.98 -2,732.71 -2,331.11 7.00 -77.77 5,985,298.21 505,632.24 8,800.00 90.27 60.09 5,828.35 -519.39 -2,643.28 -2,236.35 7.00 -77.53 5,985,342.89 505,721.62 11 8,900.00 90.51 53.09 5,827.67 -464.36 -2,559.86 -2,138.45 7.00 -88.00 5,985,398.01 505,804.97 9,000.00 90.75 46.09 5,826.57 -399.58 -2,483.77 -2,038.84 7.00 -88.05 5,985,462.87 505,880.98 12 9,100.00 90.98 53.09 5,825.06 -334.81 -2,407.68 -1,939.23 7.00 88.00 5,985,527.73 505,956.99 9,200.00 91.21 60.09 5,823.14 -279.79 -2,324.27 -1,841.35 7.00 88.11 5,985,582.84 506,040.33 9,300.00 91.41 67.09 5,820.85 -235.34 -2,234.79 -1,746.65 7.00 88.24 5,985,627.38 506,129.75 9;350.00 91.51 70.59 5,819.58 -217.30 -2,188.19 -1,700.93 7.00 88.40 5,985,645.47 506,176.33 Planned TD at 9350.00 3/31/2016 7,59:09AM Page 3 COMPASS 5000.1 Build 74 f ConocoPhillips RAN ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 317-12 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3F-12 @ 93.00usft (3F-12) Site: Kuparuk 3F Pad North Reference: True Well: 3F-12 Survey Calculation Method: Minimum Curvature Wellbore: 3F -12L1 0.00 -190.17 -799.28 Design: 3F-12L1_wp06 Point Targets Target Name hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting Shape (°) (I (usft) (usft) (usft) (usft) (usft) Latitude Longitude 3F -121-1_T01 0.00 0.00 5,723.00 -2,942.871,136,864.97 5,984,193.00 1,645,118.00 70° T49.566 N 140° 46' 15.745 W plan misses target center by 1139056.42usft at 9350.00usft MD (5819.58 TVD, -217.30 N, -2188.19 E) Point Point 3F-121-1 T03 0.00 0.00 5,748.00 -2,952.831,136,831.95 5,984,183.00 1,645,085.00 700 T49.518 N 140° 46' 16.731 W plan misses target center by 1139023.43usft at 9350.00usft MD (5819.58 TVD, -217.30 N, -2188.19 E) Point 3F-12 CTD Polygon Eas 3F -121-1T02 0.00 0.00 5,738.00 -2,948.851,136,846.96 5,984,187.00 1,645,100.00 700 T49.535 N 140° 46' 16.285 W plan misses target center by 1139038.42usft at 9350.00usft MD (5819.58 TVD, -217.30 N, -2188.19 E) Point 3F-12 CTD Polygon Eas 0.00 0.00 0.00 -2,837.871,136,877.09 5,984,298.00 1,645,130.00 70° 7' 50.568 N 140° 46' 14.945 W - plan misses target center by 1139083.15usft at 9350.00usft MD (5819.58 TVD, -217.30 N, -2188.19 E) 0.00 -190.17 -799.28 - Polygon 1,644,307.01 Point 0.00 -543.82 -1,157.70 Point 1 0.00 0.00 0.00 5,984,298.00 1,645,130.00 -1,776.83 -1,263.02 Point 0.00 -260.99 -38.28 5,984,036.99 1,645,092.02 -1,788.26 -862.99 Point 0.00 -232.64 -361.28 5,984,064.98 1,644,769.02 -576.28 -733.69 Point 0.00 107.48 -440.93 5,984,404.98 1,644,688.99 -344.00 -32.37 Point 0.00 580.28 -211.40 5,984,877.99 1,644,917.97 0.00 0.00 Point 0.00 1,487.63 1,425.73 5,985,787.07 1,646,553.92 -1,739.961,137,957.42 Point? 0.00 960.64 1,369.16 5,985,260.07 1,646,497.95 Point 0.00 253.03 -6.73 5,984,551.00 1,645,122.99 Point 0.00 0.00 0.00 5,984,298.00 1,645,130.00 70° T50.107 N 140'46'21.374 W 3F-121-1_Faultl 0.00 0.00 5,739.00 -2,949.851,136,846.96 5,984,186.00 1,645,100.00 700 T49.525 N 140° 46' 16.290 W plan misses target center by 1139038.42usft at 9350.00usft MD (5819.58 TVD, -217.30 N, -2188.19 E) Polygon Point 1 5,739.00 0.00 0.00 5,984,186.00 1,645,100.00 Point 5,739.00 1.00 1.00 5,984,187.00 1,645,101.00 3F -121-1_T06 0.00 0.00 5,828.00 -2,068.431,137,452.00 5,985,068.00 1,645,704.00 70° T57.192 N 140° 45'55.201 W plan misses target center by 1139641.69usft at 9350.00usft MD (5819.58 TVD, -217.30 N, -2188.19 E) Point 3F-121-1-02_Fault2 0.00 0.00 5,763.00 -3,058.231,136,285.78 5,984,077.00 1,644,539.00 70° T49.299 N 1400 46'32.778 W plan misses target center by 1138477.51 usft at 9350.00usft MD (5819.58 TVD, -217.30 N, -2188.19 E) Polygon Point 1 5,763.00 0.00 0.00 5,984,077.00 1,644,539.00 Point 5,763.00 1.00 1.00 5,984,078.00 1,644,540.00 3F -121-1_T05 0.00 0.00 5,777.00 -2,501.681,136,739.45 5,984,634.00 1,644,992.00 70° T54.035 N 140° 46'17.418 W plan misses target center by 1138929.93usft at 9350.00usft MD (5819.58 TVD, -217.30 N, -2188.19 E) Point 3F-12 CTD Polygon We; 0.00 0.00 0.00 -2,764.831,136,853.17 5,984,371.00 1,645,106.00 70° 7' 51.312 N 1400 46' 15.312 W plan misses target center by 1139059.07usft at 9350.00usft MD (5819.58 TVD, -217.30 N, -2188.19 E) Polygon Point 1 0.00 0.00 0.00 5,984,371.00 1,645,106.00 Point 0.00 -190.17 -799.28 5,984,179.96 1,644,307.01 Point 0.00 -543.82 -1,157.70 5,983,825.94 1,643,949.02 Point 0.00 -1,776.83 -1,263.02 5,982,592.94 1,643,845.09 Point 0.00 -1,788.26 -862.99 5,982,581.96 1,644,245.10 Point 0.00 -576.28 -733.69 5,983,793.96 1,644,373.03 Point 0.00 -344.00 -32.37 5,984,027.00 1,645,074.02 Point 8 0.00 0.00 0.00 5,984,371.00 1,645,106.00 3F-12L1_T07 0.00 0.00 5,820.00 -1,739.961,137,957.42 5,985,397.00 1,646,209.00 70° T59.636 N 140° 45' 39.349 W plan misses target center by 1140146.62usft at 9350.00usft MD (5819.58 TVD, -217.30 N, -2188.19 E) Point 3F -121-1_T04 0.00 0.00 5,775.00 -2,917.641,136,663.98 5,984,218.00 1,644,917.00 70° T50.107 N 140'46'21.374 W Ian misses target center by 1138855.36usft at 9350.00usft MD 5819.58 TVD -217.30 N -2188.19 E 313112016 7:59:09AM Page 4 COMPASS 5000.1 Build 74 Plan Annotations ConocoPhillips Vertical WE.. ConocoPhillips Planning Report (usft) BAKER 5,642.68 7,180.00 5,703.34 7,200.00 HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 3F-12 7,450.00 Company: ConocoPhillips (Alaska) Inc. -Kup2 ND Reference: Mean Sea Level 5,774.90 Project: Kuparuk River Unit MD Reference: 3F-12 @ 93 00usft (3F-12) 8,800.00 Site: Kuparuk 3F Pad North Reference: True 5,819.58 Well: 3F-12 Survey Calculation Method: Minimum Curvature -519.39 Wellbore: 3F -12L1 -399.58 -2,483.77 12 Design: 3F-121-1_wp06 Planned TD at 9350.00 - Point -- Casing Points -- Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 9,350.00 5,819.57 2 3/8" 2.375 3.000 Plan Annotations Measured Vertical Depth Depth (usft) (usft) 7,100.00 5,642.68 7,180.00 5,703.34 7,200.00 5,718.08 7,308.39 5,764.76 7,379.13 5,771.85 7,450.00 5,775.14 7,570.00 5,775.03 7,740.00 5,774.90 8,140.00 5,791.26 8,540.00 5,820.68 8,800.00 5,828.35 9,000.00 5,826.57 9,350.00 5,819.58 Local Coordinates +N/ -S +E/ -W (usft) (usft) Comment -1,388.49 -3,216.77 TIP -1,412.32 -3,263.16 KOP -1,418.17 -3,275.34 End 21 dls, Start 40 dls -1,438.46 -3,368.11 4 -1,426.13 -3,436.68 5 -1,382.63 -3,491.61 6 -1,269.44 -3,519.25 End 40 cls, Start 7 dls -1,106.51 -3,471.81 8 -786.29 -3,239.36 9 -612.26 -2,884.83 10 -519.39 -2,643.28 11 -399.58 -2,483.77 12 -217.30 -2.188.19 Planned TD at 9350.00 3/31/2016 7:59:09AM Page 5 COMPASS 5000.1 Build 74 ® Baker Hughes INTEQ WIN., ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 3F Pad Site Error: 0.00 usft Reference Well: 3F-12 Well Error: 0.00 usft Reference Wellbore 3F-121_1 Reference Design: 3F-121_1_wp06 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3F-12 3F-12 @ 93.00usft (3F-12) 3F-12 @ 93.00usft (3F-12) True Minimum Curvature 1.00 sigma OAKEDMP2 Offset Datum teference 3F-12L1_wp06 Ater type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference iterpolation Method: MD Interval 25.00usft Error Model: ISCWSA )epth Range: 7,100.00 to 9,350.00usft Scan Method: Tray. Cylinder North results Limited by: Maximum center -center distance of 1,125.70 usft Error Surface: Elliptical Conic Survey Tool Program Date 3/30/2016 From To (usft) (usft) Survey (Wellbore) Tool Name Description 100.00 7,100.00 3F-12 (3F-12) GCT -MS Schlumberger GCT multishot 7,100.00 9,350.00 3F-12L1_wp06(3F-121-1) MWD MWD - Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 9,350.00 5,912.57 2 3/8" 2-3/8 3 Summary Kuparuk 3F Pad - 3F-12 - 3F-12 - 3F-12 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) Vertical (usft) Vertical Kuparuk 3F Pad Offset Toolface + Offset Wellbore Centre Casing - Centre to 3F-11 - 3F-11 - 3F-11 Allowable Depth Depth Depth Depth Out of range 3F-12 - 3F-12 - 3F-12 7,199.96 7,200.00 0.73 3.90 -2.95 FAIL - Major Risk 3F-12 - 3F-121-1-01 - 3F-121-1-01wp01 7,650.00 7,650.00 0.09 0.49 -0.19 FAIL - Minor 1/10 3F-12 - 3F-1 21-1-02 - 3F-1 2L1-02_wp02 7,100.00 7,100.00 0.00 0.22 -0.22 FAIL - Minor 1/10 3F-12 - 3F-121-1-03 - 3F-12L1-03_wp01 7,100.00 7,100.00 0.00 0.22 -0.22 FAIL - Minor 1/10 3F-15 - 3F-15 - 3F-15 -3,231.28 2-11/16 0.00 1.12 -1.00 FAIL - Major Risk, CC Out of range 3F-16 - 3F-16 - 3F-16 7,150.00 5,773.58 0.16 0.32 -135.14 Out of range 3F-16 - 3F-16AL1 - 3F-16AL1 2-11/16 0.00 2.01 -1.78 FAIL- Major Risk 7,175.00 Out of range 3F-16 - 3F-16AL1-01 - 3F-16AL1-01 5,792.54 0.24 0.48 -135.14 -1,410.83 Out of range 3F-16 - 3F-16AL1 P131 - 3F-16AL1 PB1 0.00 2.90 -2.56 FAIL - Major Risk 7,199.96 5,811.06 Out of range 3F-18 - 3F-18AL2 - 3F-18AL2 0.26 0.64 93.86 -1,418.28 -3,274.75 Out of range Offset Design Kuparuk 3F Pad - 3F-12 - 3F-12 - 3F-12 Onset site Error: 0 00 use Survey Program: 100 -GCT -MS Rule Assigned: Major Risk Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface + Offset Wellbore Centre Casing - Centre to No Go Allowable Depth Depth Depth Depth Azimuth +N/.S +E/ -W Hole Size Centre Distance Warning Deviation (usft) (usft) (usft) (usft (usft) (usft) (°) (usft) (usft) ('7 (usft) (usft) (usft) 7,125.00 5,754.63 7,125.00 5,754.63 0.08 0.16 -135.14 -1,395.93 -3,231.28 2-11/16 0.00 1.12 -1.00 FAIL - Major Risk, CC 7,150.00 5,773.58 7,150.00 5,773.58 0.16 0.32 -135.14 -1,403.38 -3,245.78 2-11/16 0.00 2.01 -1.78 FAIL- Major Risk 7,175.00 5,792.54 7,175.00 5,792.54 0.24 0.48 -135.14 -1,410.83 -3,260.27 2-11/16 0.00 2.90 -2.56 FAIL - Major Risk 7,199.96 5,811.06 7,200.00 5,811.51 0.26 0.64 93.86 -1,418.28 -3,274.75 2-11/16 0.73 3.90 -2.95 FAIL- Major Risk, ES, SF 7,224.22 5,827.09 7,225.00 5,830.48 0.27 0.80 96.73 -1,425.74 -3,289.23 2-11/16 4.68 5.33 -0.49 FAIL - Major Risk 7,246.62 5,839.29 7,250.00 5,849.45 0.27 0.96 99.17 -1,433.21 -3,303.70 2-11/16 12.61 664 6,13 Pass - Major Risk 7,266.41 5,847.74 7,275.00 5,868.43 0.28 1.12 101.31 -1,440.68 -3,318.15 2-11/16 23.93 7.74 16.40 Pass- Major Risk 7,283.41 5,853,14 7,300.00 5,887.41 0.30 1.28 103.22 -1,448.16 -3,332.60 2-11/16 38.03 8.64 29.67 Pass - Major Risk 7,297.76 5,856.28 7,325.00 5,906.41 0.31 1.44 104.91 -1,455.63 -3,347.02 2-11/16 54.33 9.39 45.33 Pass- Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 3/30/2016 3:46:13PM Page 2 COMPASS 5000.1 Build 74 Project: Kuparuk River Unit Site: Kuparuk 3F Pad Well: 3F.12 Wellbore: 3F-121-1 ConocoPhillips Plan: 31`4211_wp06 (3F -12/31F-1121-1) WELL DETAILS: 3F-12 +N/ -S +E/ -W Northing Easting Latitude 0.00 0.00 5985865.19 508364.05 70' 22'21.370 N Sec MID Inc Azi TVDSS +N/ -S +E/ -W Dleg TFace VSect 1 7100.00 40.72 242.85 5642.68 -1388.49 -3216.77 0.00 0.00-3256.41 2 7180.00 40.66 242.78 5703.34 -1412.32 -3263.16 0.09 -142.77 -3306.07 3 7200.00 44.34 245.78 5718.08 -1418.17 -3275.34 21.00 30.00-3318.81 4 7308.39 84.00 265.97 5764.76 -1438.46 -3368.11 40.00 30.00 -3398.76 5 7379.13 84.72 294.40 5771.85 -1426.13 -3436.68 40.00 90.00 -3438.53 6 7450.00 90.06 322.28 5775.14 -1382.63 -3491.61 40.00 80.00-3446.61 7 7570.00 90.04 10.28 5775.03 -1269.44 -3519.25 40.00 90.00-3386.11 8 7740.00 90.04 22.18 5774.90 -1106.51 -3471.81 7.00 90.00 -3237.36 9 8140.00 85.36 49.82 5791.26 -786.29 -3239.36 7.00 100.00 -2846.57 10 8540.00 86.37 77.87 5820.68 -612.26 -2884.83 7.00 89.00 -2472.82 11 8800.00 90.27 60.09 5828.35 -519.39 -2643.28 7.00 282.00 -2236.35 12 9000.00 90.75 46.09 5826.57 -399.58 -2483.77 7.00 272.00 -2038.84 13 9350.00 91.51 70.59 5819.58 -217.30 -2188.19 7.00 88.00 -1700.93 535 54f 552 555 565 572 7t- 578 585 591 599 604 611 Mean Sea Avrnutl, " True North WELLBORE DETAILS: 3F -12L1 Magnetic18.27' . 27.k! Parent Wellbore: 3F-12 .',an H, 7 �'.2'-"Tl gMMV'j� Dip Angle' aD.9a' Tlue on MD: 7100.00 Dale: 7/12016 -, Model BGGM20151 -1L5v Longitude 149' 55' 55.273 W Annotation TIP KOP End 21 d1s, Start 40 dIs 4 5 6 End 40 cls, Start 7 dIs 8 9 10 11 12 Planned TD at 9350.00 501 251 -25( -50( -75( -100( ,=-125( .-:150( zO -200( ':5-225( O -250C -275( -300C -325C REFERENCE INFORMATION Co-ordinate (N/E Reference Well 3F-12, True North Verticil (TVD) Reference: Mean Sea Level BAKER a I section (VS) Reference: Slot - (O.00N. O.00E) Measured Depth Reference: 3F-12 @ 93.00ustt (3F-12) BAKER Calculation Method: Minimum Curvature HUGHES 5 Pla ned TE, at 935 .00 ---- ---- ---- ---.. I— "' - -West(-)/East(+) (250 us in)_____ -, - --v -1L5v -1 F- 12/3 F- 121, M --- - ----- - 31 -12/3F 12L7- I 3P 317-12L 1 -T06 12 --- F/d 40 dls Ste 7 F-12 1 T05 *' 1 0 FTanned,TDat9350,OC 3F.12/3F- 2LI /3F End 40 dis Start dls 3F-121,1 02 1 ault2 3F-121- ault] TIP Lev - 1900 -3835 -3770 -3705 -3640 -3575 3F-12 I_TO nd 21 dIs, St, rt 40 d s -3445 -3380 -3315 -3250 -3185 .3120 -3055 -2990 -2021 - -2X60 a71A -171A -11xzc 3F-121-1 T( I • 5 3F-121,1 TO:- 3F-1211TO3 3 -'-12LI Fault] ;F -12L -02-F ult2 3F -1/3F-12-1-03 - ..-..-- - --------- ------- ----- 3F I 23F-k2I 1 01 5 --- ---- ---- ---- ---.. I— "' - -West(-)/East(+) (250 us in)_____ -, - --v -1L5v -1 3 3F-121 1-03 1 -12/ F-12 1-02 '71 5 4 6' -TIP K( IP Enc 21 d1s Stan 8i 3P 12/3F- 2LI-01 F/d 40 dls Ste 7 dis 1 0 FTanned,TDat9350,OC 3F.12/3F- 2LI /3F 3F-121,1 02 1 ault2 3F-121- ault] Lev - 1900 -3835 -3770 -3705 -3640 -3575 -3510 -3445 -3380 -3315 -3250 -3185 .3120 -3055 -2990 -2021 - -2X60 a71A -171A -11xzc 00 -15bV -1495 -1430 -1365 Vertical Section at 45.00' (65 usft/in) 3F-12 Post RWO Schematic 16" 62# H-40 shoe at 115' MD 9-5/8" 36# J-55 shoe at 3292' MD C -sand perfs (sqz'd) 7116'- 7146' MD Proposed KOP at 7180' MD A -sand perfs (sqz'd) 7246'- 7280' MD 7" 26# J-55 shoe at 7540' MD 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" MMG SOV RKP latch @ 6885' RKB 3-1/2" X -nipple @ 6946' RKB (2.813" min ID) Baker 80/40 seal assembly @ 6997' RKB Baker ZXP packer @ 6991' MD Baker Flexlock liner hanger at 7011' RKB Baker type 1 landing collar @ 7338' RKB 4'/2', scab liner cemented in place ** Two KO joints 7131' - 7213' RKB " No centralizers on these 2 kickout joints. All other 4%" joints to be centralized. A -sand re-perf 7246'- 7280' post-RWO for SBHP monitoring (Sundry# 316-167) 3F-12 Proposed CTD Schematic 16" 62# H-40 shoe at 115' MD 5/8" 36# J-55 3292' MD C -sand perfs (sqz'd) 7116'- 7146' MD 3F-121-1-02, Planned TD = 9150' MD 2%" slotted liner with billet at 7550 MD Proposed KOP at 7180' MD 3F -12L1-03, Planned TD = 9200' MD 23/" slotted liner with top at 7175 MD A -sand perfs (sgz'd) 7246'- 7280' MD 7" 26# J-55 shoe at 7540' MD 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" MMG SOV RKP latch @ 6885' RKB 3-1/2" X -nipple @ 6946' RKB (2.813" min ID) Baker 80/40 seal assembly @ 6997' RKB Baker ZXP packer @ 6991' RKB Baker Flexlock liner hanger at 7011' RKB Baker type 1 landing collar @ 7338' RKB C/2'. scab liner cemented in place ** Two KO joints 7131'- 7213' RKB ** No centralizers on these 2 kickout joints. All other 4'/s" joints to be centralized. A -sand reperf 7246'_ 7280' post-RWO for SBHP monitoring (Sundry# 316-167) 3F-121 1-01, Planned TD = 9350' MD 2%" slotted liner with billet at 7340' MD 3F-121-.1, Plan�with 9350' MD 2%" slotted linllet at 7640' MD TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: �l (� — US -Y Development V Service _ Exploratory _ Stratigraphic Test Non -Conventional FIELD:�VEf POOL: /��%— ►�l/ �J r 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. 185 - a 3 , API No. 50-Qa9 -_&Lq$3 (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 ( PH) and API number (50-_- 50-- -_) from records, data and logs acquired for well - ___) (name onpermit). 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 weld 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 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL -490100 Well Name: KUPARUK RIV UNIT 3F -12L1 Program SER Well bore seg d❑ PTD#:2160580 Company CONOCOPHILLIPS ALASKA INC _ Initial Class/Type SER /_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 1 Permit fee attached NA 2 Lease number appropriate Yes 3 Unique well name and number Yes 4 Well located in a defined pool Yes 5 Well located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells Yes 7 Sufficient acreage available in -drilling unit Yes 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes Appr Date 11 Permit can be issued without conservation order Yes 12 Permit can be issued without administrative approval Yes PKB 4/12/2016 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_ Yes 15 All wells within 1/4 mile area of review identified (For service well only) Yes 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) Yes 18 Conductor string provided NA_ Engineering 19 Surface casing protects all known USDWs NA 20 CMT vol_ adequate to circulate on conductor & surf csg NA 21 CMT vol adequate to tie-in long string to surf csg NA 22 CMT will cover all known productive horizons_ No 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes 25 If a re -drill, has a 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes 27 If diverter required, does it meet regulations NA Appr Date 28 Drilling fluid program schematic & equip list adequate Yes VTL 4/13/2016 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes 31 Choke manifold complies w/API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of 1-12S gas probable Yes 34 Mechanical condition of wells within AOR verified (For service well only) Yes 35 Permit can be issued w/o hydrogen sulfide measures No Geology 36 Data presented on potential overpressure zones Yes Appr Date 37 Seismic analysis of shallow gas zones NA PKB 4/12/2016 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] _NA Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date ADL0025632, Surf Loc; ADL0025643, Top Prod Intery & TD. KRU 3F-121_1 KUPARUK RIVER, KUPARUK RIV OIL - 490100, governed by Conservation Order No. 432D. CO 432D contains no spacing restrictions with respect to drilling unit boundaries. CO 432D has no interwell spacing restrictions. Wellbore will be more than 500' from an external property line where ownership or landownership changes. AIO 2C-Kuparuk River Unit KRU 3F-121_1 Pre -produce for less than 30 days._ Conductor set in KRU 3F-12 Surface casing set in KRU 3F-12 Surface casing set and fully cemented Productive interval will be completed with uncemented slotted liner Rig has steel tanks; all waste to approved disposal wells Anti -collision analysis complete; no major risk failures Max formation pres_ is 4030 psig(13.7 ppg EMW); will drill w/ 8.6 ppg EMW and maintain overbal w/ MPD MPSP is 3451 psig; will test BOPS to 4000 psig H2S measures required AOR complete: no other wells within 1/4 mile radius Wells on 3F -Pad are H2S-bearing. H2S measures required. Max. potential reservoir pressure is 13.7 ppg EMW; will be drilled using 8.6 ppg mud and MPD technique. MI gas injection is prevalent at 3F -Pad. There is potential of encountering free gas while drilling. Onshore service lateral to be drilled.