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Home My WebLink About218-117MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, May 19, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 16-14C PRUDHOE BAY UNIT 16-14C Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/19/2023 16-14C 50-029-20570-03-00 218-117-0 G SPT 8627 2181170 2157 1964 1969 1970 1970 121 160 162 162 4YRTST P Guy Cook 4/3/2023 Testing completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 16-14C Inspection Date: Tubing OA Packer Depth 0 2649 2596 2580IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230402112625 BBL Pumped:5.7 BBL Returned:6 Friday, May 19, 2023 Page 1 of 1          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y Anne Prysunka at 3:59 pm, Oct 04, 2022 'LJLWDOO\VLJQHGE\'DYLG%MRUN '1FQ 'DYLG%MRUN RX 8VHUV 5HDVRQ,DPDSSURYLQJWKLV GRFXPHQW 'DWH 'DYLG%MRUN DSR-10/4/22 RBDMS JSB 100522 MGR19OCT2022 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name: Authorized Title: Authorized Signature: Date: Contact Name: Contact Email: Contact Phone: COMMISSION USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE COMMISSIONCOMMISSIONER PBU 16-14C Convert WAG to GI Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 218-117 50-029-20570-03-00 N/A ADL 0028327, 028332 16908 Conductor Surface Intermediate Production Liner 8983 80 2642 7454 2957 16820 20" 13-3/8" 9-5/8" 7" 8980 46 - 126 46 - 2688 45 - 7499 7329 - 10286 46 - 126 46 - 2688 45 - 6909 6780 - 8833 None 520 2670 4760 5410 None 1530 5380 6870 7240 16109 - 16219 4-1/2"12.6# 13Cr85 43 - 101328986 - 8985 Structural 4-1/2" HES TNT Perm Packer Red Spyder 10040, 2103 8633, 2103 Date: Bo York Sr. Area Operations Manager Oliver Sternicki Oliver.Sternicki@hilcorp.com 907.564.4891 PRUDHOE BAY, PRUDHOE OIL 10/11/2021 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 1:23 pm, Sep 30, 2021 321-518 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.09.29 10:12:16 -08'00' Bo York DSR-9/30/21 X 10-404 MGR08OCT21 DLB 09/30/2021 dts 10/11/2021 JLC 10/11/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.11 13:38:33 -08'00' RBDMS HEW 10/12/2021 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:218-117 6.50-029-20570-03-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 16908 10074 8661 10040 none none 8633 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 46 - 126 46 - 126 1530 520 Surface 2642 13-3/8" 46 - 2688 46 - 2688 5380 2670 Intermediate 7454 9-5/8" 45 - 7499 45 - 6909 6870 4760 Production Perforation Depth: Measured depth: 10331 - 16728 feet True vertical depth:8869 - 8980 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr85 43 - 10132 10040 8633Packers and SSSV (type, measured and true vertical depth) 4-1/2" HES TNT Perm Packer Liner 2957 7" 7329 - 10286 6780 - 8833 7240 5410 12. Stimulation or cement squeeze summary: Intervals treated (measured): Sleeve 4 treated with 20 bbls of 15% HCl Acid @ 1 bpm and 1253 psi Sleeve 3 treated with 20 bbls of 15% HCl Acid @ 1 bpm and 1800 psi Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0000 00 0 0 0 0 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Torin Roschinger Torin.Roschinger@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(406) 570-9630 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG 5 GINJ SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8983 Sundry Number or N/A if C.O. Exempt: 320-180 no SSSV Junk Packer Printed and Electronic Fracture Stimulation Data 5 Acid Operations shutdown Change Approved Program 5 Sleeve 4 @ 16109' Sleeve 3 @ 16219' Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing5 Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028327 & 028322 PBU 16-14C 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 8:14 am, Apr 21, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.04.20 20:52:58 -08'00' Bo York MGR30JUL2021 ADL 028332 DSR-4/21/21 RBDMS HEW 4/21/2021 SFD 4/21/2021 SFD 4/21/2021 ACTIVITYDATE SUMMARY 3/20/2021 **well on inj on arrival** SPOT EQUIP FOR AM **wsr cont on 3/21/21** 3/21/2021 **wsr cont'd from 3/20/21** PULLED MCX @ 2103'MD *flow tube stuck holding flapper open* DRIFTED w/ 3" BAILER TO STALL OUT DUE TO ~81* DEVIATION @ 10719'SLM **turned well over to dso to put on inj.** 3/25/2021 CTU#9 2.0" CT. Job Scope: Close Slv's 1 & 2. Open Slv's 3 & 4. Acidize. MIRU CTU. Bullhead 1% KCL w/ Safelube. RIH w/ NCS Sleeve Shifting BHA. Function Test Packer at 150' - good. Continue RIH. Locate Slv's 25, 26 & 27. Correct depth to put the locator sub on depth. Continue RIH. ***In Progress*** 3/26/2021 CTU#9 2.0" CT. Job Scope: Close Slv's 1 & 2. Open Slv's 3 & 4. Acidize. Tag at 16775', Shift Slv #2 Closed. PT 1000psi - Good Test. Shift Slv #1 Closed. PT 1000psi - Good Test. Open Slv #3 and Inject 20 bbls 15% HCL Acid. Open Slv #4 and Inject 20 bbls 15% HCL Acid. Final Injection Rates w/ 1% KCL + F103. 0.5 bpm @ 25psi / 1.5 bpm @ 575psi / 2 bpm @ 991psi / 2.5 bpm @ 1091psi / 3.5 bpm @ 1213psi / 4 bpm @ 1240psi. Pooh. Freeze Protect Coil w/ 60/40 Meth. Pump 15 bbl Meth Cap down Tbg. ***Job Complete / Turn over to DSO to POI*** Daily Report of Well Operations PBU 16-14C Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:218-117 6.API Number:50-029-20570-03-00 PRUDHOE BAY, PRUDHOE OIL BP Exploration (Alaska), Inc 5. Field/Pools:9. Well Name and Number: ADL 028332 & 028327 Property Designation (Lease Number): 10. 8. PBU 16-14C 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Repair Well Operations shutdown Acid Stimulate Op Shutdown GAS GSTOR5WAG SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 16908 Effective Depth MD: 13Cr85 11. May 10, 2020 Commission Representative: 15. Suspended Contact Name: Richards, Meredyth Contact Email: Meredyth.Richards@bp.com Authorized Name: Richards, Meredyth Authorized Title:Petroleum Engineer Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required? Subsequent Form Required: Approved by: COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: 4-1/2" MCX SSSV Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8983 Effective Depth TVD:Plugs (MD): Junk (MD): Suspend Plug for Redrill Perforate Perforate New Pool 10040 / 8633 2103 / 2103 Date: Liner 2957 7" 7329 - 10286 6780 - 8833 7240 5410 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 46 - 2688 46 - 2688 14. Estimated Date for Commencing Operations: BOP Sketch 46 - 126 Structural 6870 Proposal Summary 13. Well Class after proposed work: 4-1/2" HES TNT Perm Packer 10331 - 16728 8869' - 8980'4-1/2" 12.6#43 - 10132 Production 16820 8980 None None 46 - 126 520 13-3/8" 9-5/8" Contact Phone:+1 9075644867 Date: 4760 80 153020"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2642 5380 Intermediate 7454 45 - 7499 45 - 6909 Address:P.O. Box 196612 Anchorage, AK 99519-6612 3. No 5Yes Casing Length MD TVD Burst Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Fracture Stimulate Other Stimulate5 Re-enter Susp Well Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. Meredyth Richards Digitally signed by Meredyth Richards Date: 2020.04.27 13:46:43 -08'00' By Samantha Carlisle at 2:18 pm, Apr 27, 2020 320-180 SFD 4/27/2020 10-404 DSR-4/27/2020MGR06MAY20 Yes Required? Comm. 5/6/2020 dts 5/6/2020 JLC 5/6/2020 16-14C Sleeve Shift and Acid Procedure Notes: x 3/2019: LRS PERFORMED MIT-T TO 3600 psi - PASSED (AOGCC witnessed by Adam Earl) LRS PERFORMED MIT-IA TO 4000 psi - PASSED (AOGCC witnessed by Adam Earl) x All aqueous based intervention fluids should be 1% KCl with Safelube or as specified on the pump schedule. x We will use 2” coil for the job, prior intervention performing this work had no issues with overpull/push x Plan is to shift close sleeve 1 & 2 and shift open and acidize/HPBD sleeves #3 and #4. Acid Design Details Acid design will be 15% HCL Acid: 2 stages per sleeve-20 bbl/stage x Total 1% KCl Requirement: 500 bbls o Standard inhibited 1% KCl with 1 gal/1000gal F103 (surfactant) or similar x Total 15% HCl Requirement: 40 bbls Loading for HCl 15% HCl Product Code: Function: per Mgal A264 ACI 6 A201 Inhibitor Aid 40 A153 Intensifier 5 F103 Flowback aid 2 L058 Iron Control 20 W054 Antiemulsifier 5 Max Pressures: No pressure on IA: 3600 psi With 2500 psi on IA: 4500 psi CTU Procedure 1. Drift to PBTD for NCS Shifting tool. 2. At bottom circ well to 1% KCl by pumping 300 bbls down CT taking returns through choke. 3. MU NCS BHA attachment below a. Modification can be made per NCS/WSL discretion b. Need Gauges above and below packer element, include force gauge above 4. RIH and shift sleeves 1&2 closed 5. Pressure test wellbore to 1000 psi (not an MIT) to confirm both sleeves closed and holding 6. Sheer NCS BHA to prevent from closing after opening sleeves 3&4 7. RIH to Sleeve #3 @ 16,291’ MD. Shift open per NCS 8. Acidize per below. hold 2500 psi on IA to increase our max injection pressure to 4500 psi. a. Record time, rate, well head pressure, treating pressure, and annulus pressures in the WSR throughout the job. The goal is to obtain pre-acid injection test then circulate 20 bbls of HCl down the coil while taking returns. Once acid is at BHA, the backside is shut in and 10 bbls of acid is forced into the sleeve. After 10 bbls of HCl is pumped, a mid-acid injection test is obtained then the remainder of the acid is injected and a post acid injection test is obtained. The process is repeated on sleeve 18 9. POOH to sleeve #4 @ 16,109’ MD. Shift open per NCS and acidize per below. a. Record time, rate, well head pressure, treating pressure, and annulus pressures in the WSR throughout the job. 10. Unseat NCS packer and RIH below sleeve #3 to obtain final injectivity test. a. Pump down backside at 0.5, 1, 1.5, 2, 3 and MAX BPM. Please call town APE to discuss final injection test results i. Max pressure 3600 psi with no IA pressure ii. Max pressure 4500 psi with 2500 psi on IA b. Goal is to have >2 bpm injectivity at 2000 psi. If this is acheivable, additional acid stimulation should not be required WBD: Figure 1: NCS Shifting Tool Prior Operations (Well 09-51Ai results): DATA SUBMITTAL COMPLIANCE REPORT 6/17/2019 Permit to Drill 2181170 Well Name/No. PRUDHOE BAY UNIT 16-14C Operator BP Exploration (Alaska) Inc. API No. 50-029-20570-03.00 MD 16908 TVD 8983 Completion Date 3/22/2019 Completion Status WAGIN Current Status WAGIN UIC Yes REQUIRED INFORMATION / / Mud Log No ✓ Samples No ✓ Directional Survey Yes v DATA INFORMATION List of Logs Obtained: MWD / GR / RES, MWD / GR / RES (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH I Type MedlFrmt Number Name Scale Media No Start Stop CH Received Comments ED C 30828 Digital Data 7480 16908 5/22/2019 Electronic Data Set, Filename: 16- 14C_BHGE_OTK_MEM _Composite _FE Drilling Data.las ED C 30828 Digital Data 5/22/2019 Electronic File: 16- 14C_BHGE_LTK_2MD_Memory Drilling Log.cgm ED C 30828 Digital Data 5/22/2019 Electronic File: 16- 14C_BHGE_LTK_2TVDSS_Memory Drilling Log.cgm ED C 30828 Digital Data 5/22/2019 Electronic File: 16- 14C_BHGE_LTK_5MD_Memory Drilling Log.cgm ED C 30828 Digital Data 5/22/2019 Electronic File: 16- 14C_BHGE_LTK_5TVDSS_Memory Drilling Log.cgm ED C 30828 Digital Data 5/22/2019 Electronic File: 16- 14C BHGE_OTK_MEM _Composite _FE Drilling Data.dls ED C 30828 Digital Data 5/22/2019 Electronic File: 16- 14C_BHGE_OTK_2MD_Memory Drilling Log.pdf ED C 30828 Digital Data 5/22/2019 Electronic File: 16- 14C_BHGE_OTK_2TVDSS_Memory Drilling Log.pdf ED C 30828 Digital Data 5/22/2019 Electronic File: 16- 14C_BHGE_OTK_5MD_Memory Drilling Log.pdf ED C 30828 Digital Data 5/22/2019 Electronic File: 16- 14C_BHGE_OTK_5TVDSS_Memory Drilling Log.pdf ED C 30828 Digital Data 522/2019 Electronic File: 16-14C_BHGE_Final Survey Report.csv AOGCC Page I of 3 Monday, June 17, 2019 DATA SUBMITTAL COMPLIANCE REPORT 6/17/2019 Permit to Drill 2181170 Well Name/No. PRUDHOE BAY UNIT 16-14C MD 16908 TVD 8983 Completion Date 3/22/2019 ED C 30828 Digital Data ED C 30828 Digital Data Log C 30828 Log Header Scans ED C 30877 Digital Data ED C 30877 Digital Data ED C 30877 Digital Data ED C 30877 Digital Data ED C 30877 Digital Data ED C 30877 Digital Data Log C 30877 Log Header Scans Well Cores/Samples Information: Name INFORMATION RECEIVED Completion Report Y Production Test Information Y /15) Geologic Markers/Tops 0 COMPLIANCE HISTORY Interval Start Stop Operator BP Exploration (Alaska) Inc. API No. 50-029-20570.03-00 Completion Status WAGIN Current Status WAGIN UIC Yes 5/22/2019 Electronic File: 16-14C_BHGE_Final Survey Report.pdf 5/22/2019 Electronic File: 16-14C_BHGE_Final Survey Report.txt 0 0 2181170 PRUDHOE BAY UNIT 16-14C LOG HEADERS 10161 7417 6/3/2019 Electronic Data Set, Filename: 16- 14C_C7_20190320_RBT_HAL_MAIN.las 8512 7390 6/3/2019 Electronic Data Set, Filename: 16- 14C_C1_20190320_RBT_HAL_REPEAT.las 6/3/2019 Electronic File: 16- 14C C1 20190320_RBT_HAL_MAIN- REPEAT.pdf 6/3/2019 Electronic File: 16- 14C_C1_20190320_RBT_HAL_MAIN- REPEAT.tiff 6/3/2019 Electronic File: 16- 14C_C 1 20190320_RBT_HAL_MAI N.dlis 6/3/2019 Electronic File: 16- 14C_C1_20190320_RBT_HAL_REPEAT.dlis 0 0 2181170 PRUDHOE BAY UNIT 16-14C LOG HEADERS Sample Set Sent Received Number Comments Directional / Inclination Data l�J Mud Logs, Image Files, Digital DataY Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data FilesP Daily Operations Summary YO Cuttings Samples Y p Core Chips Y Core Photographs Y Laboratory Analyses Y N AOGCC Page 2 of 3 Monday, June 17, 2019 DATA SUBMITTAL COMPLIANCE REPORT 6/17/2019 Permit to Drill 2181170 Well Name/No. PRUDHOE BAY UNIT 16-14C Operator BP Exploration (Alaska) Inc. MD 16908 TVD 8983 Completion Date 3/22/2019 Completion Status WAGIN Current Status WAGIN Completion Date: 3/22/2019 Release Date: 10/10/2018 Description Date Comments Comments: Compliance Reviewed By: Date: API No. 50.029-20570-03-00 UIC Yes AOGCC Page 3 01'3 Monday, lune 17, 2019 WELL LOG TRANSMITTAL #905563912 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Cement Bond Log: 16-14C Run Date: 3/20/2019 2181 ;7 30 87 7 May 21, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 16-14C Data in LAS format, Digital Log Image files 50-029-20570-03 RECEIVED JUN 032019 AOGCC 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com and GANCPDC@USAANC.hou. Date: U i Iq Signed: 21 s1 17 30 82 8 BA ER PRINT DISTRIBUTION LIST F UGHM a GE COm (Jany Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc. BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 WELL NAME 16-14C 900 E. Benson Blvd. Anchorage, Alaska 99508 or FIELD Prudhoe Bay Unit CD/DVD FINAL COUNTY PRUDHOEBAY LOGS I BHI DISTRICT Alaska LOGS AUTHORIZED BY Paul Canbcares EMAIL Paul.Canizaresabhae.com LOG TYPE GR - RES LOG DATE March 14, 2019 TODAYS DATE May 20, 2019 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY ADDRESS(FEDEXW L NOT DELIVER TO P.O. BOX) PERSON ATTENTION 1 :BP North Slope. :EOA, PBOC. PRB-20 (Office 109) :D&C Wells Project Aides !Attn: Benda Glassmaker& Peggy O'Neil j900 E. Benson Blvd. :Anchorage, Alaska 99508 ............ 2 ;ConacoPhillips Alaska Inc. Attn: Ricky Elgarico MATO 3.344 700 G Street 3 :ExxonMobil, Alaska Attn: Lynda M. Yaskell and/or Lisa Boggs '.3201 C Street, Suite 505 Anchorage, AK 99503 e of Alaska -AOGCC c Natural Resources Technifian W. 7th Ave, Suite 100 horeee. Alaska 99501 t - Division of Oil & Gas — : Garmt Brown West 7th Avenue, Suite 1100 tome¢. Alaska 99501 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 FIELD/ FINAL CD/DVD FINAL PRELIM LOGS I (las, dlis, PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) (Compass) # OF PRIN ur MIN # OF COPIES I#OFGOPIES # OF COPIES RECEIVED TOTALS FOR THIS PAGE: 0 0 4 0 0 STATE OF ALASKA 'LASKA OIL AND GAS CONSERVATION COMMISR"N WELLI 'IMPLETION OR RECOMPLETION REPO( 4ND LOG RECEIVE® Ann la. Well Status: Oil 11Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG 0 - WDSPL ❑ No. of Completions: One Developmr8iq[y�.�❑ �l Service ®®®®®® bIa 2. Operator Name: 6, Date Comp., Susp., or Abend.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 3/22/2019 218-117 - 3, Address: 7, Date Spudded: 16. API Number: P.O. Box 196612 Anchorage, AK 99519-6612 3/2/2019 50-029-20570-03-00 4a, Location of Well (Governmental Section): 8. Dale TO Reached: 16, Well Name and Number. 3/13/2019 PBU 16-14C ' 9 Ref Elevations KB 85.01 17. Field/Pool(s): Surface: 1534' FNL, 527' FWL, Sec. 24, T10N, RISE, UM Top of Productive Interval: 2017' FSL, 1122' FWL, Sec. 13, TION, RISE, UM GL 37.33 • BF 37.73 PRUDHOE BAY, PRUDHOE OIL 10. Plug Back Depth(MD/TVD): 18, Property Designation: Total Depth: 1417' FSL, 3326 FEL, Sec. 11, TION, R15E, UM • 16820'18980' ' ADL 028332 8 028327 - 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11, Total Depth (MD/TVD): 19. DNR Approval Number: Surface: x- 719306 • y- 5929396 Zone - ASP • 16908'/8983' 79-081 TPI: x- 719797 y- 5932963 Zone - ASP 4 12. SSSV Depth (MD/TVD): 20 Thickness of Permafrost MD/rVD: Total Depth: x- 715212 y- 5937513 Zone - ASP 4 2103'/ 2103' 1900' (Approx.) 5. Directional or Inclination Survey: Yes 0 (attached) No ❑ 13. Water Depth, if Offshore: 21. Re -dr ill-ateral Top Window MO/rVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 7699'17049' 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 MWO/GR/RES, MWD/GR/RES 23. CASING, LINER AND CEMENTING RECORD CASING Wt. PER FT. GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 20" 94# H40 46' 126' 46' 126' 32" 300 sx Permafrost 13-3/8" 72# L -so 46' 2688' 46' 2688' 17-1/2" 3000 sx Fondu, 1250 sx Permafrost 9-5/8" 47# L-eo 45' 7699' 45' 7049' 12-1/4" 500 sx Class'G' 7" 26# L -M 7329' 10286' 6779' 8833' B -1/2"x9-7/8" 469 sx Class'G' 4-1/2" 12.6#13cres F 10123' 16906'. 8701' 8983' 6-1/8" 682 ax Class'G' 24. Open to production or injection? Yes 0 No ❑ 25. TUBING RECORD If Yes, list each interval open (MDrI VD of Top and Bottom; Perforation Size and Number; Date Perfd): GRADE DEPTH SET (MD) PACKER SET (MD/TV 4-1/2" 12.6# 13CB5 10132' 10040'18633' 4-1/2" Fracport Sleeves 3/19/2019 10331' 8869' 12850' 9044' 15752' 8983' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10399' 8917' 12959' 9040' 16109' 8986' Was hydraulic fracturing used during completion? Yes ❑ No 0 Per 20 AAC 25.283 (i)(2) attach electronic and printed 10509' 8985' 13401' 9028' 16219' 8985' 10855' 9066' 13510' 9025' 16618, 8981, 10965' 9066' 13952' 9013' 1iVIVll�f_C1�QN information 11405' 9066' 14061' 9010' C DEPTH INTERVAL (MDI AMOUNT AND KIND OF MATERIAL USED 11515' 9066' 14459' 9001'AT 11914' 9066' 14569' 8998' 3 Z 9 12024' 9066' 15051' 8986' 12382' 9063' 15159' 8983' VERI IED 2100' Freeze Protect wl 144 Bois Diesel 12492' 9059' 15642' 8982' ==_ 27. PRODUCTION TEST Date First Production: Apt 4, 2019 Method of Operation (Flowing, gas lift, etc): Gas Injection Date of Test : Hours Tested Production for Oil -Bbl' Gas -MCF: Water -Bbl: Choke Sive Gas -Oil Ratio. Test Period y Flow Tubing Press Casing Press: I Calculated 24 Hour Rate y Oil -Bbl: G..MCF: Water -Bbl: Oil GraviN - API foorl: Forth 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only Wt 7 RBDMSL� APR 2 21019 i � V, 3,11 28. CORE DATA Conventional Cores) Yes ❑ No 0 Sidewall Cores Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize nlhology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost - Top Well Tested? Yes ❑ No 0 Permafrost- Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 10280' 8828' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Colville Mudstone 7621' 6998' HRZ 10001' 8601' LCU/Sadlerochit-Zone 4 10280' 8828' CGL - Zone 3 10528' 8995' Base of CGL - Zone 2 10665' 9049' Formation at total depth: Zone 2 10665' 9049' 31. List of Attachments: LOT / FIT Summary, Summary of Daily Drilling Reports, Survey, Cement Reports, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Minge, David Authorized Title: SIM ea ist Contact Email: David.Minge@bp.com Authorized Signature: Date: I I I Contact Phone: +1 9075645279 INSTRUCTIONS General: This form is designed for submitting a complete and correct "it completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. 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 Ia. 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 Disp, Water Supply for Injection, Observation or Other. Item 41b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of pemrafrost 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 forth 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. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. 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 10407 Revised 5/2017 _ Submit ORIGINAL Only TRFF = WELLHEAD= VETCO GRAY ACTUATOR= ACTUALSZ OKB. ELEV = _BAKER 70' REF ELEV = 85.01' BF.ELEV= 37.73' KOP = --_ 4200' Max Angle= 94° Q 12796' Dahm MD = 10280' Dakin TVD = _ 8800' SS 72#, L-80 BTC, ID= 12.347' 95B" SLB WHIPSTOCK (03 B" CSG. 47#. LA0 BTC. ID = 7" TOC Minimum ID = 3.813" Q 2103' 4-112" HES X NIPPLE 4-12" TBG, 12.6#, 13CR-85 VAM TOP, .0152 bot. ID = 3.958' T" LNR. 26#. LA0 VAM TOP HC, .0383 bpf. ID = 6.276' 2675 — 14-12' LNR.12.6#.13-CR HTTC..0152 bpf. ID = 3.958" 1 16 14C SAF NOTES: WELL REQUIRES A SSSV WHEN ON A1LWcLL ANGLE>70'@10618". MAX OLS: 15.2'@ 10587'. "'CHROME TBG 8 LNR'"' 2�0_.-r__14-12"HES XNIP _D=3813' 7329'I j -5 8 X 7' WFD LTP WMIEBACK SLEEVE 8 9W FD WPHR HGR, ID = 6.190' MLLOUT WINDOW (16-14C) 7499' - 7513' 10040' 1y7'X4-12'HESTNTPKR,D=3.856" 100 4-12" HES X NP, D = 3.813' 7"X 5' HRD-E ZXP LTP WMIEBACK SLEEVE 8 WFD HGR ID =4.250' 10132° I 10175' ELMD Tf LOGGED 0320/19 \ 10154' NCS FRACPORT SLVS. ID = 3.870' NO DEPTH SEATSZ ACTUALSZ OIC DATE 27 10331 NA 5.740 C 0320119 26 10399 NA 5.740 C 0320/19 25 10509 NA 5140 C 0320119 24 10855 NA 5.740 C 0320119 23 10965 NA 5.740 C 0320119 22 11405 NA 5.740 C 0320119 21 11515 NA 5.740 C 0320/19 20 11914 NA 5.740 C 0320119 19 12024 NA 5.740 C 0320M9 18 12382 NA 5.740 C 0320119 17 12492 NA 5.740 C 0320/19 16 12850 NA 5.740 C 0320119 15 12959 NA 5.740 C 0320/19 14 13401 NA 5.740 C 0320119 13 13510 NA 5.740 C 03)20/19 12 13952 NA 5.740 C 0320/19 11 14061 NA 5.740 C 0320119 10 14459 NA 5.740 C 0320119 9 14569 NA 5.740 C 0320119 8 15051 NA 5.740 C 0320119 7 15159 NA 5.740 C 0320/19 6 15642 NA 5.740 C 0320119 5 15752 NA 5.740 C 0320119 4 16109 NA 5.740 C 0320119 3 16219 NA 5.740 C 0320119 2 16618 NA 5.740 O 03/30/19 1 . 16728 1 NA 5.740 O 03/JW19 O=OPEN C=CLOSED DATE REV BY COMMENTS DATE REV BY COMMENTS 071091B1 ORIGINAL COMPLETION 04/02/19 JDMIJMD OPENED FRAC SLEEVES 04M 3B8 SIDETRACK 16.14A 04/02/19 JNUJMD ADDED BF ELEV 03M9B6 N2ES SIDETRACK 16-148 04/16/19 DWJMD+ FINAL ODE APPROVAL 0322MS P-272 SIDETRACK (18-14C) 04/19/19 JNUJMD+ REF ELEV UPDATE 0327/19 JMD DRLG HO CORRECTIONS 0328119 JMD HO CORRECTIONS W/REDLNE PRUDHOE BAY UNIT WELL: 16-14C PERMD No: 218-117 API No: 50-029-20570-03 SEC 24, T10N, R15E,1534' FNL 8 526 SP Explombon (Alaska) Page 1 of 1 BP AMERICA LOT / FIT Summary Well Name: 16-14C Surface Leak Off Test Test Test Depth Test Depth AMW Pressure Pressure EMW Date Type (TMD -Ft) (TVD -Ft) (pp) (psi) (BHP) (psi) (ppg) 03/02/19 FIT 7,497.93 6,907.44 10.00 760.00 4,348.84 12.12 03/08/19 FIT 10,285.00 8,831.81 8.60 700.00 4,647.97 10.12 Page 1 of 1 2/28/2019 00:00 - 03:00 3.00 MOB P -1.07 PRE GENERAL RIG UP - HOOK UP INTERCONNECTS - INSTALL ROOF TOP WALKWAYS - INSTALL PIPE SHED/ROOF TRANSITIONS _ _ - HOOK UP WELLHOUSE 03:00 - 03:30 0.50 MOB P 1.07 PRE RAISE DERRICK -540 KLBS OFF RACK 03:30 - 04:00 0.50 MOB P -1.07 PRE SKID FLOOR - SKID HAUNCH RAISE PIPE CAT 0400 - 0530 1.50 RIGU P -1.07 PRE GENERAL RIG UP: .-HOOK UP MUD LINES AND STEAM LINES TO RIG FLOOR - CALIBRATE TOTCO SYSTEM COMPLETE PRESPUD CHECKLIST North America - ALASKA - BP Page 1 of 22 Operation Summary Report Common Well Name: 16-14 —ACCEPT RIG AT 05:30 PER APPROVED AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 2/28/2019 End Date: 3/14/2019 X3 -0197F -C: (5,676,591 00 ) Project: PBU Site: 16 Rig Name/No.: PARKER 272 Spud Date/Time: 2/16/2006 12:00 OOAM Rig Release: 3/22/2019 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00001922 Active datum: ACTUAL KB P272 @82.93us8 (above Mean Sea Level) Date From - To Has Task Code NPT Total Depth Phase Description of Operations RIGU (hr) (usft) PRE 2/27/2019 :10:00 - 18:00 8.00 MOB P -1.07 PRE GENERAL RIG DOWN: - SKID RIG FLOOR - BRIDAL DOWN - LOWER DERRICK - PREP MODULES FOR SEPARATION _-SEPARATE MODULES AND STAGE ON PAD 18:00 - 22:00 4.00 MOB P -1.07 PRE MOVE ALL 3 MODULES FROM DS09 TO DS16 2200 - 0000 2.00 MOB P -1.07 PRE SPOT THE DRILL MOD OVER WELL 16-14 PRE HOLD RIG EVAC/H2S DRILL WITH JAMES - MATE UP UTILITY MOD AND MUD MOD TO THE DRILL MOD 2/28/2019 00:00 - 03:00 3.00 MOB P -1.07 PRE GENERAL RIG UP - HOOK UP INTERCONNECTS - INSTALL ROOF TOP WALKWAYS - INSTALL PIPE SHED/ROOF TRANSITIONS _ _ - HOOK UP WELLHOUSE 03:00 - 03:30 0.50 MOB P 1.07 PRE RAISE DERRICK -540 KLBS OFF RACK 03:30 - 04:00 0.50 MOB P -1.07 PRE SKID FLOOR - SKID HAUNCH RAISE PIPE CAT 0400 - 0530 1.50 RIGU P -1.07 PRE GENERAL RIG UP: .-HOOK UP MUD LINES AND STEAM LINES TO RIG FLOOR - CALIBRATE TOTCO SYSTEM COMPLETE PRESPUD CHECKLIST Printed 3/28/2019 8:32:58AM **All depths reported in Drillers Depths" —ACCEPT RIG AT 05:30 PER APPROVED CHECKLIST— WBS:RU 05'.30 - 08:30 3.00 RIGU P -1.07 PRE GENERAL RIG UP: - BRIDAL DOWN -PERFORM DERRICK INSPECTION 0830 - 0930 1.00 RIGU P -1.07 PRE HOLD RIG EVAC/H2S DRILL WITH JAMES HUNDLEY'S CREW - HOLD PRESPUD MEETING 0930 - 1200 2.50 RIGU P -1.07 PRE RIG UP TO CIRCULATE OUT DIESEL FREEZE PROTECT 1200 - 1300 1.00 RIGU P -1.07 PRE ROCK OUT DIESEL FREEZE PROTECT - PUMP 20 BBL DOWN THE IAAT 3 BPM, 350 PSI - PUMP 40 BBL DOWN THE TUBING AT 4 BPM, 250 PSI -MONITOR WELL WITH CHARGE PUMP ON AN ISOLATED PIT FOR 10 MIN (STATIC) OPEN UP WELLAND MONITOR WELL FOR 10 MIN (STATIC) 13:00 - 13:30 0.50 RIGU P -1.07 PRE PERFORM RIG EVAC / H2S DRILL WITH LYLE BUCKLERS CREW 13:30 - 17:30 4.00 RIGU P -1.07 PRE NIPPLE DOWN THE TREE AND ADAPTER FLANGE - CLEAN AND INSPECT HANGER THREADS - INSTALL CROSSOVER AND BLANKING PLUG - CAMERON REP ON LOCATION TO FUNCTION LOCK DOWN SCREWS -MONITOR WELLTHROUGH OPEN T Printed 3/28/2019 8:32:58AM **All depths reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Page 2 of 22 Common Well Name: 16-14 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date. 2/28/2019 End Date: 3/14/2019 X3 -0197F -C (5,676,591.00 ) Project: PBU - Site: 16 Rig Name/No.: PARKER 272 Spud Date/time: 2/16/2006 12:00:OOAM Rig Release: 3/22/2019 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00001922 Active datum. ACTUAL KB P272 @82.93usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) — - (usft) _ 17:30 - 20:00 2.50 RIGU P -1.07 PRE NIPPLE UP THE BOP STACK - NIPPLE UP HIGH PRESSURE RISERS AND THE BOP STACK - INSTALL CHOKE LINE, FLOW LINE, FILL UP LINES, AND TURNBUCKLES -INSTALL FLOW NIPPLE - INSTALL MOUSEHOLE - MONITOR WELL THROUGH OPEN T 2000. - 22'.00 2.00 RIGU P -1.07 PRE RIG UP TO TEST BOPE - MAKE UP TEST JOINT - BLEED AIR FROM SOME -PERFORM SHELL TEST - CHECK TORQUE OF BOLTS ON THE BOP STACK 22:00 - 00:00 2.00 RIGU P -1.07 PRE PRESSURE TEST BOPE TO 250 PSI LOWAND 5000 PSI HIGH FOR 5 MIN EACH - PRESSURE TEST THE ANNULAR TO 250 PSI LOWAND 3500 PSI HIGH FOR 5 MIN EACH TEST WITH 4", 5" AND 7" TEST JOINTS - TEST WITNESSED BY AOGCC REP BOB NOBLE _ 3/1/2019 0000 - 0330 3.50 RIGU P -1.07 PRE PRESSURE TEST BOPE TO 250 PSI LOWAND 5000 PSI HIGH FOR 5 MIN EACH .- PRESSURE TEST THE ANNULAR TO 250 PSI LOWAND 3500 PSI HIGH FOR 5 MIN EACH -TEST WITH 4",5"AND 7" TEST JOINTS -TEST GAS ALARMS - TEST PVT AND FLOW ALARMS - NO FAILURES - TEST CHARTS ATTACHED -TEST WITNESSED BYAOGCC REP BOB NOBLE 03:30 - 05:30 2.00 STCTPL P -1.07 DECOMP BLOW DOWN AND RIG DOWN TESTING EQUIPMENT -PULL BLANKING PLUG - BREAK DOWN TEST JOINT - MAKE UP LANDIING JOIINT WBS:DECOMP 0530 - 0630 100 STCTPL P -1.07 DECOMP PULL TUBING HANGER TO THE RIG FLOOR -CAMERON REP ON LOCATION TO BACKOUT LOCK DOWN SCREWS - PULL 135 KLBS TO OFFBEAT TUBING HANGER AND 120 KLBS TO PULL HANGER TO THE RIG FLOOR 06:30 - 09:00 2.50 STCTPL P -1.07 DECOMP CIRCULATE SOAP SWEEP SURFACE TO SURFACE - 500 GPM, 570 PSI - LAY DOWN HANGER AND LANDING JOINT - MONITOR WELL, WELL U -TUBING FROM IA UP THE TUBING - CIRCULATE 2X TUBING VOLUME I - MONITOR THE WELL FOR 10 MIN (STATIC)_ 09:00 - 16:00 7.00 STCTPL P -1.07 DECOMP PULL OUT OF THE HOLE LAYING DOWN 4-1/2" TCII TUBING FROM CUTAT 7629' MD (FROM 272 RKB) - LAY DOWN TOTAL OF 181 FULL JOINTS, 1 CUT JOINT 39.47', 1 X -NIPPLE ASSY Printed 3/28/2019 8.32.58AM "All depths reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Page 3 of 22 Common Well Name: 16-14 AFE No Event Type: RE -ENTER -ONSHORE (RON) Start Date: 2/28/2019 End Date 3/14/2019 X3 -0197F -O. (5,676,591.00 ) Protect: PBU Site: 16 Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level) Date From - To Hrs Task Code NPT (hr) 16:00 - 17:30 1.50 STCTPL P 17:30 - 21:00 3.50 STWHIP P 21:00 - 00:00 3.00 STWHIP P 3/2/2019 00:00 - 05:30 1 5.50 STWHIP P 05:30 - 07:00 1.50 STWHIP P 07:00 - 08:00 1.00 STWHIP P 0800 - 1800 10.00 T STWHIP P BPUOI. USA00001922 Total Depth Phase (usft) -1.07 DECOMP -1.07 WEXIT Description of Operations RIG DOWN TUBING HANDLING EQUIPMENT -CLEAN AND CLEAR RIG FLOOR - CHANGE OUT MOUSEHOLE TO 30' -SET WEAR BUSHING (8-7/8" ID) MAKE UP 9-5/8" X 8-1/2" WHIPSTOCKIWINDOW MILLING BHA TO TOTAL LENGTH OF 953' MD --SURFACE TEST THE MWD PRIOR TO PICKING UP THE WHIPSTOCK WITH 600 GPM, 1000 PSI (GOOD TEST) •WBS:WEXIT Ao7 WEXIT _ . RUN IN THE HOLE WITH THE 9-5/8" X 8-1/2" WHIPSTOCKIWINDOW MILLING BHA ON 5" DP • FROM 953' MD TO 3000' MD AT MIDNIGHT -SINGLE IN THE HOLE WITH 5" D_P -1.07 WEXIT RUN IN THE HOLE WITH THE 9-5/8" X 8-1/2" WHIPSTOCK/WINDOW MILLING BHA ON 5" DP FROM 3000' MD TO THE TOP OF THE TUBING ,STUBAT 7621'MD -SINGLE IN THE HOLE WITH 5" DP • __.- PU 227 KLBS, 50193 KLBS 7,497.93 WEXIT SETWHIPSTOCK -ORIENT WHIPSTOCK 41" LEFT OF HIGH SIDE - SET DOWN ON TUBING STUB 1 OK TO TRIP ANCHOR - PULL UP THE HOLE PIPE STRETCH +99' MD TO SETTING DEPTH AT 7522' MD - SET WHIPSTOCK AND SHEAR OFF WITH 50 KLBS DOWN - TOP OF WHIPSTOCK/TOP OF WINDOW SET AT 7499' MD, BOTTOM OF WINDOWN SET AT 7513' MD 7.497 93 WEXIT DISLACE WELL TO 10 PPG LEND MILLING FLUID - 550 GPM, 1440 PSI 7,531.93 WEXIT KICK OFF "C" SIDETRACK AND MILL 9-5/8"X 8-1/2" WINDOW FROM 7499' MD TOP OF WINDOW TO 7513' MD + 20' OF NEW FORMATION TO 7533' MD - 450 GPM, 1200 PSI, 120 RPM, 10-19/12 KFT-LBS TRQ ON/OFF BTM - MW IN/OUT =10 PPG LEND, NO LOSSES - NO CEMENT OBSERVED BEHIND 9-5/8" CASING, NO PRESSURE OBSERVED ON OA - CLOSE MANUAL VALVES ON MUD CROSS - OBSERVE HIGHER THAN EXPECTED TORQUE WHILE MILLING THE WINDOWAND RATHOLE - TEMPORARILY HELD UP AT 7131' MD, WORK PIPE FREE WITH PUMPS AND OVER PULL UP TO 50K Printed 3128/2019 8:32:58AM **Ali depths reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Common Well Name. 16-14 Event Type: RE-ENTER- ONSHORE (RON) Start Date: 2/28/2019 End Date: 3/14/2019 Project: PBU Site: 16 Rig Name/No.: PARKER 272 Spud Date/Time: 2/16/2006 12:00 LOAM AFE No 53 -0197F -C: (5,676,591 00 ) Page 4 of 22 Rig Contractor: PARKER DRILLING GO. BPUOI: USA00001922 Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level) Date Flom - To His Task Code NPT Total Depth Phase Description of Operations _ (hQ _ _ (usft) - CLEAN AND CLEAR RIG FLOOR 01:30 18:00 - 19:00 1.00 STWHIP P 7,531.93 WEXIT PULL UP INTO THE WINDOWAND PERFORM FIT TO TOTAL LENGTH OF 1002' MD - MUD WEIGHT: 10.0 PPG, 6908' TVD, 7499' MD - RERUN VM -1 MILLTOOTH TRIGONE BIT - PUMP 1.6 BBLS TO 760 PSI, BLEED BACK 1.5 - MUD MOTOR WITH 1.5' AKO BBLS -MWD/LWD - FIT EMW = 12.1 PPG - TEST MWD AT 1002' MD WITH 550 GPM, 1100 - KICK TOLERANCE >25 BBL WITH EMW >12.1 PSI (GOOD TEST) PPG 06:30 2.50 STWHIP P 7,531.93 WEXIT - FIT APPROVED BY ODE 19:00 - 20:30 1.50 STWHIP P 7,531.93 WEXIT MADD PASS FROM 7533' MD TO 7350' MD TO THE TOP OF THE WINDOWAT 7499'MD 06:30 - 07:00 0.50 STWHIP P - 180 FPM, 600 GPM, 1755 PSI WEXIT HOLD D1 KICK WHILE TRIPPING DRILLAND -MONITOR WELL FOR 10 MIN (STATIC) 20:30 - 23:00 2.50 STWHIP P 7,531.93 WEXIT PULL OUT OF THE HOLE ON ELEVATORS - STOP THE JOB WHILE CDR2 MOVES DOWN FROM 7350' MD TO THE TOP OF THE BHAAT DS16 ACCESS ROAD 07:00 953' MD 0.50 STWHIP P 7,531.93 WEXIT RUN IN THE HOLE TO BOTTOM AT 7533'MD - MONITOR THE WELLAT THE TOP OF THE BHA FOR 10 MIN (STATIC) - HOLD UNANNOUNCED DI KICK WHILE TRIPPING DRILLAND AAR 2300 - 0000 1.00 STWHIP _ P� 7,531.93 T WEXIT _ PULLOUT OF THE HOLE WITH THE BHA FROM 953' MD TO SURFACE - RACK BACK THE HWDP - LAY DOWN THE DRILL COLLARS AND MILLING ASSEMBLY -MILLS GAUGE: LEAD MILL 1/4" UNDER, FOLLOW MILL 1/8" UNDER, DRESS MILL 1/16" 3/3/2019 00:00 - 01:00 1.00 _ _ __ STWHIP _ _ _ P _____ 7,531.93 _ WEXIT _UNDER LAY DOWN BHA 1 - SEE DETAILS IN PREVIOUS TIME ENTRY 01:00 - 01:30 0.50 STWHIP P 7,531.93 WEXIT FLUSH STACK Printed 3/28/2019 8:32:58AM **All depths reported in Drillers Depths" - FUNCTION BOPE AND FLUSH STACK AGAIN - LINE UPALL BOPE FOR HARD SHUT IN - CLEAN AND CLEAR RIG FLOOR 01:30 - 0400 2.50 STWHIP P 7,531.93 WEXIT MAKE UP 8-1/2" INTERMEDIATE MOTOR BHA TO TOTAL LENGTH OF 1002' MD - RERUN VM -1 MILLTOOTH TRIGONE BIT - MUD MOTOR WITH 1.5' AKO -MWD/LWD - TEST MWD AT 1002' MD WITH 550 GPM, 1100 PSI (GOOD TEST) 64M- 06:30 2.50 STWHIP P 7,531.93 WEXIT RUN IN THE HOLE ON 5" DP FROM 1002' MD TO THE TOP OF THE WINDOWAT 7499'MD 06:30 - 07:00 0.50 STWHIP P 7,531.93 WEXIT HOLD D1 KICK WHILE TRIPPING DRILLAND AAR - STOP THE JOB WHILE CDR2 MOVES DOWN DS16 ACCESS ROAD 07:00 - 07:30 0.50 STWHIP P 7,531.93 WEXIT RUN IN THE HOLE TO BOTTOM AT 7533'MD - ORIENT MOTOR TO 40° LEFT OF HIGH SIDE Printed 3/28/2019 8:32:58AM **All depths reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Common Well Name: 16-14 - 18.30 Event Type. RE-ENTER- ONSHORE (RON) Project: PBU Start Date: 2/28/2019 Site: 16 Active datum: ACTUAL KB P272 ID82.93usft (above Mean Sea Level) Date From - To Hrs Task Code NPT (hr) 07:30 - 16:00 8.50 DRILL P 16'.00 - 1730 1.50 DRILL P E,d Date 3114/2019 OO:OOAM Total Depth Phase (usft) _ 7,868.93 INT1 7,868.93 INTI 17:30 - 18.30 1.00 DRILL P 7,868.93 INTI L 18:30 - 21:00 2.50 DRILL P 7,868.93 INTI Printed 3/28/2019 8:32:58AM **All depths reported in Drillers Depths** Page 5 of 22 X3 -0197F -C.(5,676,591.00) BPUOI: USA00001922 Description of Operations DIRECTIONAL DRILL 8-1/2" INTI HOLE THROUGH CM3 FORMATION FROM 7533' MD TO 7870' MD, 7122' TVD (337' IN 8.5 HRS = 39.6 FPH WITH CONNECTIONS). - INSTANTANEOUS ROP: 30-100 FPH SLIDING, 30 - 150 FPH ROTATING - 550 GPM, 1850/1700 PSI ON/OFF BOTTOM, 40 RPM, 12/12 KFT-LBS TRQ ON/OFF BTM, UP TO 25 KLBS WOB - MW IN/OUT = 10.0 PPG, NO LOSSES DRILLING AHEAD i- ECD CLEANHOLE = 10.5 PPG, ACTUAL= 10.63 PPG, HARDLINE = 11.7 PPG - GASWATCH BACKGROUND RANGE =50 UNITS, MAX = 110 UNITS - NO BACKREAMING AT CONNECTIONS, SURVEY EVERY 30' FOR DIRECTIONAL i MONITORING - FIRST CLEAN MWD SURVEY AT 7686' MD - MEET REQUIREMENTS FOR MOTOR RUN AT '7870' MD; CONFIRMED SEPARATION FROM'B' WELLBORE, ENOUGH FOOTAGE TO BURY UNDERREAMER (218'), AND FIVE CLEAN .SURVEYS WITH NO MAGNETIC INTERFERENCE TO ALLOW FOR SURVEY VERIFICATION PER BP PRACTICE 100203 - SIMOPS: PICKUP 4" DRILLPIPE WITH OFFLINE EQUIPMENT WBS:INT1 BACKREAM THROUGH THE OPENHOLE SECTION FROM BOTTOM AT 7870' MD TO THE TOP OF THE WINDOWN AT 7499' MD BIT DEPTH (IN PREPARATION FOR RUNNING STIFF UNDERREAMER ASSEMBLY BACK INTO HOLE) - 550 GPM, 1700 PSI, 60 RPM, 8-10 KFT-LBS TRO - NO ISSUES THROUGH OPENHOLE - FLOWCHECK WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM (STATIC) - ATTEMPT TO PULL ON ELEVATORS FROM 7670' MD, ENCOUNTER -30 KLBS OVERPULL AT 7630' MD BIT DEPTH, BACKREAM BHA THROUGH WINDOW WITH 20 RPM, 10-17 KFT-LBS TORQUE, 250 GPM, 600 PSI, UNABLE TO PULL WITHOUT PUMPSAND ROTARY UNTIL MOTOR IS ACROSS THE WHIPSTOCK, DID NOT PUMP OR ROTATE BITACROSS WHIPSTOCK CIRCULATE BOTTOMS UP AT THE TOP OF THE WINDOW - 550 GPM, 1700 PSI - NO ROTATION, RECIPROCATE PIPE 60' PULL OUT OF THE HOLE ON ELEVATORS FROM THE TOP OF THE WINDOW AT 7499' MD TO THE TOP OF THE BHAAT 1002' MD - MONITOR WELL FOR 10 MIN AT THE TOP OF THE BHA (STATIC) North America - ALASKA - BP Operation Summary Report Common Well Name: 16-14 Event Type: RE-ENTER- ONSHORE (RON) Start Date: 2/28/2019 Project PBU Site: 16 Rig Name/No.: PARKER 272 Spud Date/Time: 2/1E Rig Contractor. PARKER DRILLING CO. INTI Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level) Date From - To Him Task Code (hr) DRILL 21:00 - 2300 2.00 DRILL P End Date: 3/14/2019 2006 12:00:OOAM NPT Total Depth Phase (usft) 7,868.93 INTI 23:00 - 23:30 0.50 DRILL P 7,868.93 INTI 23:30 - 00:00 0.50 DRILL P 7,868.93 INTI 3/4/2019 100:00 - 03:00 3.00 DRILL P 7,868.93 INTI 03:00 - 07:30 4.50 DRILL P 7,868.93 INTI -- --07:30 - 12:00 4.50 -- _-DRILL P 8,178.93 INTI Printed 3/28/2019 8*32:58AM **All depths reported in Drillers Depths— Page 6 of 22 AFE No X3 -0197F -C:(5,676,591.00) BPUOI: USA00001922 Description of Operations PULL OUT OF THE HOLE WITH THE BHA FROM 1002' MD TO SURFACE - RACK BACK THE HWDP AND LAY DOWN THE DIRECTIONAL TOOLS '- BIT GRADE = 1 -1 -IN GAGE CLEAN AND CLEAR RIG FLOOR SERVICE RIG MAKEUP 8-1/Z'/ 9-7/8" RSS / ANDERREAMER DRILLING ASSEMBLY TO TOTAL LENGTH OF 1038' MD - FLOWCHECK WELL FOR 10 MIN PRIOR TO RUNNING IN HOLE (STATIC) - AUTO TRAK, NEW NOV SK616M-J1D PDC BIT, ONTRAK (GR/RES/PWDNSS/SURVEY) - ANDERREAMER CUTTERS 132' BACK FROM BIT - PLUG IN AND VERIFY MWD TRIP IN THE HOLE WITH THE 8-1/2" X 9-7/8" RSS /ANDERREAMER DRILLING ASSEMBLY ON 5"DRILLPIPE AND ELEVATORS FROM 1038' MD TO PREVIOUSLY DRILLED DEPTH OF 7870' MD -SHALLOW HOLE TEST THE MWDAT 1038' MD WITH 650 GPM, 1700 PSI (GOOD TEST) - OBTAIN ECD BENCHMARKS AT THE TOP OF THE WINDOW AT 7499' MD - NO ISSUES WITH UNDERREAMER THROUGH WINDOW OR OPENHOLE - TAKE THREE VERIFICATION SURVEYS WITH NEW MWD - DROP 1-3/8" ACTIVATION BALL FOR ANDER_R_EAMERA_T7708' MD DIRECTIONAL DRILL 8-117X 9-7/8" INTI HOLE THROUGH CM3 FORMATION FROM 7870" MD TO 8180' MD (310' IN 4.5 HRS = 69 FPH WITH CONNECTIONS) - INSTANTANEOUS ROP: UP TO 75-100 FPH 700 GPM, 2725 PSI ON/OFF BOTTOM, 150 RPM, 14/12 KFT-LBS TRO ON/OFF BTM, UP TO 20 KLBS WOB - MW IN/OUT = 10.0 PPG, NO LOSSES DRILLING AHEAD - ECD CLEANHOLE = 10.69 PPG, ACTUAL= 11.1 PPG, HARDLINE = 11.7 PPG - GASWATCH BACKGROUND RANGE =65 UNITS, MAX = 90 UNITS - NO BACKREAMING AT CONNECTIONS, SURVEY EVERY 90' FOR DIRECTIONAL MONITORING - PUMP 35 BBL HIGH VIS SWEEP AT 8150' MD, 50% INCREASE IN CUTTINGS BACK AT SHAKERS -SIMOPS: PICKUP 4" DRILLPIPE WITH OFFLINE EQUIPMENT North America - ALASKA- BP Operation Summary Report Common Well Name: 16-14 Event Type: RE-ENTER- ONSHORE(RON) Project: PBU Start Date 2/28/2019 Site: 16 APE No End Date 3/14/2019 X3 -0197F -C:(5,676,591,001 Page 7 of 22 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00001922 Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations . (hr) (usft) 12:00 - 17:00 5.00 DRILL P 8,501.93 INTI DIRECTIONAL DRILL 8-1/7'X9-7/8"INTI HOLE THROUGH CM3 FORMATION FROM 8180" MD TO 8503' MD (323' IN 5 HRS = 65 FPH WITH CONNECTIONS) - INSTANTANEOUS ROP: UP TO 50-100 FPH - 700 GPM, 2900 PSI ON/OFF BOTTOM, 150 RPM, 14/12 KFT-LBS TRQ ON/OFF BTM, UP TO 20 KLBS WOB - MW IN/OUT = 10.0 PPG, NO LOSSES DRILLING AHEAD - ECD CLEANHOLE = 10.69 PPG, ACTUAL = 11.15 PPG, HARDLINE = 11.7 PPG - GASWATCH BACKGROUND RANGE =30 UNITS, MAX = 90 UNITS - NO BACKREAMING AT CONNECTIONS, SURVEY EVERY 90' FOR DIRECTIONAL MONITORING - PUMP 35 BBL WEIGHTED SWEEPAT 8415' MD, 75% INCREASE IN CUTTINGS BACK AT SHAKERS - - SIMOPS: PICKUP 4" DRILLPIPE WITH ,.. OFFLINE EQUIPMENT 17:00 - 17:30 0.50 DRILL P 8,501.93 INT1 RIG SERVICE REPLACE SWAB IN MUD PUMP 1730 - 21:00 3.50 DRILL P 8,731.93 INTI DIRECTIONAL DRILL 8-1/2" X 9-7/8" INTI HOLE THROUGH CM3 FORMATION FROM 8503' MD TO 6733' MID (231' IN 3.5 HRS = 66 FPH WITH CONNECTIONS) - INSTANTANEOUS ROP: UP TO 50-100 FPH - 700 GPM, 2900 PSI ON/OFF BOTTOM, 150 RPM, 14/12 KFT-LBS TRQ ON/OFF BTM, UP TO 20 KLBS WOB - MW IN/OUT = 10.0 PPG, NO LOSSES DRILLING AHEAD - ECD CLEANHOLE = 10.69 PPG, ACTUAL= 11.15 PPG, HARDLINE = 11.7 PPG - GASWATCH BACKGROUND RANGE= 30 UNITS, MAX =90 UNITS - NO BACKREAMING AT CONNECTIONS, SURVEY EVERY 90' FOR DIRECTIONAL MONITORING - PUMP 35 BBL HIGH VIS SWEEP AT 8597' MD, 75% INCREASE IN CUTTINGS BACKAT SHAKERS -SIMOPS: PICKUP4" DRILLPIPE WITH OFFLINE EQUIPMENT 21 00 - 21'.30 0.50 DRILL N 8,731.93 INTI REPLACE SEATAND VALVE IN MUD PUMP Printed 3/28/2019 8:32:58AM **All depths reported in Drillers Depths" North America - ALASKA - EIP Operation Summary Report Page 8 of 22 Common Well Name: 16-14 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 2/28/2019 End Date: 3/14/2019 X3 -0197F -C: (5,676,591,00) Project PBU Site: 78 Rig Name/No.: PARKER 272 Spud Daterrime: 2/16/2006 12:00:OOAM Rig Release: 3/22/2019 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00001922 Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations _(hr) .. (usft) _ 21:30 - 00:00 2,50 DRILL P 8,909.93 INT1 DIRECTIONAL DRILL 8-1/2"X9-7/8"INTI HOLE THROUGH CM3 AND CM2 FORMATIONS FROM 8733" MD TO 8911' MD (178' IN 2.5 HRS = 71 FPH WITH CONNECTIONS) - INSTANTANEOUS ROP: UP TO 150 FPH - 700 GPM, 3000 PSI ON/OFF BOTTOM, 150 RPM, 14-16/14 KFT-LBS TRO ON/OFF BTM, UP TO 25 KLBS WOB - MW IN/OUT = 10.0 PPG, NO LOSSES DRILLINGAHEAD -ECD CLEANHOLE= 10.7 PPG, ACTUAL= 11.25 PPG, HARDLINE = 11.7 PPG - GASWATCH BACKGROUND RANGE =30 UNITS, MAX = 90 UNITS - NO BACKREAMING AT CONNECTIONS, SURVEY EVERY 90' FOR DIRECTIONAL MONITORING - PUMP 35 BBL WEIGHTED SWEEP AT 8894' MD, 50% INCREASE IN CUTTINGS BACKAT SHAKERS - SIMOPS: PICKUP 4" DRILLPIPE WITH OFFLINE EQUIPMEN_T__ _ _ 3/5/2019 0000 - 0600 6.00 DRILL P 9,340.00 INTI DIRECTIONAL DRILL B-1/2"X9-7/8"INTI HOLE THROUGH CM2 FORMATION FROM 8911' MD TO 9340' MD (429' IN 6 HRS = 71 FPH WITH CONNECTIONS) - INSTANTANEOUS ROP: UP TO 150 FPH - 700 GPM, 3100 PSI ON/OFF BOTTOM, 150 RPM, 14-17/14 KFT-LBS TRO ON/OFF BTM, UP TO 25 KLBS WOB -MW IN/OUT= 10.1 PPG, NO LOSSES j DRILLING AHEAD -ECD CLEANHOLE= 10.7 PPG, ACTUAL= 11.25 - 11.35 PPG, HARDLINE =11.7 PPG - GASWATCH BACKGROUND RANGE =30 UNITS, MAX = 90 UNITS - NO BACKREAMING AT CONNECTIONS, SURVEY EVERY 90' FOR DIRECTIONAL MONITORING - PUMP 35/35 BBL LO-VIS/HI-VIS TANDEM SWEEP AT 9170' MID, 75% INCREASE BACKAT SHAKERS - BEGIN INCREASING MUD WEIGHT, WITH SACK BAR, TO BE AT 10.2 PPG PRIOR TO THE PLANNED TOP OF CM1 AT 9654' MD Pnnted 328/2019 8.32'58AM '*All depths reported in Drillers Depths— North America - ALASKA- BP Operation Summary Report Page 9 of 22 Common Well Name. 16-14 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 2/28/2019 End Date'. 3/14/2019 X3 -0197F -C: (5,676,591.00 ) Project: PBU Site: 16 Rig Name/No.: PARKER 272 Spud Dale/Time: 2/18/2006 12:00:OOAM Rig Release: 3/22/2019 Rig Contractor. PARKER DRILLING CO. BPUOI: USA00001922 Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) _ _ _ (usft) 0600 - 1200 6.00 DRILL P 9,751.00 INTI DIRECTIONAL DRILL B-1/2"X9-7/8"INTI HOLE THROUGH CM2 AND CMI FORMATIONS FROM 9340' MD TO 9751' MD (411' IN 6 HRS = 69 FPH WITH CONNECTIONS) - INSTANTANEOUS ROP: UP TO 150 FPH - 700 GPM, 3150 PSI ON/OFF BOTTOM, 150 RPM, 15-18/14 KFT-LBS TRQ ON/OFF BTM, UP TO 25 KLBS WOB - MW IN/OUT = 10.2 PPG, NO LOSSES DRILLINGAHEAD -ECD CLEANHOLE= 10.91 PPG, ACTUAL= 111.3- 11.5 PPG, HARDLINE = 11.7 PPG - GASWATCH BACKGROUND RANGE =50 UNITS, MAX = 100 UNITS - NO BACKREAMING AT CONNECTIONS, 1 SURVEY EVERY 90' FOR DIRECTIONAL MONITORING - PUMP 35 BBL HIGH VIS SWEEPAT 9370' MD, DUMPED SWEEP DID NOT OBSERVE CUTTINGS RETURNS - PUMP 35 BBL HIGH VIS SWEEPAT 9750'MD, DUMPED SWEEP DID NOT OBSERVE CUTTINGS RETURNS 1200. - 2030'. 8.50 DRILL P 10,26000 INTI DIRECTIONAL DRILL B-1/2"X9-7/8"INTI HOLE THROUGH CMi AND HRZ FORMATIONS FROM 1i 9751'MD TO 10,260' MID (509' IN 8.5 HRS =59 FPH WITH CONNECTIONS) 1 - INSTANTANEOUS ROP: HOLDING BACK ON ROP FOR ECD CONTROLAT 10,017' MD - 700 GPM, 3250 PSI ON/OFF BOTTOM, 150 RPM, 15-18/14 KFT-LBS TRQ ON/OFF BTM, UP TO 20 KLBS WOB - MW IN/OUT =10.4 PPG, NO LOSSES DRILLING AHEAD - ECD CLEANHOLE = 11.11 PPG, ACTUAL= 11.5 - 11.6 PPG, HARDLINE = 11.7 PPG - GASWATCH BACKGROUND RANGE =50 UNITS, MAX = 100 UNITS - NO BACKREAMING AT CONNECTIONS, SURVEY EVERY 90' FOR DIRECTIONAL MONITORING - WEIGHT UP TO 10.4 PPG PRIOR TO ENTERING THE PLANNED HRZ TOP AT 10,036' MD - PUMP 35 BBL HIGH VIS SWEEPAT 10100' MD, 100% INCREASE IN CUTTINGS BACKAT SHAKERS - PUMP 35 BBL HIGH VIS SWEEPAT 10205' MD, 75% INCREASE IN CUTTINGS BACKAT SHAKERS - OBSERVE THE MHRZ AT 10,201' MD - HOLD ROP CONSTANTAT 50 FPH TO OBSERVE REVERSE DRILLING BREAK, OBSERVE REVERSE DRILLING BREAKAT 10,255' MD, DRILLADDITIONAL 5' MD Printed 3/28/2019 8:32:58AM **All depths reported in Drillers Depths" Common Well Name: 16-14 Event Type: RE-ENTER- ONSHORE (RON) Project: PBU North America - ALASKA - BP Operation Summary Report Start Date: 2/28/2019 Site: 16 Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level) Date From - To Hrs Task Code NPT (hr) 20:30 - 00:00 3.50 DRILL P 3/6/2019 00:00 - 0200 2.00 DRILL P 02:00 - 03:30 1.50 DRILL P 03:30 - 11:30 8.00 DRILL P 11:30 - 14:00 2.50 DRILL P 14:00 - 15:00 1.00 DRILL P 1500 - 1530 0.50 CASING P Page 10 of 22 AFE No End Date3/14/2019 X3 -0197F -C'. (5,676,591.00 ) BPUOI: USA00001922 Total Depth Phase Description of Operations (usft) 9,751.00 INT1 SCRATCH AND SNIFF FOR THE TSAD FROM 10,260' MD TO 10,275' MD -CIRCULATE BOTTOMS UP FOR SAMPLES EVERY5'MD - 700 GPM, 3220 PSI - 60 RPM, 16-18 KFT-LBS TORQUE '- OBSERVE TEMPORARY 3% LEL IN SHAKER ROOM, WSL NOTIFY WSUP _ 10,280.00 MT1 SCRATCH AND SNIFF FOR THE TSAD FROM 10275'MD TO 102f1 Mn -CIRCULATE BOTTOMS UP FOR SAMPLES .EVERY 5'MD - 700 GPM, 3220 PSI - 60 RPM, 16-18 KFT-LBS TORQUE _ - TSAD CONFIRMEDAT 10,277'MD 10,280.00 INTI CIRCULATE HOLE CLEAN WITH 2 BOTTOMS UP - DROP 1-7/8" BALL TO LOCK UNDERREAMER BLADES CLOSED - PUMP BALL DOWN AT 100 GPM, OBSERVE 1917 PSI PRESSURE SPIKE, BLEED OFF PRESSURE FOR 2 MIN -ECO =11.3 PPG EMW - STAGE PUMPS UP TO 700 GPM, 3220 PSI - ROTATE 120 RPM, 17 KFT-LBS TORQUE - PUMP 35 BBL HIGH VIS SWEEP, 10% INCREASE IN CUTTINGS BACK AT SHAKERS 10,280.00 INT1 PULLOUT OF THE HOLE FROM BOTTOM AT 10,280' MD TO THE TOP OF THE BHAAT 1038' MD - MONITOR THE WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM AND AT THE WINDOW (STATIC) - MUD WEIGHT IN/OUT = 10.4 PPG - OBSERVE TIGHT HOLE FROM 7787' MD TO THE TOP OF THE WINDOWAT 7499'MD - BACKREAM AT 4 BPM, 380 PSI, 40 RPM, 9-18 KFT-LBS TORQUE - NO ROATION WITH STABILIZERS OR BIT _ACROSS THE WHIPSTOCK 10,280.00 INTI LAY DOWN THE BHA FROM 1038' MD TO SURFACE - MONITOR THE WELL AT THE TOP OF THE BHA FOR 10 MIN (STATIC) - BIT GRADE = 1 -1 -IN GAGE_ 10,280.00 INTI CLEAN AND CLEAR THE RIG FLOOR 10,280.00 INT1 RIG UP DOYON CASING RUNNING EQUIPMENT WITH TORQUE TURN - RIG UP DOUBLE STACK TONGS - CHANGE ELEVATORS WBS:INTICSG Printed 3/28/2019 8:32:58AM "AII depths reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Page 11 of 22 Common Well Name. 16-14 AFE No Event Type: RE-ENTER- ONSHORE (RON) Stan Date 2/28/2019 Eno Date. 3/14/2019 X3 -0197F -C: (5,676 591 00 ) Project: PBU Site: 16 Rig Name/No.: PARKER 272 Spud Date/Ttme: 2/16/2006 12:00 OOAM Rig Release: 3/22/2019 Active datum: ACTUAL KB P272 @82.93usR (above Mean Sea Level) Date From - To Him Task Code (hr) 15:30 - 22:30 7.00 CASING P CASING P BPUOI'. USA00001922 NPT Total Depth 22:30 - 00:00 1.50 3/7/2019 INTI RUN 7", 26#, L-80, ViHC, INTERMEDIATE - 07:001 7.00 00:00 CASING P BPUOI'. USA00001922 NPT Total Depth Phase Description of Operations _ (usft) 10,280.00 INTI RUN 7", 26#, L-80, ViHC, INTERMEDIATE LINER TO TOTAL LENGTH OF 2957' MD - CHECK FLOATS (HOLDING) - USE JET LUBE SEAL GUARD PIPE DOPE - TORQUE CONNECTIONS TO 11,950 FT -LBS - FILL LINER ON THE FLYAND TOP OFF EVERY 10 JOINTS - TOTAL LINER WEIGHT PU 108K, SO 99K MAKE UP LINER HANGERIPACKER ASSEMBLY - ADD MGEL MIX -CIRCULATE 1X LINER VOLUMES AT 7 BPM, 300 PSI 10,280.00 INTI RUN IN HOLE WITH THE 7" LINER ON 5" OP TO 4590' MD '- RIH AT 90 FT/MIN FROM CASING P 10,280.00 INTI I RUN IN HOLE WITH THE 7" LINER ON 5" DP 07:00 - 10:00 3.00 CASING P FROM 4590' MD TO SET DEPTH AT 10278' MD - RIH AT 90 FT/MIN - CIRCULATE IX DPAND LINER VOLUME AT BPM, 500 PSI - PU 220K, SO 140K AT 7499' MD RUN INTO OPEN HOLE WITH LINER .- BREAK CIRCULATION EVERY 5 STANDSAT 5 BPM FOR -5 MINUTES - OBTAIN PU/SO WEIGHTS EVERY 5 STANDS - FINAL PU 265K, SO 180K - MUD WEIGHT: 10.4 PPG IN, 10.4 PPG OUT -NO LOSSES - TOP OF LINER AT 7321' MD - OBSERVE -30 KLBS ADDITIONAL DRAG WITH CENTRALIZERS IN THE CASING ! OBSERVE TIGHT HOLE/FILL AND WASH TO BOTTOM FROM 10190' MD TO BOTTOM AT 10278'MD 10,280.00 INT1 STAGE UP PUMPS IN 1 BBL INCREMENTS TO 7 BPM AND CONDITION MUD TO CEMENTING PROPERTIES - 7 BPM, 55 PSI - INITIAL PRESSURE AT CEMENTING RATE: 615 PSI - FINAL PRESSURE AT CEMENTING RATE AFTER MUD CONDITIONED: 590 PSI - RECIPROCATE PIPE STRETCH AT SURFACE AT 1000 FPH Printed 3/28/2019 8 32 58A **All depths reported in Drillers Depths" Common Well Name: 16-14 Event Type. RE-ENTER- ONSHORE(RON) Project: PBU North America - ALASKA - BP Operation Summary Report Stan Date. 2/28/2019 Site: 16 Rig Contractor: PARKER DRILLING CO. Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level) Date From - To 1000 - 1230 12:30 - 13:30 Hrs Task (hr) 2.50 CASING 1.00 CASING End Date: 3/14/2019 ]:OOAM Code NPT Total Depth _(usft) P 10,280.00 Phase AFE No X3 -0197F -C:(5,676,591.00) SPUOI: USA00001922 Description of Operations Page 12 of 22 INTI CEMENT 7°, 26#, L-80, VTHC INTERMEDIATE LINER AS FOLLOWS: - FILL LINES WITH WATER AND PRESSURE TEST TO 4300 PSI FOR 5 MINUTES - PUMP 50 BELS OF 13 PPG MUDPUSH II SPACER @ 7 BPM, 350 PSI - DROP BOTTOM DRILL PIPE WIPER DART t yvk jkee CU.FT/SK) ...___ ..._ - DROP TOP RILL PIPE WIPER RECIPROCATED 26 %�� t" TRETCH AT SURFACEWHD E PUMPS G CEMENTT 4j PERFORM DISPLACEMENT WITH RIG PUMPS / �2-u' - 213 BBLS DISPLACED AT 7 BPM: ICP 550 PSI, /y(' ItA FCP 1400 PSI $ �llaJJj�irr`//'( ZO - 6 BBLS DISPLACED AT 2 BPM: ICP 780 PSI, FCP 875 PSI I - SLOW DOWN TO OBSERVE LATCH ON BOTH V DRILLPIPE WIPER DARTS LATCH TO 3 BPM, G DID NOT OBSERVE LATCH ON EITHER WIPER DART - DISPLACEMENT FLUID: 219 BBLS OF 10.4 PPG LSND - REDUCE RATE TO 2 BPM PRIOR TO PLUG BUMP: FINAL CIRCULATING PRESSURE 875 PSI, SIMULATED CEMENT PRESSURE IS -600 PSI. FINALACTUAL PRESSURE MEETS REQUIREMENTS FOR TOC (LIFT PRESSURE) VERIFICATION TECHNIQUE PER BP PRACTICE 100221, TABLE 1. - INCREASE PRESSURETO 1500 PSIAFTER BUMPAND HOLD FOR 3 MIN, BLEED OFF AND CHECK FLOATS (FLOATS HOLDING) - CIP @ 12:22 - FIELD PICK TOC 8268' MD (GAGE HOLE -BA=DN LIFT PRESSURE) - TOTAL DISPLACEMENT VOLUME 219 BBLS (MEASURED BY STROKES @ 96% PUMP EFFICIENCY) - RECIPROCATE PIPE STRETCH AT SURFACE DURING DISPLACEMENT - NO LOSSES DURING THEM NT JOB Oma_ 10,280.00 INTI INCREASE PRESSURE TO 2500 PSI TO SET HANGER - SET DOWN 100 KLBS TO CONFIRM HANGER SET - INCREASE PRESSURE TO 4200 PSI TO RELEASE FROM HANGER -BLEED PRESSURE OFF - PU TO EXPOSE DOG SUB AND SET DOWN ON LINER TOP 60 KLBS, 50 RPM - PU RUNNING TOOLABOVE LINER TOP AND MARK NO-GO. CIRCULATE 1X BU AT 18 BPM, 2300 PSI - OBSERVE 55 BBL OF CONTAMINATED MUDIMUD PUSH 13:30 - 14:30 1.00 CASING P 10,280.00 INTI BREAKOFFAND LAY DOWN CEMENT HEAD AND 4 SINGLES OF DRILL PIPE TO.7200'_MD 1430 1500 0.50 CASING P 10,280.00 INTI RIG SERVICE Printed 3/28/2019 8.32:58AM **All depths reported in Drillers Depths" North America - ALASKA - BP Page 13 of 22 Operation Summary Report Common Well Name: 16-14 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 2/28/2019 Eno Date. 3/14/2019 X3 -0197F -C. (5,676,591 00 ) Project: PBU Site: 16 Rig Name/No.: PARKER 272 Spud Date/time: 2/16/2006 12:00:OOAM Rig Release: 3/22/2019 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00001922 Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level) Date From - To Hm Task Code NPT Total Depth Phase Description of Operations P 10,280.00 INT1 (usft) 15:00 - 16:30 1.50 CASING P 10,280.00 INT1 CUTAND SLIP DRILL LINE - RECALIBRATE BLOCK HEIGHT WITH AMPHION AND BAKER SYSTEMS 16:30 - 19:30 3.00 CASING P 10,280.00 INTI PULL OUT OF THE HOLE FROM 7200' MD TO - ENCOUNTER TOP OF PLUGS -9-10' DEEPER THAN EXPECTED AT 101 96'MD - ENCOUNTER FLOAT COLLAR -9'-10' DEEPER THAN EXPECTED AT 10243' MD 15.30 - 17:30 2.00 DRILL P 10 280.00 INT1 DISPLACE 10.4 PPG LSND WITH 8.6 PPG QUIKDRIL-N - WSL MONITOR SIMULATED VS ACTUAL DISPLACEMENT PRESSURE - MONITOR BBL IN/BBL OUT - 300 GPM, ICP - 2840 PSI, FCP -1570 PSI ROTATE 20 RPM 8 - 7 KFT-LBS TORQUE, RECIPROCATE 60' -MONITOR WELLAFTER DISPLACEMENT FOR 15 MIN (STATIC) Printed 3/28/2019 8:32:58AM "All depths reported in Drillers Depths" SURFACE - LAY DOWN THE LINER RUNNING TOOL, _ DOGS EXPOSED, ALL COMPONENTS INTACT 19.30 - 00:00 4.50 BOPSUR P 10,280.00 INT1 CHANGE OUT UPPER RAMS AND TEST TO 250 PSI LOWAND4000 PSI HIGH FOR 5 MIN EACH -CLOSE BLIND RAMS AND CIRCULATE ACROSS THE MUD CROSS TO MONITOR 'FLUID VOLUME IN WELL .-INSTALL 2-7/8"X5"VBR TEST WITH 4" AND 5" TEST JOINTS 3/8/2019 00:00 - 01:30 1.50 BOPSUR P 10,280.00 INT1 RIG DOWN BOP TEST EQUIPMENT -PULL TEST PLUG -INSTALL WEAR BUSHING (8-7/8" ID) 01:30 - 0300 1.50 SOPSUR P 10,280.00 INT1 PRESSURE TEST 7" LINER TO 4000 PSI HIGH 30 IN PRES_ SORETM APPROVED BY WSUP 0300 - 0430 1.50 BOPSUR P 10,280.00 INT1 MAKE UP 6-1/8" PRODUCTION HOLE MOTOR BHA TO A TOTAL LENGTH OF 174'MD - SMITH 6-1/8" XR2 TRI -CONE INSERT BIT, MOTOR WITH 1.8-AKO, MWD/LWD (GAM/RES/PRESNSS/SURVEY) PU 45 KLBS, SO 45 KLBS it- 0430 - 0630 2.00 DRILL P 10,280.00 INTI RUN IN THE HOLE ON 4"XS" DP TAPERED STRING FROM 174' MD TO 4075' MD - SHALLOW HOLE TEST MWDAT 2069' MD, _ 300 GPM, 1500 PSI (GOOD TEST) _ 0630 - 0800 1.50 DRILL P 10,280.00 INTI PERFORM 04 WELL KILL DRILL PERFORM WEEKLY BOPE FUNCTION TEST 0800 - 11:30 3.50 DRILL _ P 10,280.00 INTI RUN IN THE HOLE ON 4"XS" DP TAPERED STRING FROM 4075' MD TO 10116' MD - WASH DOWN THE LAST STAND AT 250 GPM, 1850 PSI, 40 RPM, _7 KFT-LBS TORQUE 1130 - 15.30 4.00 DRILL P 10,280.00 INTI DRILL CEMENT, PLUGS AND FLOAT EQUIPMENT FROM 10116' MD TO 10268' MD (10' FROM 7" SHOE) 250 GPM, 1920 PSI ON BOTTOM, 1820 PSI OFF BOTTOM, 40 RPM, 9/8 KFT-LBS TORQUE ON/OFF BOTTOM, 10-14 KLBS WOB - PU 214 KLBS, SO 148 KLBS, ROT 172 KLBS -MUD WEIGHT IN/OUT= 10.4 PPG - ENCOUNTER TOP OF PLUGS -9-10' DEEPER THAN EXPECTED AT 101 96'MD - ENCOUNTER FLOAT COLLAR -9'-10' DEEPER THAN EXPECTED AT 10243' MD 15.30 - 17:30 2.00 DRILL P 10 280.00 INT1 DISPLACE 10.4 PPG LSND WITH 8.6 PPG QUIKDRIL-N - WSL MONITOR SIMULATED VS ACTUAL DISPLACEMENT PRESSURE - MONITOR BBL IN/BBL OUT - 300 GPM, ICP - 2840 PSI, FCP -1570 PSI ROTATE 20 RPM 8 - 7 KFT-LBS TORQUE, RECIPROCATE 60' -MONITOR WELLAFTER DISPLACEMENT FOR 15 MIN (STATIC) Printed 3/28/2019 8:32:58AM "All depths reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Common Well Name: 16-14 Event Type: RE -ENTER -ONSHORE (RON) Start Date: 2/28/2019 Eno Date: 3/14/2019 AFE No (5,676,591 00 ) Page 14 of 22 Project: PBU Site: 16 Rig Name/No.: PARKER 272 Spud Date/Time: 2/16/2006 12:00 OOAM Rig Release. 3/22/2019 Rig Contractor: PARKER DRILLING CO. BPUOL USA00001922 Active datum: ACTUAL KB P272 @j82.93usft (above Mean Sea Level) Date From - To Hrs Task Code NET Total Depth Phase Description of Operations (hr) (usft)_ 17:30 - 19:00 1.50 DRILL P 10,310.00 INTI DRILL OUT THE SHOE AND 20' OF NEW FORMATION TO 10310' MD - 250 GPM, 1250 PSI ON BOTTOM, 1150 PSI OFF BOTTOM, 40 RPM, 8/7 KFT-LBS TORQUE ON/OFF BOTTOM, 10 KLBS WOB - MUD WEIGHT IN/OUT = 8.6 PPG MONITOR WELL FOR 15 MIN AFTER DRILLING SHOEAND PRIOR TO DRILLING NEW • FORMATION . NOTIFIED ODE OF THE 10' DISCREPENCY OF • .THE LANDING COLLAR AND FLOAT COLLAR 1900 - 2000 1.00 DRILL P 10,310.00 INT1 CIRCULATE BOTTOM$ UP - 300 GPM, 1550 PSI -40 RPM, 8 KFT-LBS TORQUE -MUD WEIGHT IN/OUT=8.6 PEG_ 20:00 - 21:30 1.50 DRILL P 10,310.00 INTI _ RIG UP AND PERFORM FIT - MUD WEIGHT: 8.6 PPG, 8831' TVD, 10278' MD - PUMP 2 BBLS TO 700 PSI, BLEED BACK 2 BELS -FIT EMW=10.1 PPG - KICK TOLERANCE INFINITE WITH EMW -9.0 PPG _ _ _ I- FIT APPROVED BY ODE 21:30 - 0000 2.50 DRILL P 10,386.00 PROD1 DIRECTIONAL DRILL B-118" PRODUCTION HOLE SECTION FROM 10310' MD TO 10386' MD -76 FT IN 2.5 HRS =30 FT/HR WITH CONNECTIONS - INSTANTANEOUS ROP 50-100 FPH - 275 GPM, 1510/1430 PSI ON/OFF BOTTOM, 40 RPM, S/7 KFT-LBS TRQ ON/OFF BTM, UP TO 10 KLBS WOB - PU = 203 KLBS, SO = 160 KLBS, ROT = 181 KLBS - SURVEY EVERY 30 FT FOR DLS >5° -ZERO LOSSES WHILE DRILLING AHEAD - MUD WEIGHT IN/OUT = 8.6 PPG - GAS WATCH: AVG BACKGROUND 27 UNITS, MAX 91 UNITS 7" LINER SHOE LOGGED AT 10286' MD, 8837' MD WBS:PROD1 Printed 3/28/2019 8:32:58AM **Al depths reported in Drillers Depths" Common Well Name. 16-14 Event Type. RE-ENTER- ONSHORE (RON) Project: PBU North America - ALASKA - BP Operation Summary Report Stan Date. 2/28/2019 End Date: 3/14/2019 Site: 16 2/16/2006 12:00 OOAM Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level) Date From - To Hrs Task Code ___ (hr) 3/9/2019 00:00 - 14:00 14.00 DRILL P 14:00 - 15:30 1.50 DRILL P 15'.30 - 17'.00 1.50 DRILL P 17:00 - 2300 6.00 DRILL P 2300 - 0000 1.00 DRILL P 3/10/2019 00:00 - 03:00 2.00 DRILL P 03:00 - 09:00 6.00 DRILL P NPT Total Depth Phase (us8) Page 15 of 22 ARE No K3 -0197F -C: (5,676,591.00) Rig Release: 3/22/2019 BPUOI: USA00001922 Description of Operations 10,863.00 PROW DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE SECTION FROM 10386' MD TO 10863' MD - 477 FT IN 14 HRS = 34 FT/HR WITH CONNECTIONS - INSTANTANEOUS ROP UP TO 150 FPH, 20-30 FPH WHILE DRILLING THROUGH THE 42N SHALE FROM 10425' MD TO 10528' MD - 275 GPM, 1600/1450 PSI ON/OFF BOTTOM, 40 RPM, 11/10 KFT-LBS TRQ ON/OFF BTM, UP TO 20 KLBS WOB - PU = 230 KLBS, SO = 157 KLBS, ROT = 182 KLBS - SURVEY EVERY 30 FT FOR DLS>5' - ZERO LOSSES WHILE DRILLING AHEAD -MUD WEIGHT IN/OUT=8.6 PPG - GAS WATCH: AVG BACKGROUND 75 UNITS, _ MAX 225 UNITS _ 10,863.00 PROD? PUMP 358BL HIGH VIS SWEEP AND CIRCULATE SURFACE TO SURFACE • �.- 300 GPM, 1750 PSI !- 40 RPM, 10K TORQUE - RECIPROCATE FULL STAND WHILE CIRCULATING '- 25% INCREASE IN CUTTINGS BACK AT SHAKERS - MONITOR THE WELL FOR 10 MIN (STATIC) 10.863 00 PROD1 PUMP OUT OF THE HOLE FROM 10863' MD TO THE 7" LINER SHOE AT 10285' MO - MONITOR THE WELL FOR 10 MIN (STATIC) - 250 GPM, 1250 PSI - MUD WEIGHT IN/OUT = 8.6 PPG 10,663.00 PROD1 PULL OUT OF THE HOLE ON ELEVATORS FROM 10285' MD TO THE TOP OF THE DIRECTIONAL TOOLS AT 174' MD - MONITOR THE WELL FOR 10 MIN AT THE TOP OF THE HWDP (STATIC) - STRAP STANDS IN THE DERRICK WHILE PULLING OUT OF THE HOLE 10,863.00 PROD1 LAY DOWN THE BUILD BHA FROM 174' MD TO SURFACE - MONITOR THE WELL FOR 10 MIN AT THE TOP OF THE BHA (STATIC) - BIT GRADE = 3 -1 -IN GAGE 10,863.00 PROD1 MAKE UP 61/8" PRODUCTION HOLE RSS BHA TOATOTAL LENGTH OF 155' MD - HDBS 6-1/8" MM64D PDC BIT, AUTOTRAK EXACT, MWD/LWD _ __(GAWR_E_S_/PRESNSS/SURVEY) 10,863.00 PROD? RUN IN THE HOLE ON 4" X 5" DP TAPERED STRING FROM 155' MD TO 10863' MD - SHALLOW HOLE TEST MWD AT 2050' MD, 300 GPM, 900 PSI (GOOD TEST) - OBSERVE OBSTRUCTION AT 10567' MD, ATTEMPT TO WORK PAST OBSTRUCTION WITH 20 KLBS DOWN WITH NO SUCCESS, WASH TO BOTTOM AT 250 GPM, 1160 PSI, DID NOT OBSERVE OBSTRUCTION WITH PUMPS ON - TAKE THREE VERIFICATION SURVEYS WITH NEW MWD Printed 3/28/2019 8:32:58AM **All depths reported in Drillers Depths'" North America - ALASKA - BP Operation Summary Report Common Well Name. 16-14 Event Type: RE-ENTER- ONSHORE (RON) Start Date: 2/28/2019 End Date. 3/14/2019 Project: PBU Site: 16 Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth (hr) _ _ (usft) 09:00 - 18:00 9.00 DRILL P 11,830.00 1800 - 00:00 6.00 DRILL P 12.488.00 Page 16 of 22 AFE No K3 -0197F -C:(5,676,591.001 BPUOI: USA00001922 Phase Desonption of Operations PROD1 DIRECTIONAL DRILL&1/8"PRODUCTION HOLE SECTION FROM 10863' MD TO 11830' MD - 967 FT IN 9 HRS = 107 FT/HR WITH CONNECTIONS - INSTANTANEOUS ROP UP TO 195 FPH, LIMITED FOR HOLE CLEANING PER WELL PROGRAM - 320 GPM, 1750 PSI ON/OFF BOTTOM, 150 RPM, 13/11 KFT-LBS TRQ ON/OFF BTM, UP TO 10 KLBS WOB - PU = 233 KLBS, SO = 155 KLBS, ROT = 184 KLBS -SURVEY EVERY STAND -ZERO LOSSES WHILE DRILLING AHEAD - MUD WEIGHT IN/OUT = 8.7 PPG - GAS WATCH: AVG BACKGROUND 50 UNITS, MAX 113 UNITS - PUMP 35 BBL HIGH VIS SWEEPAT 11413' MD, 25% INCREASE IN CUTTINGS BACKAT SHAKERS PROD? DIRECTIONAL DRILL&1/8"PRODUCTION HOLE SECTION FROM 11830' MD TO 12488' MD - 658 FT IN 6 HRS = 110 FT/HR WITH CONNECTIONS - INSTANTANEOUS ROP UP TO 195 FPH, LIMITED FOR HOLE CLEANING PER WELL PROGRAM - 320 GPM, 1800 PSI ON/OFF BOTTOM, 150 RPM, 13/12 KFT-LBS TRQ ON/OFF BTM, UP TO 8-10 KLBS WOB - PU = 243 KLBS, SO = 158 KLBS, ROT = 188 KLBS - SURVEY EVERY STAND - ZERO LOSSES WHILE DRILLING AHEAD - MUD WEIGHT IN/OUT = 8.7 PPG - GAS WATCH: AVG BACKGROUND 50 UNITS, MAX 113 UNITS - PUMP 35 BBL HIGH VIS SWEEPAT 12177' MD, 25% INCREASE IN CUTTINGS BACKAT SHAKERS Printed 3/2812019 8:32:58AM **All depths reported in Drillers Depths" Common Well Name: 16-14 Event Type: RE-ENTER- ONSHORE(RON) Rig Name/No.: PARKER 272 North America - ALASKA - Blo Operation Summary Report Start Date. 2/28/2019 End Date: 3/14/2019 Site: 16 Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level) Date From - To Him Task Code NPT _ (hr) __ _ 3/11/2019 00:00 - 0600 6.00 DRILL P Page 17 of 22 AFE No X3 -0197F -C. (5,676,591.00 i BPUOI: USA00001922 Total Depth Phase Description of Operations -.. - (usft). _ _ _ — - 13,200.00 PRODt DIRECTIONAL DRILL 6-7/8" PRODUCTION HOLE SECTION FROM 12488' MD TO 13200' MD - 720 FT IN 6 HRS = 120 FT/HR WITH CONNECTIONS - INSTANTANEOUS ROP UP TO 195 FPH, LIMITED FOR HOLE CLEANING PER WELL 'PROGRAM - 320 GPM, 1900 PSI ON/OFF BOTTOM, 150 RPM, 15/13 KFT-LBS TRQ ON/OFF BTM, UP TO 8-10 KLBS WOB - PU = 242 KLBS, SO = 158 KLBS, ROT = 190 KLBS �- SURVEY EVERY STAND - ZERO LOSSES WHILE DRILLING AHEAD - MUD WEIGHT IN/OUT = 8.7 PPG - GAS WATCH: AVG BACKGROUND 50 UNITS, MAX 113 UNITS - PUMP 35 BBL HIGH VIS SWEEP AT 12935' MD, 25% INCREASE IN CUTTINGS BACK AT SHAKERS 06:00 - 1200 6.00 DRILL P 14,002.00 PROD? DIRECTIONAL DRILL 6-1/8" PRODUCTION HOLE SECTION FROM 13200' MD TO 14002' MD - 802 FT IN 6 HRS = 134 FT/HR WITH CONNECTIONS - INSTANTANEOUS ROP UP TO 195 FPH, LIMITED FOR HOLE CLEANING PER WELL PROGRAM - 320 GPM, 2000 PSI ON/OFF BOTTOM, 150 RPM, 18/15 KFT-LBS TRQ ON/OFF BTM, UP TO 10 KLBS WOB - PU = 277 KLBS, SO = 155 KLBS, ROT = 193 KLBS - SURVEY EVERY STAND -5-10 BPH LOSSES WHILE DRILLING AHEAD - MUD WEIGHT IN/OUT = 8.7 PPG GAS WATCH: AVG BACKGROUND 55 UNITS, MAX 90 UNITS - PUMP 35 BBL HIGH VIS SWEEPAT 13680' MD, 25% INCREASE IN CUTTINGS BACKAT SHAKERS Printed 3/28/2019 8*32:58AM **All depths reported in Drillers Depths" North America - ALASKA- BP Operation Summary Report Common Well Name'. 16-14 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date. 2/28/2019 End Date: 3/14/2019 X3 -0197F -C. (5,676.591 00 ) Project: PBU Site. 16 Page IS of 22 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00001922 Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 12:00 - 18:00 6.00 DRILL P 14,669.00 PROD? DIRECTIONAL DRILL 6-1/9' PRODUCTION HOLE SECTION FROM 14002' MD TO 14669' MD - 667 FT IN 6 HRS = 111 FT/HR WITH CONNECTIONS - INSTANTANEOUS ROP UP TO 195 FPH, LIMITED FOR HOLE CLEANING PER WELL 'PROGRAM - 320 GPM, 2050 PSI ON/OFF BOTTOM, 150 RPM, 19/17 KFT-LBS TRQ ON/OFF BTM, UP TO 15 KLBS WOB - PU = 278 KLBS, SO =156 KLBS, ROT = 199 KLBS - SURVEY EVERY STAND - 5-10 BPH LOSSES WHILE DRILLING AHEAD - MUD WEIGHT IN/OUT = 8.7 PPG - GAS WATCH: AVG BACKGROUND 52 UNITS, MAX 115 UNITS 1800 - 00:00 600 DRILL P - PUMP 35 BBL HIGH VIS SWEEP AT 14430' MD, 25% INCREASE IN CUTTINGS BACKAT SHAKERS 15,298.00 PROD1 DIRECTIONAL DRILL 6-1/8'PRODUCTION HOLE SECTION FROM 14668' MD TO 15298' MD - 630 FT IN 6 HRS = 105 FT/HR WITH CONNECTIONS - INSTANTANEOUS ROP UP TO 195 FPH, LIMITED FOR HOLE CLEANING PER WELL PROGRAM - 320 GPM, 2100 PSI ON/OFF BOTTOM, 150 RPM, 20/17 KFT-LBS TRQ ON/OFF BTM, UP TO ' 15 KLBS WOB - PU = 271 KLBS, SO = 163 KLBS, ROT = 201 KLBS - SURVEY EVERY STAND - 5-10 BPH LOSSES WHILE DRILLING AHEAD TOTAL LOSSES LAST 24 HRS = 136 BBL - MUD WEIGHT IN/OUT = 8.7 PPG - GAS WATCH: AVG BACKGROUND 52 UNITS, MAX 115 UNITS Printed 3/28/2019 8.32:58AM "All depths reported in Drillers Depths" Common Well Name: 16-14 Event Type: RE-ENTER- ONSHORE(RON) PBU North America - ALASKA - BP Operation Summary Report Start Date. 2/26/2019 End Date: 3/14/2019 Site: 16 Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level) Page 19 of 22 AFE No X3 -0197F -C:(5,676,591.00) Rig Release: 3/22/20191, BPUOI: USA00001922 Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usit) _ 3/12/2019 00:00 - 09:30 9.50 DRILL P 16,000.00 PROD1 DIRECTIONAL DRILL 6-1/W' PRODUCTION HOLE SECTION FROM 15298' MD TO 16000' MD -703 FT IN 6 HRS =70 FT/HR WITH CONNECTIONS, AVERAGE ROP UP TO 05:001 15850' MD = 110 FPH - INSTANTANEOUS ROP UP TO 195 FPH, LIMITED FOR HOLE CLEANING PER WELL PROGRAM - 320 GPM, 2100 PSI ON/OFF BOTTOM, 150 RPM, 21/18 KFT-LBS TRQ ON/OFF BTM, UP TO 15 KLBS WOB - PU = 271 KLBS, SO = 163 KLBS, ROT= 201 KLBS - SURVEY EVERY STAND -&10 BPH LOSSES WHILE DRILLING AHEAD -MUD WEIGHT IN/OUT=8.7 PPG -GAS WATCH: AVG BACKGROUND 100 UNITS, MAX 360 UNITS - PUMP 35 BBL HIGH VIS SWEEPAT 15312' MD, 75% INCREASE IN CUTTINGS BACKAT SHAKERS ' - WEIGHT UP MUD SYSTEM TO 9.0 PPG IN PREPARATION TO POOH 09.30 - 10 30 1.00 DRILL P 10.30 - 13:00 2.50 1300 - 2000 7.00 20:00 - 22:00 2.00 2200 - 22:30 0.50 DRILL P DRILL P DRILL P DRILL P FROM -15850' MD, RETRACT RIBS ON Pnnted 3/28/2019 8:32:58AM **All depths reported in Drillers Depths— - OBSERVE PRESSURE SPIKES WHEN THE BIT CONTACTS BOTTOM AND REDUCED ROP FROM -15850' MD, RETRACT RIBS ON AUTOTRACK TO TROUBLESHOOT WITH LITTLE SUCCESS, DRILLAHEAD WITH REDUCED ROP TO 16001' MD, DECISION MADE TO -POOH -FOR BIT TRIP 16,000.00 PROD? CIRCULATE 1.SX BOTTOMS UP - 325 GPM, 2200 PSI _ - 150 RPM, 17 KFT-LBS TORQUE 16,000.00 PRODt PUMP OUT OF THE HOLE FROM 16000' MD TO 14000' MD - 2 BPM, 300 PSI - MONITOR WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM (NOT FLOWING) _ -MUD WEIGHT IN/OUT=9.0 PPG _ 16,000.00 PRODi PULL OUT OF THE HOLE ON ELEVATORS FROM 14000' MD TO THE TOP OF THE DIRECTIONAL TOOLS AT 155' MD - MONITOR WELL FOR 10 MIN AT THE TOP OF THE H WDP AND THE TOP OF THE DIRECTIONAL TOOLS (NOT FLOWING) - WORK THROUGH TIGHT SPOT AT 14460' MD WITH 50 KLBS OVER, WORK DOWN THROUGH TIGHT SPOT AND PULL BACK THROUGH WITH 20 KLBS OVER - MUD WEIGHT IN/OUT = 9.0 PPG SIMOPS: - PRESSURE TEST THE CHOKE MANIFOLD OFFLINE 16,000.00 PROD1 LAY DOWN BHA FROM 155' MD TO SURFACE BIT GRADE: -8 -1 -IN GAGE, BIT CORED OUT 16,000.00 PROD1 CLEAN AND CLEAR RIG FLOOR Pnnted 3/28/2019 8:32:58AM **All depths reported in Drillers Depths— Common Well Name. 16-14 Event Type: RE-ENTER- ONSHORE(RON) _.. Project: PBU Rig Name/No.: PARKER 272 Active datum: ACTUAL KB P272 @82.93usft ( Date From - To Him (hr) 22:30 - 00:00 1.50 3113/2019 00:00 - 03'.00 3.00 0300 - 0330 0.50 0330 - 0600 2.50 0600 - 15.30 9.50 North America - ALASKA - BP Page 20 of 22 Operation Summary Report AFE No Start Date: 2/28/2019 End Date. 3/14/2019 X3 -0197F -C. (5,676,591 00 ) Site: 16 above Mean Sea Level) Task Code NPT DRILL P DRILL P DRILL P DRILL P DRILL P BPUOI: USA00001922 Total Depth Phase Description of Operations (usft) _ 16,000.00 PROIDI RIG UP TO TEST BORE - MAKE UP 4" TEST JOINT - SUCK OUT STACK AND PULL WEAR BUSHING - SET TEST PLUG - RIG UP SECONDARY KILL TO IA FOR CONTINUOUS HOLE FILLIMONITORING 16,000.00 PROD? TEST BORE TO 250 PSI LOW, 4000 PSI HIGH FOR 5 MINUTES EACH - TEST WITH 4" AND W TEST JOINTS -ALLTESTS CHARTED, SEE ATTACHED BOP 'TEST CHARTS - TEST WITNESS WAIVED BY AOGCC REP GUYCOOK '- LOSS RATE WHILE TESTING 2 BPH 16,000.00 PROD1 'BLOW DOWN AND RIG DOWN TESTING EQUIPMENT - PULL TEST PLUG AND SET WEAR BUSHING (8-7/8" ID) 16,000.00 PROD1 MAKE UP 6-1/8" PRODUCTION HOLE RSS BHA TO A TOTAL LENGTH OF 155' MD - HDBS 6-1/8" MM64D PDC BIT, AUTOTRAK EXACT, MWD/LWD (GAM/RES/PRESNSS/SURVEY) HELD STOP THE JOB DRILL AND AAR WITH RIG CREW: SECURING WELL WHILE PLUGGED IN TO MWD TOOLS WHILE WAITING FOR CDR2 TO CLEAR THE ACCESS ROAD 16,000.00 PROW RUN IN THE HOLE WITH 6-1/8" PRODUCTION HOLE RSS ASSEMBLY ON ELEVATORS FROM 155' MD TO 15951' MD - FILL PIPE EVERY 2000' MD - SHALLOW HOLE TEST MWD TOOLS AT 2056' MD: GOOD TEST - TEST AUTOTRACK IN OPEN HOLE AT 10469' MD: GOOD TEST - PU 260 KLBS, SO 164 KLBS AT 15951' MD - MUD WEIGHT IN/OUT = 9.0 PPG - MONITOR WELL WITH HOLE FILLAND TRIP TANK WHILE RUNNING IN: STATIC LOSS RATE 2-5 BPH. WASH DOWN FROM 15900' MDAT 250 FPH TO OVERLAP LOGS - 320 GPM, 2200 PSI, 150 RPM, 17 KFT-LBS TORQUE Printed 3/28/2019 8:32:58AM "AII depths reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Common Well Name: 16-14 - 01:30 Event Type: RE-ENTER- ONSHORE (RON) Project: PBU Start Date: 2/28/2019 Site: 16 AFE No End Date: 3/1412019 X3 -0197F -C.(5,676, 591.00) Rig Release: 3/22/2019 Page 21 of 22 Rig Contractor. PARKER DRILLING CO. - 01:30 0.50 DRILL BPUOI'. USA00001922 Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level) - 0230 1.00 DRILL Date From -To Him Task Code NPT Total Depth Phase Description of Operations P (hr) - _ _(usft) RPM, 25/25 KFT-LBS TORQUE ON/OFF BTM, _ _ 15:30 - 00:00 8.50 DRILL P 16,835.00 PROD? DIRECTIONAL DRILL 6-1/8'PRODUCTION - 5-10 BPH LOSSES WHILE DRILLING AHEAD - MUD WEIGHT IN/OUT = 9.0 PPG HOLE SECTION FROM 16000' MD TO 16835' - GAS WATCH: AVG BACKGROUND 240 UNITS, MAX 300 16,908.00 MD BBLS) - 320 GPM, 2250 PSI, 150 SPM, 25 KFT-LBS - 835 FT IN 8.5 HRS = 98.2 FT/HR WITH TORQUE -MUD WEIGHT IN/OUT =9.0 PPG 16,908.00 CONNECTIONS 116000' MD - MONITOR WELL FOR 10 MIN PRIOR TO - INSTANTANEOUS ROP UP TO 200 FPH, PULLING OFF BOTTOM: STATIC LOSS RATE - 2BPH LIMITED FOR HOLE CLEANING PER WELL - 2 BPM, 500 PSI - PULLING AT < 70 FPM PROGRAM PROD? RUN IN THE HOLE ON ELEVATORS FROM 16000' MD TO TO AT 16908' MD - 320 GPM, 2420/2340 PSI ON/OFF BTM, 150 RATE -2 BPH - MUD WEIGHT IN/OUT = 9.0 PPG RPM, 23/18 KFT-LBS TORQUE O WOFF BTM, - MONITOR WELL WITH TRIP TANK AND HOLE FILL WHILE RUNNING IN 16,908.00 PROW CIRCULATE 2X BOTTOMS UP, 612 BBLS UP TO 18 KLBS WOB - STAGE UP PUMPS IN 1 BPM INCREMENTS - 320 GPM; 2300 PSI - 150 RPM, 23 KFT-LBS TORQUE - PU 281 KLBS, SO 175 KLBS, ROT 206 KLBS - STANDING BACK ONE STAND PER HOUR -SURVEY EVERY STAND -5-10 BPH LOSSES WHILE DRILLING AHEAD - MUD WEIGHT IN/OUT = 9.0 PPG - GAS WATCH: AVG BACKGROUND 50 UNITS, MAX 275 UNITS 3/14/2019 00:00 - 01:00 1.00 DRILL P 16,908.00 PROD1 DIRECTIONAL DRILL 6-1/8" PRODUCTION 01:00 - 01:30 0.50 DRILL P 01:30 - 0230 1.00 DRILL P 02'.30 - 0300 0.50 DRILL P 03'.00 - 06'.00 3.00 DRILL P Printed 3/28/2019 8.32:58AM **All depths reported in Drillers Depths** HOLE SECTION FROM 16835 MD TO SECTION To AT 16908' MD -73 FT IN 1.0 HRS =73 FT/HR WITH CONNECTIONS - INSTANTANEOUS ROP UP TO 200 FPH, LIMITED FOR HOLE CLEANING PER WELL PROGRAM - 320 GPM, 2300/2250 PSI ON/OFF BTM, 150 RPM, 25/25 KFT-LBS TORQUE ON/OFF BTM, UP TO 18 KLBS WOB - PU 300 KLBS, SO 174 KLBS, ROT 206 KLBS -SURVEY EVERY STAND - 5-10 BPH LOSSES WHILE DRILLING AHEAD - MUD WEIGHT IN/OUT = 9.0 PPG - GAS WATCH: AVG BACKGROUND 240 UNITS, MAX 300 16,908.00 PROD? CIRCULATE AN OPEN HOLE VOLUME (-140 BBLS) - 320 GPM, 2250 PSI, 150 SPM, 25 KFT-LBS TORQUE -MUD WEIGHT IN/OUT =9.0 PPG 16,908.00 PROD1 PUMP OUT OF THE HOLE FROM 16908' MD TO 116000' MD - MONITOR WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM: STATIC LOSS RATE - 2BPH - PU 305 KLBS, SO 148 KLBS AT 16800' MD - 2 BPM, 500 PSI - PULLING AT < 70 FPM 16,908.00 PROD? RUN IN THE HOLE ON ELEVATORS FROM 16000' MD TO TO AT 16908' MD - MONITOR WELL FOR 10 MIN: STATIC LOSS RATE -2 BPH - MUD WEIGHT IN/OUT = 9.0 PPG - MONITOR WELL WITH TRIP TANK AND HOLE FILL WHILE RUNNING IN 16,908.00 PROW CIRCULATE 2X BOTTOMS UP, 612 BBLS - STAGE UP PUMPS IN 1 BPM INCREMENTS - 320 GPM; 2300 PSI - 150 RPM, 23 KFT-LBS TORQUE - STANDING BACK ONE STAND PER HOUR Printed 3/28/2019 8.32:58AM **All depths reported in Drillers Depths** North America - ALASKA- BP Operation Summary Report VVII IF I IVII Y Event Type: RE -ENTER -ONSHORE (RON) Start Date. 2/28/2019 ProiecL PBU Site: 16 Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level) Date From - To Ars Task Code (hr) 06:00 - 09:00 3.00 DRILL P 0900 - 14:00 5.00 14.00 - 14'.30 0.50 14 30 - 16'.00 150 DRILL P DRILL P DRILL P End Date: 3/14/2019 NPT Total Depth Phase (usft) Page 22 of 22 AFE No X3 -0197F -C:(5,676,591.00) Rig Release: 3/222019 BPUOI: USA00001922 Description of Operations 16,908.00 PROD1 PUMP OUT OF THE HOLE FROM 16640' MD TO 13980' MD - MONITOR WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM: STATIC LOSS RATE - 2 BPH - PU 305 KLBS, SO 148 KLBS AT 16500' MD - 2 BPM, 400 PSI - PULLING AT 70-90 FPM - MUD WEIGHT IN/OUT = 9.0 PPG 16,90800 PROD1 PULL OUT OF THE HOLE ON ELEVATORS FROM 13980' MD TO 7321' MD - PU 265 KLBS, SO 165 KLBS AT 13900' MD - MONITOR THE WELL WITH HOLE FILLAND TRIP TANK, 3 BPH LOSS RATE - MUD WEIGHT IN/OUT = 9.0 PPG - PULLED 30K OVER AT 10500' MD AND 10450' MD - MONITOR THE WELL FOR 10 MIN AT THE 7" SHOE (10286' MD): STATIC LOSS RATE 34 BPH - MONITOR THE WELL FOR 10 MIN AT THE 7" LINER TOP (7321' MD): STATIC LOSS RATE 3-4 BPH_ 16,908.00 PROD1 SERVICE RIG - CHANGE OUT WASH PIPE - GREASE BLOCKS AND TOP DRIVE - CHECK HYDRAULIC AND GEAR OIL LEVELS ON TOP DRIVE 18,908.00 PROD1 CIRCULATE 2X BOTTOMS UPAT THE 7" LINER TOP, 7321' MD - 340 GPM; 1620 PSI - 80 RPM, 4 KFT-LBS TORQUE - RECIPROCATE PIPE 65' 1600 - 2000 4.00 DRILL P 16,908.00 PRODi CONTINUE TO PULL OUT OF THE HOLE ON ELEVATORS FROM 7321' MD TO TOP OF THE BHAAT 154'MD -MONITOR THE WELL FOR 10 MIN: STATIC LOSS RATE 3-4 BPH - PU 154 KLBS, SO 135 KLBS AT 7321' MD - LAY DOWN 5 STANDS OF 4" H WOP FROM 6777' MD TO 6375' MD 20:00 - 21:00 1.00 DRILL P 16 908.00 PROD? PULLAND LAY DOWN 6-1/8" RSS DRILLING ASSEMBLY FROM 154' MD - LAY DOWN 3 FLEX COLLARS TO PIPE SHED - BREAK OUT BIT AND FLUSH AUTOTRAK - LAY DOWN BCPM, ONTRAK AND AUTOTRAK TO PIPE SHED -BIT GRADE: 1 -1 - NO - N - X - I - NO - TD END RON EVENTAT 21:00 HRS ON MARCH 14, 2019 Printed 3/282019 8:32:58AM "AII depths reported in Drillers Depths" Common Well Name: i6-14 Event Type: COM- ONSHORE (CON) North America - ALASKA - BP Operation Summary Report Start Date. 3/14/2019 Eno Date. 3/22/2019 Site: 16 AFE No (2,917 406 00 ) Page 1 of 15 Rig Contractor: PARKER DRILLING CO. PIPE SHED PER APPROVED LINER RUN _.TALLY 23:30 - 00:00 0.50 CASING P 16,908.00 RUNPRD BPUOI: USA00001922 Active datum ACTUAL KB P272 @82.93usft (above Mean Sea Level) 'PRODUCTION LINER WITH FRAC SLEEVES - MAKE UP FLOAT SHOE, FLOAT COLLAR AND Date From - To Him Task Code NET Total Depth Phase Description of Operations 3/15/2019 0000 - 0930 9.50 CASING P 16,908.00 RUNPRD (hr) (usft) SLEEVES TO 6746' MD 3/14/2019 21:00 - 21:30 0.50 CASING P 16,908.00 RUNPRD BEGIN 16-14C CON EVENTAT 21:00 HRS HTTC CONNECTIONS - TORQUE 4-1/2" VAMTOP HTTC CLEAN AND CLEAR RIG FLOOR 21:30 - 22:30 1.00 CASING P 16,908.00 RUNPRD RIG UPTO RUN 4-1/2", 12.8 #/FT VAMTOP - RUN (1) 4.5" x 5.85" VOLANT HYDROFORM CENTRALIZER LOCKED DOWN 4' FROM PIN HTTC PRODUCTION LINER - RUN (1) 4.5'x 5.85" VOLANT HYDROFORM CENTRALIZER LOCKED DOWN MID -JOINT ON ,-RIG UP 41/2" SIDE -DOOR ELEVATORS - RUN (2) 4.5" x 5.85" VOLANT HYDROFORM CENTRALIZERS PER JOINT ON JOINTS - RIG UP CASING TONGS RINGS 4' AND 10' FROM PIN, (1) LOCKED DOWN 10' FROM THE BOX - RIG UPTORQUE TURN EQUIPMENT 22:30 - 23:30 1.00 CASING P 16,908.00 RUNPRD ORGANIZE LINER AND FRAC SLEEVES IN Printed 4/10/2019 8:47:16AM '"AII depths reported in Drillers Depths" PIPE SHED PER APPROVED LINER RUN _.TALLY 23:30 - 00:00 0.50 CASING P 16,908.00 RUNPRD RUN 41/2",12.6#/FT VAMTOP HTTC 'PRODUCTION LINER WITH FRAC SLEEVES - MAKE UP FLOAT SHOE, FLOAT COLLAR AND LANDING COLLAR ON RIG FLOOR li '- FILL SHOE TRACK AND CHECK FLOATS: HO_LDIN_G_ _ 3/15/2019 0000 - 0930 9.50 CASING P 16,908.00 RUNPRD CONTINUE TO RUN 4-112",12.6 #/FT VAMTOP HTTC PRODUCTION LINER WITH FRAC SLEEVES TO 6746' MD - BAKERLOK SHOE TRACK -FLOATS: HOLDING '.- USE BEST -O -LIFE 4010NM ON ALL VAMTOP HTTC CONNECTIONS - TORQUE 4-1/2" VAMTOP HTTC CONNECTIONS TO 7830 FT -LBS - RUN (1) 4.5" x 5.85" VOLANT HYDROFORM CENTRALIZER LOCKED DOWN 5' FROM PIN ON JOINT'A' - RUN (1) 4.5" x 5.85" VOLANT HYDROFORM CENTRALIZER LOCKED DOWN 4' FROM PIN ON JOINT PB' - RUN (1) 4.5'x 5.85" VOLANT HYDROFORM CENTRALIZER LOCKED DOWN MID -JOINT ON JOINT'C' - RUN (2) 4.5" x 5.85" VOLANT HYDROFORM CENTRALIZERS PER JOINT ON JOINTS #1-138: (1) FREE-FLOATING BETWEEN STOP RINGS 4' AND 10' FROM PIN, (1) LOCKED DOWN 10' FROM THE BOX -TOTAL CENTRALIZERS RUN = 279, TOTAL STOP RINGS = 557 - FILL LINER EVERY 10 JTS - RUN A TOTAL OF 27 FRAC SLEEVE ASSEMBLIES - MUD WEIGHT IN/OUT = 9.0 PPG - PU 121 KLBS, SO 111 KLBS AT 6801' MD 09.30 - 10:30 1.00 CASING P 16,908.00 RUNPRD MAKE UP LINER HANGER/LINER TOP PACKER ASSEMBLY PER BAKER REP - MAKE UP LINER WIPER PLUG ON BOTTOM OF SLICK STICK - MAKE UP LINER HANGER/ LINER TOP PACKER ASSEMBLY -ADD PAL MIXAND SECURE JUNK BONNET - PU 121 KLBS, SO 111 KLBS AT 680.1' MD 1030 - 11:00 0.50 CASING P 16,908 00 RUNPRD CIRCULATE 1.5X LINER VOLUME - 5 BPM, 200 PSI 1MUD WEIGHT IN/OUT =9.0 PPG Printed 4/10/2019 8:47:16AM '"AII depths reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Page 2 of 15 Common Well Name'. 16-14 AFE No Event Type: COM- ONSHORE (CON) Start Date: 3/14/2019 Eod Date: 3/22/2019 X3 -0197F -C: (2,917,406.00 ) Project: PBU Site: 16 Rig Name/No.: PARKER 272 Spud Date/Time: 2/16/2006 12:00:OOAM Rig Release: 3/22/2019 Rig Contractor: PARKER DRILLING CO. BPUOI'. USA00001922 Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 11:00 - 1400 3.00 CASING P 16,908.00 RUNPRD CONTINUE TO RUN 4-1/2" VAMTOP HTTC LINER ON 4" AND 5" DRILL PIPE STANDS FROM 6801' MD TO 10270' MD, 16' ABOVE THE 7" SHOE - RUN IN THE HOLE AT 90 FPM - PU 180 KLBS, SO 161 KLBS AT 10270' MD 14:00 - 14:30 0.50 CASING P 16,908.00 RUNPRD SERVICE TOP DRIVE GREASE WASHPIPE 14:30 - 15:30 1.00 CASING P 16,908.00 RUNPRD CIRCULATE 1.SX LINER AND DRILL PIPE VOLUMES PRIOR TO ENTERING OPEN HOLE - 5 BPM, 500 PSI - MUD WIEGHT IN/OUT = 9.0 PPG ESTABLISH ROTATING PARAMETERS: - 10 RPM, 4.9 KFT-LBS TORQUE '- 15 RPM, 5.1 KFT-LBS TORQUE ]-20 RPM, 4.8_KF_T-LBS TORQUE 15.30 - 16.00 0.50 CASING P 16,908.00 RUNPRD CONTINUE TO RUN 4-1/2" VAMTOP HTTC LINER ON 5" DRILL PIPE STANDS FROM 10270' MD TO 10720' MD - RUN IN THE HOLE AT 90 FPM ENCOUNTER TIGHT HOLEAT 10720' MD - ATTEMPT TO WORK THROUGH WITH 20 KLBS - PICK UP FREE WITH 25 KBLS OVERPULL - ATTEMPT TO WORK THROUGH WITH 30 KLBS - PULL UP TO 235 KLBS (40 KLBS OVERPULL) AND UNABLE TO PULL FREE Printed 4/10/2019 8:47:16AM **All depths reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Common Well Name. 16-14 AFE No Event Type. COM- ONSHORE (CON) Start Date: 3/14/2019 End Date: 3/22/2019 X3 -0197F -C. (2,917,406 00 ) Project: PBU Site: 16 Rig Name/No.: PARKER 272 Spud Date/Time: 2/16/2006 12*00:001 Rig Release: 3/22/2019 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00001922 Active datum: ACTUAL KB P272 ®82.93usft (abc Date From - To Him (hr) _ 18:00 - 00:00 8.00 Mean Sea Level) Task 1 Code I NPT -+ CASING N 3/16/2019 00:00 - 01:00 1.00 CASING N 01:00 - 02:00 1.00 CASING N 02:00 - 02:30 0.50 CASING N Page 3 of 15 Total Depth Phase Description of Operations oaf 18,908.00 RUNPRD CONTINUE TO WORK TIGHT HOLE FROM 10720' MD TO 10730' MD - WORK PIPE WITH 40-55 KLBS OVERPULL WITH AND WITH OUT PUMPS (2 BPM, 230 PSI) iWITHOUTSUCCESS - NO INDICATIONS OF PACK -OFF OR CUTTINGS BEDS WHILE WORKING PIPE WITH PUMPS ON - DISCUSS WITH ODE AND WOS - PULL UP TO 270 KLBS (75 KLBS OVERPULL) IN 5 KLBS INCREMENTS TO BREAK FREE - PULL AND STAND BACK 2 STANDS TO WIPE HOLE, NO ISSUES NOTED WHILE PULLING - PU 194 KLBS, SO 146 KLBS AT 10554' MD - RUN BACK IN THE HOLE AND TAG UPAGAIN AT 10730' MD - ATTEMPT TO WORK THROUGH SETTING 25- 50 KLBS SEVERAL TIMES MAKING A SMALL AMOUNT OF HEADWAY EACH TIME (1-2') - PULL UP TO 253 KLBS (60 KLBS OVERPULL) TO FREE PIPE - SET DOWN 60 KLBS AND MADE T TO 10740' MD - PULL UP TO 266 KLBS (75 KBLS OVERPULL) AND UNABLE TO PULL FREE -ATTEMPT TO WORK FREE, PULLING TO 270 KLBS, WITH AND WITH OUT PUMPS (UP TO 5 BPM, 533 PSI) WITHOUT SUCCESS. - SPOT 40 BBL 5% NXS LUBE PILL IN OPEN HOLE AND ATTEMPT TO WORK FREE, PULLING UP TO 270 KLBS MULTIPLE TIMES WITHOUT SUCCESS. - CONTINUE TO WORK PIPE WITH AND WITHOUT PUMPS, PULLING UP TO 275K LBS WITHOUT SUCCESS - DISCUSS WITH ODE, WOS, ETLAND WOM TO DEVELOP PLAN FORWARD - PUMP SECOND 40 BBL 5% NXS LUBE PILL 16,908.00 RUNPRD CONTINUE TO WORK TIGHT HOLEAT 12730' MD - SPOT A SECOND 40 BBL 5% NXS LUBE PILL IN OPEN HOLE - PULL UP TO 300 KLBS (106 KLBS OVERPULL) AND HOLD FOR 5 MIN. REPEAT 3 TIMES - PULLED FREE ON THIRD ATTEMPT, PULLED TO 302 KLBS - PU 185 KLBS, SO 148 KLBS AT 10600' MD - MONITOR THE WELL FOR 10 MIN, STATIC LOSS RATE -2 BPM 16,908.00 RUNPRD PULL OUT OF THE HOLE WITH 4-1/2" PRODUCTION LINER, STANDING BACK DRILL PIPE - MONITOR THE WELL FOR 10 MIN AT THE 7" SHOE (10286' MD), STATIC LOSS RATE -2 BPM - PU 171 KLBS, SO 140 KLBS AT 9800' MD _ } - MUD WEIGHT IN/OUT= 9.0 PPG 16,908.00 1 RUNPRD PERFORM DERRICK INSPECTION - INSPECT TOP DRIVE, DERRICKAND DRILL LINE Pnnted 4/10/2019 8:47a6AM **All depths reported in Drillers Depths" Common Well Name: 16-14 Event Type: COM- ONSHORE (CON) Project: PBU North America -ALASKA - BP Page 4 of 15 Operation Summary Report AFE No Start Date: 3/14/2019 End Date: 3/22/2019 X3 -0197F -C'.(2,917 406.00) Rig Contractor: PARKER DRILLING CO. BPUOI: USA00001922 Active datum: ACTUAL KB P272 @82.93ustt (above Mean Sea Level) Date From - To Hm Task Code NPT Total Depth Phase Description of Operations On _ _ _ (usft) 0230 - 0400 1.50 CASING N 16,908.00 RUNPRD CONTINUE TO PULLOUT OF THE HOLE WITH 4-1/2" PRODUCTION LINER, STANDING BACK DRILL PIPE - MONITOR THE WELL FOR 10 MIN AT THE 7" LINER TOP, STATIC LOSS RATE -2 BPM - PU 168 KLBS, SO 136 KLBS AT 9400' MD - MUD WEIGHT IN/OUT = 9.0 PPG 04:00 - 05:00 1.00 CASING N 16,908.00 RUNPRD RIG UP TO PULLAND LAY DOWN 4-1/2" PRODUCTION LINER -CLEAN RIG FLOOR - RIG UP CASING TONGS '- HOLD PJSM WITH RIG CREW, DOYON CASING, BAKER AND VAM REP ON PULLING AND LAYING DOWN THE LINER HANGER / LINER TOP PACKER ASSEMBLYAND 4-1/2" VAMTOP HTTC LINER. 05:00 - 15:00 10.00 CASING N 16,908.00 RUNPRD . PULL AND LAY DOWN BAKER LINER HANGER /LINER TOP PACKER AND 4-1/2" VAMTOP HTTC LINER WITH FRAC SLEEVES FROM 6800' MD - LAY DOWN BUMPER SUB, LINER HANGER / 'LINER TOP PACKER ASSEMBLY PER BAKER REPRESENTATIVE - PU 115 KLBS, SO 106 KLBS AT 6300' MD PULL AND LAY DOWN 4-1/2"VAMTOP HTTC LINER AND FRAC SLEEVES - VAM REP ON SITE TO INSPECT THREADS AFTER LAYING DOWN IN PIPE SHED - RINSE THREADS, APPLY LIGHT COAT OF BEST -O -LIFE 401ONM THREAD DOPE AND INSTALL THREAD PROTECTOR PRIOR TO LAYING DOWN TO PIPE SHED - FLUSH SHOE TRACK WITH WATER, DRY THREADS AND RACK BACK IN COLLAR FINGER - MONITOR WELL WITH HOLE FILLAND TRIP TANK: -24 BPH LOSS RATE - MUD WEIGHT IN/OUT = 9.0 PPG 15:00 - 16:00 1.00 CASING N 16,908.00 RUNPRD RIG DOWN LINER RUNNING EQUIPMENT - RIG DOWN DOYON CASING TONGS AND ELEVATORS - BREAK DOWN XO AND FOSV - CLEAN AND CLEAR RIG FLOOR 1600 - 1700 1.00 CASING N 16,908.00 RUNPRD SLIP AND CUT DRILL LINE AND RECALIBRATE BLOCKS - HANG OFF BLOCKS - CUT 11 WRAPS OF LINE - SPOOL NEW LINE AND TORQUE DEADMAN ANCHOR - CALIBRATE WEIGHT INDICATOR PANCAKE GAUGE -CALIBRATE BLOCKS 17:00 - 1730 0.50 CLEAN IN 16,908.00 RUNPRD MOBILIZE CLEAN OUT BHA COMPONENTS TO RIG FLOOR Printed 4/10/2019 8:47'.16AM •'All depths reported in Drillers Depths" Common Well Name: 16-14 Event Type: COM -ONSHORE (CON) st: PBU North America - ALASKA - SP Operation Summary Report Start Date: 3/14/2019 Site: 16 Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level) Date From - To Hrs Task Code NPT (hr) 17:30 - 19:30 2.00 CLEAN N 19:30 - 00:00 4.50 CLEAN N 3/17/2019 0000 - 0200 2.00 CLEAN N 0200'. - 07'.30 5.50 CLEAN N 0730 - 0800 0.50 CLEAN N Page 5 of 15 AFE No End Dale'. 3/22/2019 X3 -0197F -C'. (2,917,406.00 ) BPUOI: USA00001922 Total Depth Phase Description of Operations (usft) 16,908.00 RUNPRD MAKE UP AND RUN IN THE HOLE WITH BHA #7,6.118" CLEANOUT ASSEMBLY TO 202' MD -6-1/8" INSERT BIT W1 JETS PULLED AND FULL GUAGE NEAR BIT STABILIZER - COLLAR FOLLOWED BY: STABILIZER AND PONY COLLAR (x3) -BAKER ONTRAKAND BCPM -PLUG INAND VERIFY MWD PER BAKER REP - PU 45 KLBS, S045 KLBS AT 202' MD - MONITOR WELL WITH HOLE FILLAND TRIP TANK: -2 BPH LOSS RATE - MUD WEIGHT IN/OUT = 9.0 PPG 16,908.00 RUNPRD RUN IN THE HOLE ON ELEVATORS WITH BHA #7 ON 4" DRILL PIPE TO 6919' MO - FILL PIPE EVERY 2000' MD - SHALLOW HOLE TEST MWD AT 2097'MD AND 3994' MD: GOOD '- MONITOR WELL WITH HOLE FILLAND TRIP TANK: -2 BPH LOSS RATE -MUDWEIGHT IN/OUT=9.0 PPG 16,906.00 RUNPRD CONTINUE TO RUN IN THE HOLE ON ELEVATORS WITH BHA #7,6-118" CLEANOUT ASSEMBLY FROM 6919' MO TO 7" CASING SHOE AT 10286'MD - FILL PIPE EVERY 2000' MD - MONITOR WELL WITH HOLE FILLAND TRIP TANK: -2 BPH LOSS RATE -MUD WEIGHT IN/OUT =9.0 PPG - PU 185 KLBS, SO 150 KLBSAT 10288' MD 16,908.00 RUNPRD REAM DOWN FROM 10287' MD TO 10990' MD - 350 GPM, 1700 PSI - 120 RPM, 5-8 KFT-LBS TORQUE - PU 185 KLBS, SO 150 KLBS, ROT 165 KLBS - REAM DOWN AT 400 FPH - BACK REAM UPAS REQUIRED AT 200 FPH TIGHT SPOTS: 10456' MD TO 10463' MD: UP TO 7 KLBS WOB, 10 KFT-LBS TORQUE 10487' MD TO 10513' MD: UP TO 9 KLBS WOB, 11 KFT-LBS TORQUE 10550' MD TO 10610' MD: UP TO 14 K LBS WOB, 10-16 KFT-LBS TORQUE - BACKREAM FROM 10610' MD TO 10540' MD - RUN STAND BACK IN ON ELEVATORS, TOOK 7-9 KLBS - BACK REAM STAND SECOND TIME - RUN STAND BACK IN ON ELEVATORS WITH NO ISSUES 16,908.00 RUNPRD PULL OUT OF THE HOLE ON ELEVATORS FROM 10990' MD TO 10287' MD - MONITOR THE WELL FOR 10 MIN: STATIC LOSS RATE -2 BPH - PU 195 KLBS, SO 150 KLBS AT 10287'MD - MONITOR WELL WITH HOLE FILLAND TRIP TANK: -2 BPH LOSS RATE - MUD WEIGHT IN/OUT = 9.0 PPG NO HOLE ISSUES NOTED WHILE PULLING Printed 4/10/2019 8:47:16AM **Ali depths reported in Drillers Depths" Common Well Name. 16-14 Event Type. COM- ONSHORE (CON) Project: PBU Rig Name/No.: PARKER 272 North America - ALASKA - BP Page 6 of 15 Operation Summary Report Start Date'. 3/14/2019 End Date: 3/22/2019 Site: 16 Spud Date/Time: 2/16/2006 12:00:OOAM AFE No X3 -0197F -C:(2,917,406.00) Rig Contractor: PARKER DRILLING CO. BPUOI: USA00001922 Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) .. _(usft) 08:00 - 08:30 0.50 CLEAN N 16,908.00 ' RUNPRD RUN IN THE HOLE WITH 8-1/8" CLEANOUT ASSEMBLY ON ELEVATORS FROM 10287' MD TO 11000' MD -MONITOR WELL WITH HOLE FILLAND TRIP I TANK: -2 BPH LOSS RATE -MUD WEIGHT IN/OUT = 9.0 PPG - PU 195 KLBS, SO 150 KLBS AT 10990' MD ENCOUNTER TIGHT HOLE AT 11000' MD, SET DOWN 30 KLBS AND UNABLE TO WORK THROUGH 0830 - 2330 15.00 CLEAN N 16,908.00 RUNPRD CONTINUE TO REAM DOWN FROM 10990' MD TO 15809' MD - 350 GPM, 2300 PSI 120 RPM, 5-18 KFT-LBS TORQUE 'I- 183 KLBS ROTATING WEIGHT - REAM DOWN AT 400-600 FPH, FROM 10990' MD TO 11 990'MD - REAM DOWN AT 500-700 FPH, FROM 11990' MD TO 15809' MD - MUD WEIGHT IN/OUT 9.1 PPG - DYNAMIC LOSS RATE -7 BPH TIGHT SPOTS: 11535' MD: SET DOWN 40 KLBS, PULLED 30-40 KLBS OVER W/O SUCCESS. JARRED UP WITH 50 KLBS OVER TO PULL FREE 13660' MD: ATTEMPT TO RUN ON ELEVATORS, SET DOWN 20 KLBS. PULLED FREE WITH 15 -'. KLBS OVER 2330 - 0000 0.50 CLEAN N 16,908.00 RUNPRD SERVICE TOP DRIVE AND BLOCKS - GREASE WASHPIPE - CHECK HYDRAULIC AND GEAR OIL LEVELS - INSPECT NC50 SAVER SUB THREADS: GOOD - - - 3/18/2019 00:00 - 04:00 4.00 CLEAN N 16,908.00 RUNPRD CONTINUE TO REAM DOWN FROM 15809' MD ! TO 16908' MD - 350 GPM, 2330 PSI -120 RPM, 5-18 KFT-LBS TORQUE - 187 KLBS ROTATING WEIGHT - REAM DOWN AT 500.700 FPH - MUD WEIGHT WOUT 9.1 PPG DYNAMIC LOSS _RATE _-7_-10 BPH - 0430 0.50 CLEAN N 16,908.00 RUNPRD PERFORM POST JARRING DERRICK 10400 - INSPECTION _ 04:30 - 0500 0.50 CLEAN N 16,908.00 RUNPRD CIRCULATE AN OPEN HOLE VOLUME .350 GPM, 2413 PSI - 120 RPM, 16 KFT-LBS TORQUE - PU 250 KBLS, SO 160 KLBS AT 16900' MD - MUD WEIGHT IN/OUT 9.1 PPG - DYNAMIC LOSS RATE -15 BPH 05:00 - 09:00 4.00 CLEAN N 16,908.00 RUNPRD PUMP OUT OF THE HOLE FROM 16908' MD TO 13916' MD - MONITOR WELL FOR 10 MIN: STATIC LOSS RATE -10 BPH - 2 BPM, 300 PSI - PULLING AT 70-90 FPM - PU 235 KLBS, SO 148 KLBS AT 15700' MD - MUD WEIGHT IN/OUT = 9.1 PPG Printed 4/10/2019 8:47:16AM **All depths reported in Drillers Depths" Common Well Name: 16-14 Event Type: COM- ONSHORE (CON) Project: PBU Rig Name/No.: PARKER 272 North America - ALASKA- BP Operation Summary Report Start Date: 3/14/2019 End Dale: 3/222019 Site: 16 Spud Date/Time: 2/16/2006 12:00:OOAM Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level) AFE No K3 -0197F -C:(2,917,406.00) BPUOI: USA00001922 Page 7 of 15 Date From - To Hm Task Code NPT Total Depth Phase Descrip0on of Operations _ (hr) (usft) 09:00 - 11:00 2.00 CLEAN N 16,908.00 RUNPRD PULLOUTOFTHE HOLE ON ELEVATORS FROM 13916' MD TO 10890' MO - PU 214 KLBS, SO 163 KLBS AT 13800' MD - MONITOR WELL WITH HOLE FILL AND TRIP TANK: STATIC LOSS RATE -8 BPH - MUD WEIGHT IN/OUT = 9.1 PPG 1100 - 13:00 2.00 CLEAN N 16,908.00 RUNPRD BACK REAM OUT OF THE HOLE, THROUGH THE BUILD SECTION, FROM 10890' MD TO 10286' MD - MONITOR THE WELL FOR 10 MIN: STATIC LOSS RATE -7-8 BPH - 350 GPM, 1900 PSI - 120 RPM, 7 KFT-LBS TORQUE - 160 KLBS ROTATING WEIGHT '- BACKREAMING SPEEDS FROM 400-500 FPH - MUD WEIGHT IN/OUT = 9.1 PPG DYNAMIC LOSS RATE -6-7 BPH 13.00 - 13:30 0.50 CLEAN N 16,908.00 ,- RUNPRD RUN IN THE HOLE WITH 6-1/8" CLEANOUT ASSY, THROUGH THE BUILD SECTION, ON ELEVATORS FROM 10286' MD TO 10804' MD I 1 - PU 180 KLBS, SO 150 KLBS AT 10286' MD - MONITOR WELL WITH HOLE FILL AND TRIP TANK: STATIC LOSS RATE -6 BPH - MUD WEIGHT IN/OUT = 9.1 PPG _ NO ISSUES NOTED RUNNING IN 13:30 - 1400 0.50 CLEAN N 16,908.00 RUNPRD PULL OUT OF THE HOLE, THROUGH THE BUILD SECTION, ON ELEVATORS FROM 10804' MD TO 10265' MD - PU 190 KLBS, SO 150 KLBS AT 10804' MD - MONITOR WELL WITH HOLE FILLAND TRIP TANK: STATIC LOSS RATE -6 BPH - MUD WEIGHT IN/OUT = 9.1 PPG NO HOLE ISSUES NOTED WHILE PULLING OUT 14:00 - 1500 1.00 CLEAN N 16,908.00 RUNPRD CIRCULATE BOTTOMS UP AT THE r, SHOE - 350 GPM, 1830 PSI - 80 RPM, 6 KFT-LBS TORQUE - RECIPROCATE PIPE 90' DURING CIRCULATION - MUD WEIGHT IN/OUT = 9.1 PPG 1500 - 1630 150 CLEAN N 16,908.00 RUNPRD PULLOUT OF THE HOLE ON ELEVATORS FROM 10286' MD TO TOP OF 7" LINER AT 7321' MD -MONITOR WELL FOR 10 MIN: STATIC LOSS RATE -6-7 BPH - PU 140 KLBS, SO 130 KLBS AT 7321' MD - MONITOR WELL WITH HOLE FILL AND TRIP TANK: STATIC LOSS RATE -5-6 BPH _ -MUD WEIGHT IN/OUT =9.I PPG 16:30 - 17:30 1.00 CLEAN N 1 16,908.00 RUNPRD CIRCULATE BOTTOMS UP AT THE 7" LINER TOP - 350 GPM, 1500 PSI - 80 RPM, 3 KFT-LBS TORQUE '- RECIPROCATE PIPE 90'DURING (CIRCULATION - MUD WEIGHT IN/OUT = 9.1 PPG Printed 4/10/2019 8:47:16AM "All depths reported in Drillers Depths** Common Well Name. 16-14 Event Type. COM- ONSHORE (CON) North America - ALASKA - BP Page 8 of 15 Operation Summary Report AFE No Start Date. 3/14/2019 End Date. 3/22/2019 X3 -0197F -C'. (2.917,406 00 ) Project: PBU Site: 16 Rig Name/No.: PARKER 272 Spud Daterrme: 2/16/2006 12:00:00AM Rig Release: 3/22/2019 Active datum: ACTUAL KB P272 Date From - To isit (above Mean Sea Level) Hrs Task Code NPT Total Depth Phase Description of Operations 17:30 - 21:00 3.50 CLEAN 21:00 - 2230 1.50 CLEAN 2230 - 2300 0.50 CLEAN 2300 - 2330 0.50 CASING 2330 - 0000 3/19/2019 0000 - 0900 0.50 CASING 9.00 CASING 09.00 - 09'.30 0.50 CASING (usft) N 16,908.00 RUNPRD PULL OUT OF THE HOLE ON ELEVATORS FROM 7321' MD TO 202' MD - MONITOR THE WELL FOR 10 MIN: STATIC LOSS RATE -5-6 BPH - PU 45 KLBS, SO 45 KLBS AT 202'MD - MONITOR WELL WITH HOLE FILLAND TRIP TANK: STATIC LOSS RATE -5-6 BPH -MUD WEIGHT IN/OUT=9.I PPG N 16,908.00 RUNPRD PULLAND LAY DOWN BHA #7,6-1/8" CLEANOUTASSY FROM 202' MD -MONITOR WELL WITH HOLE FILLAND TRIP TANK: STATIC LOSS RATE -5-6 BPH - MUD WEIGHT IN/OUT = 9.1 PPG -DULL BIT GRADE: 3 -2 -BT -A -E -1 -LT -TD N 16,908.00 _ RUNPRD 'CLEAN AND CLEAR RIG FLOOR N 16,908.00 RUNPRD RIG UP TO RUN 4-1/2", 12.6 #/FT VAMTOP HTTC PRODUCTION LINER - RIG UP 4-1/2" SIDE -DOOR ELEVATORS - RIG UP CASING TONGS RIG UP_ TORQUE TURN EQUIPMENT N 16,908.00 RUNPRD SERVICE AND INSPECT PIPE CAT IN 16,908.00 RUNPRD RUN 4-117, 12.6 #/FT VAMTOP HTTC PRODUCTION LINER WITH FRAC SLEEVES TO 6804' MD - BAKERLOK SHOE TRACK - FLOATS: HOLDING - USE BEST -O -LIFE 4010NM ON ALL VAMTOP HTTC CONNECTIONS - TORQUE 4-1/2" VAMTOP HTTC CONNECTIONS TO 7830 FT -LBS - RUN (1) 4.5" x 5.85" VOLANT HYDROFORM CENTRALIZER LOCKED DOWN 5' FROM PIN ON JOINT kA' - RUN (1) 4.5" x 5.85" VOLANT HYDROFORM CENTRALIZER LOCKED DOWN 4' FROM PIN ON JOINT'B' - RUN (1) 4.5" x 5.85" VOLANT HYDROFORM CENTRALIZER LOCKED DOWN MIDJOINT ON JOINT'C' - RUN (2) 4.5" x 5.85" VOLANT HYDROFORM CENTRALIZERS PER JOINT ON JOINTS #1-138: (1) FREE-FLOATING BETWEEN STOP RINGS 4' AND 10' FROM PIN, (1) LOCKED DOWN 10' FROM THE BOX - TOTAL CENTRALIZERS RUN = 279, TOTAL STOP RINGS = 557 - FILL LINER EVERY 10 JTS - RUN ATOTAL OF 27 FRAC SLEEVE ASSEMBLIES - MUD WEIGHT IN/OUT = 9.1 PPG - PU 111 KLBS, SO 103 KLBS _ N 16,908.00 RUNPRD MAKE UP LINER HANGER/LINER TOP PACKER ASSEMBLY PER BAKER REP - MAKE UP LINER WIPER PLUG ON BOTTOM OF SLICK STICK - MAKE UP LINER HANGER / LINER TOP PACKERASSEMBLY - ADD PAL MIX AND SECURE JUNK BONNET - RIG DOWN CASING EQUIPMENT Printed 4/10/2019 8.4716AM **All depths reported in Drillers Depths" North America - ALASKA - BP Page 9 of 15 Operation Summary Report Common Well Name. 16-14 AFE No Event Type. COM- ONSHORE(CON) Start Date'. 3/14/2019 End Date. 3/22/2019 X3 -0197F -C:(2,917,406,00) Project: PBU - - Site: 16 -- - - _ - - - Rig Name/No.: PARKER 272 Spud DateTme: 2/16/2006 12:00:OOAM Rig Release: 3/22/2019 Rig Contractor: PARKER DRILLING GO. BPUOI: USA00001922 Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hQ 109:30 - - _ - - _ - -0311) - 10:00 0.50 CASING N 16,908.00 RUNPRD CIRCULATE 1.SX LINER VOLUME - 5 BPM, 200 PSI - MUD WEIGHT IN/OUT = 9.1 PPG SIMOPS: -CONTINUE TO RIG DOWN CASING EQUIPMENT 10.00 - 13:00 3.00 CASING N 16,908.00 1 RUNPRD CONTINUE TO RUN 4-1/2" VAMTOP HTTC LINER ON 4" AND 5" DRILL PIPE STANDS FROM 6804' MD TO 10270' MD, 16' ABOVE THE T' SHOE " - RUN IN THE HOLE AT 90 FPM - PU 162 KLBS, SO 135 KLBS AT 10270' MD - FILL PIPE EVERY 2000' MD -MONITOR WELL WITH HOLE FILLAND TRIP TANK: 4-5 BPH LOSS RATE WHILE RUNNING _-MUD WEIGHT IN/OUT =9.1 PPG 13:00 - 13:30 0.50 CASING N 16,908.00 RUNPRD CIRCULATE 1.5X LINER AND DRILL PIPE VOLUMES PRIOR TO ENTERING OPEN HOLE - 5 BPM, 525 PSI - MUD WIEGHT IN/OUT = 9.1 PPG ESTABLISH ROTATING PARAMETERS: -10 RPM, 3.8 KFT-LBS TORQUE - 15 RPM, 4.1 KFT-LBS TORQUE _- 20 RPM, 4.5 KFT-LBS TORQUE _ 13:30 - 14:00 0.50 CASING N 16,906.00 RUNPRD CONTINUE TO RUN 4-1/2" VAMTOP HTTC LINER ON 5" DRILL PIPE STANDS FROM 10270' MD TO 10720' MD RUN IN THE HOLE AT 90 FPM 1400 -, 1830 4.50 CASING P 16,908.00 RUNPRD CONTINUE TO RUN 4-1/2" VAMTOP HTTC LINER ON 5" DRILL PIPE STANDS FROM 10720' MD TO 16906' MD - RUN IN THE HOLE AT 90 FPM - FILL PIPE EVERY 2000' MD - PU 232 KLBS, SO 161 KLBS AT 16888' MD - NO ISSUES NOTED WHILE RUNNING IN THE HOLE - LOSS RATE -4-5 BPH - MUD WEIGHT IN/OUT = 9.0+ PPG MAKE UP CEMENT HEAD AND WASH TO BOTTOM - PICK UP SINGLE JOINTAND CEMENT HEAD - RIG UP CEMENT LINE AND WASH UP LINE TO CEMENT HEAD -WASH DOWN FROM 16888' MD AND TAG BOTTOM AT 16908' MD WITH 5K LBS - PICK UP AND SET LINER TOFF BOTTOM AT 16906' MD LOST TOTAL OF 45 BBLS WHILE RUNNING LINER Printed 4/10/2019 8:47:16AM **All depths reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Common Well Name: 16-14 Event Type. COM- ONSHORE (CON) Start Date: 3/14/2019 End Date. 3/22/2019 Project: PBU — - Site: 16 --- _--- AFE No X3 -0197F -C:(2,917, 406 00) Page 10 of 15 Rig Name/No.: PARKER 272 Spud Date/time: 2/16/2006 12:00:OOAM Rig Release: 3/22/2019 Rig Contractor. PARKER DRILLING CO. BPUO1: USA00001922 Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations _ - (hr) - _ _ _ deft) 18:30 - 23:30 5.00 CASING P 16,908.00 RUNPRD STAGE UP TO CEMENTING RATE IN 1 BPM INCREMENTS TOA FINAL CEMENTING RATE OF 5 BPM - 2 BPM, 800 PSI - 3 BPM, 960 PSI - 4 BPM, 1170 PSI - 5 BPM, 1465 PSI - CONDITION MUD TO 16 YP - FINAL CIRCULATING RATE AFTER HOLE CONDITIONED: 1390 PSI - CIRCULATE A TOTAL OF 2X BOTTOMS UP - RECIPROCATE 6' OF PIPE STRETCH AT SURFACE LOST TOTAL OF 10 BBLS WHILE CIRCULATING WITH LINER ON BOTTOM SIMOPS: - LAY DOWN DRILL PIPE WITH OFF-LINE _ STAND BUILDING EQUIPMENT 2330 - 0000 0.50 CASING P 16,908.00 RUNPRD CEMENT 4-1/2", 12.6 LB/FT, 13CR85, VAMTOP HTTC PRODUCTION LINER -SEE CEMENTJOB DETAILSON REPORT22- MARCH 20, 2019 Printed 4/10/2019 8.47:16AM **All depths reported in Drillers Depths" Common Well Name. 16-14 Event Type: COM- ONSHORE (CON) Project: PBU Rig Name/No.: PARKER 272 Rig Contractor: PARKER DRILLING CO. Active datum: ACTUAL KB P272 @82.93 Date I From - To 3/20/2019 '00:00 - 01:00 North America - ALASKA - Blo Operation Summary Report Start Date'. 3/14/2019 End Date3/22/2019 Site: 16 Spud Date/Time: 2/16/2006 12:00 00AM jsft (above Mean Sea Level) AFE No X3 -0197F -C (2,917 406 00 ) Release: 3/22/2019 Page 11 of 15 Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 1.00 CASING P 16,908.00 RUNPRD CONTINUE TO CEMENT 4-112",12.6 LB/FT, 13CR85, VAMTOP HTTC PRODUCTION LINER AS FOLLOWS: - FILL LINES WITH MUD PUSH AND PRESSURE TEST TO 4500 PSI FOR 5 MIN: GOOD TEST - PUMP 40 BBLS OF 12.0 PPG MUDPUSH II SPACER AT 5 BPM, 1200 PSI -PUMP 153 BBLS (682 SKS) OF 15.0 PPG ACID -S LUBLE CEMENTAT2-5 BPM, EXCESS VOLUME 30% OPEN HOLE VOL (YIELD =1.26 CU.FT/SK) - RECIPROCATE 6' OF PIPE STRETCH AT SURFACE WHILE PUMPING CEMENTAT5 BPM ,- CLOSE LOWER TIWVALVE AND WASH UP ON TOP OF DART '- OPEN TIW VALVE AND DROP DRILL PIPE WIPER DART PERFORM CEMENT DISPLACEMENT WITH SCHLUMBERGER CEMENT TRUCKS - DISPLACE CEMENT WITH 251.5 BBLS OF 9.0 PPG BRINE AT 5 BPM, SLOWING TO 3 BPM FOR LATCH AND PLUG BUMP - CAUGHT CEMENTAT 100 BBLS INTO DISPLACEMENT: 5 BPM, FCP 2026 PSI - STOPPED RECIPROCATING PIPE STRETCH AFTER CEMENT EXITED SHOE - REDUCED RATE TO 3 BPM 10 BBLS BEFORE DITCH -CONFIRMED DART LATCH UP AT 152 BBLS DISPLACED - RESUMED DISPLACING AT 5 BPM, FCP 3668 PSI - REDUCED RATE TO 3 BPM PRIOR TO PLUG BUMP: FINAL CIRCULATING PRESSURE 2400 PSI - BUMP PLUG AT 2450 PSI AND PRESSURE UP TO 3200 PSI AND HOLD FOR 5 MIN. - TOTAL DISPLACEMENT VOLUME 251.5 BBLS (MEASURED BY TANK VOLUME) - LOSSES FROM CEMENT EXIT SHOE TO CEMENT IN PLACE 8 BBLS - TOTAL LOSSES DURING CEMENT JOB: 16 BBLS - CEMENT IN PLACE AT 01:05 ON 03/20/2019 SIMOPS: - LAY DOWN DRILL PIPE WITH OFF-LINE Panted 4/10/2019 8.47:16AM **All depths reported in Drillers Depths" Common Well Name: 16-14 Event Type. COM- ONSHORE(CON) North America - ALASKA - BP Page 12 of 15 Operation Summary Report Start Date: 3/14/2019 End Date: 3/22/2019 AFE No K3 -0197F -C:(2,917,406.00) Project PBU Site: 16 Rig Name/No.: PARKER 272 Spud Date/time: 2/16/2006 12:00 OOAM Rig Release: 3/22/2019 Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level) Date From - To Hm Task Code NPT Total Depth (hr) (usft) _— —. _ 01:00 - 02:00 1.00 CASING P 18,908.00 02:00 - 03:00 1.00 CASING P I 16,908.00 Phase Description of Operations RUNPRD SET LINER HANGER / LINER TOP PACKER PER BAKER REPRESENTATIVE - INCREASE PRESSURE TO 4500 PSI TO SET 03:00 - 08:00 5.00 CASING P , HANGER AND SHEAR RUNNING TOOL RUNPRD - SET DOWN 60 KLBSAND CONFIRM HANGER SET - BLEED OFF PRESSURE AND CHECK FLOATS: HOLDING - PICK UP TO 232 KLBS: RUNNING TOOL NOT SHEARED -SET DOWN 80 KLBSAND PRESSURE UP TO 4700 PSI - BLEED OFF PRESSURE AND PICK UP TO EXPOSE DOG SUB - SET DOWN 60 KLBS ON LINER TOP WITH 10 RPM, 6 KFT-LBS TORQUE - OBSERVE LINER TOP PACKER SHEAR WITH 25 KLBS - PRESSURE UP TO 900 PSI AND PICK UP TO PULLPACKOFF -OBSERVE PRESSURE DROPAND KICK IN PUMPS TO CIRCULATE OUT EXCESS CEMENT FROM LINER RUNPRD �CLRCULATE EXCESS CEMENT FROM TOP OF RUNPRD .LINER AND DISPLACE WELL TO 9.0 PPG BRINE -PULL RUNNING TOOL ABOVE LINER TOP AND MARK NO-GO - 16 BPM, 2500 PSI -9.0 PPG BRINE IN/OUT - LAY DOWN CEMENT HEAD AND SINGLE TO 0900 - 0930 0.50 BOPSUR P PIPE SHED Pnnted 4110/2019 8:4716AM **All depths reported in Drillers Depths** -20 BBLS OF GOOD CEMENT BACK TO 03:00 - 08:00 5.00 CASING P , 16,908.00 RUNPRD _SURFACE PULL OUT OF THE HOLE ON ELEVATORS, STANDING BACK DRILL PIPE, FROM 10048' MD TO SURFACE - MONITOR WELL FOR 10 MIN: STATIC - PU 211 KLBS, SO 185 KLBS AT 10000' MD - LAY DOWN BAKER LINER RUNNING TOOL AND BUMPER SUB - MONITOR WELL WITH HOLE FILLAND TRIP TANK: HOLE TAKING PROPER FILL BRINE WEIGHT IN/OUT =9.0_PPG _ 08.00 - 0900 1.00 CASING P 16,908.00 RUNPRD CLEAN OUT BOP STACK - MAKE UP STACK FLUSHING TOOL - FLUSH BOP STACK WITH BLACK WATER PILL FOR CEMENT 0900 - 0930 0.50 BOPSUR P 16,908.00 RUNCMP PERFORM WEEKLY ROPE FUNCTION TEST CLOSING TIMES: ANNULAR - 20 SEC, UPPER RAMS - 6 SEC, LOWER RAMS - 6 SEC, BLIND/SHEAR RAMS - 16 SEC, HCR CHOKE - 1 SEC, HCR KILL - 1 SEC WBS: RUNCMP Pnnted 4110/2019 8:4716AM **All depths reported in Drillers Depths** North America - ALASKA- BP Page 13 of 15 Operation Summary Report Common Well Name: 16-14 AFE No Event Type: COM- ONSHORE (CON) Start Date: 3/14/2019 End Date: 3/22/2019 X3 -0197F -C: (2,917,406.00 ) Project: PBU Site: 16 Rig Name/No.: PARKER 272 Spud Date/Time: 2/16/2006 12:00:OOAM Rig Release: 3/22/2019 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00001922 Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations _ (hr) _i (usft) _ 0930 - 1700 7.50 RUNCOM P 16,908.00 RUNCMP PERFORM CEMENT BOND LOG OFT' CASING OM 10175' MD TO 7400' MD -PRE JOB SAFETY MEETING WITH HALLIBURTON E -LINE SERVICES - RIG UP E -LINE SHEAVES - MAKE UP AND RUN IN THE HOLE WITH CBUCCUGR TOOL STRING -LOG CEMENT INTERVAL FROM TOP OF 4-1/2" PRODUCTION LINER TO 7400' - SEND LOGGING SULTS TO ODE AND PETROPHYSICIST FOR INTERPRETATION - RIG DOWN HALLIBURTON E -LINE SIMOPS: - LAY DOWN DRILL PIPE WITH OFF-LINE STAND BUILDING EQUIPMENT 17:00 - 1800 1.00 RUNCOM P 16,908.00 RUNCMP RIG UP TO RUN 41/2", 12.6 LB/FT, 13CR85 VAMTOP LINER - RIG UP DOYON CASING TONGS - RIG UP TORQUE TURN EQUIPMENT - RIG UP SIDE -DOOR ELEVATORS AND MAKE UP XO TO FOSV - VERIFY PIPE COUNT IN PIPE SHED - PICK UP WLEG AND FIRST JOINT AND PERFORM DUMP TEST ON TONGS 1800 - 1830 0.50 RUNCOM N 16,908.00 RUNCMP WAIT FOR APPROVAL TO PROCEED WITH RUNNING COMPLETION - PETROPHYSICIST REVIEWING CBL LOGS FOR CEMENT ISOLATION REQUIREMENTS - TOP OF CEMENT BASED ON CBL 7658' MD - RECEIVED AUTHORIZATION TO PROCEED WITH COMPLETION RUN FROM ODE 1830 - 0000 5.50 RUNCOM P 16,908.00 RUNCMP RUN 4-1/2", 12.6 LB/FT, 13CR85 VAMTOP COMPLETION TO 3867' MD - BAKERLOKALL CONNECTIONS BELOW THE PACKER - USE JET -LUBE SEAL GUARD PIPE DOPE - TORQUE ALL VAMTOP CONNECTIONS TO 4440 FT -LBS - RUN IN THE HOLE AT 90 FT/MIN - MONITOR WELL WITH HOLE FILLAND TRIP TANK: GOOD DISPLACEMENT - BRINE WEIGHT IN/OUT = 9.0 PPG - PU 92 KLBS, SO 88 KLBS AT 3867' MD 321/2019 00'.00 - 07'.00 7.00 RUNCOM P 16,908.00 RUNCMP CONTINUE TO RUN 4-1/2", 12.6 LB/FT, 13CR85 VAMTOP COMPLETION FROM 3867' MD TO 10100' MD - BAKERLOKALL CONNECTIONS BELOW TH E PACKER - USE JET -LUBE SEAL GUARD PIPE DOPE - TORQUE ALL VAMTOP CONNECTIONS TO 4440 FT -LBS - RUN IN THE HOLE AT 90 FT/MIN - MONITOR WELL WITH HOLE FILLAND TRIP TANK: GOOD DISPLACEMENT - BRINE WEIGHT IN/OUT = 9.0 PPG Printed 41102019 8:47'16AM **All depths reported in Drillers Depths" Common Well Name. 16-14 Event Type: COM- ONSHORE (CON) Project: PBU Rig Name/No.: PARKER 272 Rig Contractor: PARKER DRILLING CO. Active datum: ACTUAL KB P272 @82.93 Date From - To 07:00 - 09:30 North America - ALASKA - BP Page 14 of 15 Operation Summary Report Start Date. 3/14/2019 End Date: 3/22/2019 Site: 16 AFE No K3 -0197F -C.(2,917,406,00) BPUOI: USA00001922 lsft (above Mean Sea Level) Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 2.50 RUNCOM P 16,908.00 RUNCMP SPACE OUT AND LAND 4-1/2"VAMTOP 0930 - 1000 0.50 10'.00 - 13:00 3.00 1300 - 1400 1.00 14:00 - 20:00 6.00 20:00 - 21:00 1.00 21.00 - 00:00 3.00 Printed 4/10/2019 8:47a6AM **All depths reported in Drillers Depths'" COMPLETION - TAG BOTTOM OF PBR AT 10138' MD 2X WITH 5 KLBS - SPACE OUT WITH WLEG -5' INTO PBR - LAND HANGER AND RUN IN LOCK DOWN SCREWS AND TORQUE TOSPEC RUNCOM P 16,908.00 RUNCMP RIG DOWN DOYON CASING AND CLEAR RIG FLOOR RUNCOM P 16,908.00 RUNCMP FREEZE PROTECT IAAND TUBING TO -2100' MD WITH 6.8 PPG DIESEL - REVERSE IN 144 BBLS OF DIESELAT 2.5 BPM, 300 PSI - ALLOW TO U -TUBE FOR 1 HOUR SIMOPS: - LAY DOWN DRILL PIPE WITH OFF-LINE STAND BUILDING EQUIPMENT - EMPTY PITS L -_MAKE UP T -BAR FOR TWC WHSUR P J _ 16,908.00 RUNCMP DRY -ROD IN TWC PER CAMERON REPRESENTATIVE - VERIFY WELL STATIC INSTALL TWC WITH DRY -ROD_ RIGD P 16,908.00 RUNCMP WAIT ON CEMENT TO REACH 1000 PSI COMPRESSIVE STRENGTH PRIOR TO TESTING TWC - CEMENT IN PLACE AT 01:05 ON 03/20/2019 - 1000 PSI COMPRESSIVE STRENGTH AT 42.47 HRS PER SLB UCA SIMOPS: - LAY DOWN DRILL PIPE WITH OFF-LINE STAND BUILDING EQUIPMENT - EMPTY PITS - BLOW DOWN ALL SURFACE LINES - SUCK OUT STACKAND DRIP PANS - RIG DOWN RIG FLOOR LINES - BLOW DOWN PITS - RIG DOWN MUD MODULE INTERCONNECT WBS: RIGD RIGD P 16,908.00 RUNCMP PRESSURE TEST TWO FROM BELOW4000 PSI FOR 5 CHARTED MIN: GOOD TEST - SEE ATTACHED TEST CHART SIMOPS: - LAY DOWN DRILL PIPE WITH OFF-LINE STAND BUILDING EQUIPMENT _ RIGD P 16,90800 RUNCMP NIPPLE DOWN AND RACK BACK BOP STACK - BREAK BOLTS ON ALL FLANGES -PULL AND LAY DOWN RISER - REMOVE HOLE FILL LINES AND TURNBUCKLES - REMOVE CHOKE HOSE AND SET BOP STACK BACK ON STUMP - PULL HIGH PRESSURE RISERS TO RIG FLOOR AND LAY DOWN TO PIPE SHED SIMOPS: - LAY DOWN DRILL PIPE WITH OFF-LINE Printed 4/10/2019 8:47a6AM **All depths reported in Drillers Depths'" Printed 4/10/2019 8:47:16AM "All depths reported in Drillers Depths" North America - ALASKA - BP Page 15 of 15 Operation Summary Report Common Well Name: 16-14 AFE No Event Type: COM- ONSHORE (CON) Start Date. 3/14/2019 End Date. 3/22/2019 X3 -0197F -C: (2,917,406.00 ) Project: PBU Site: i6 Rig Name/No.: PARKER 272 Spud Date/Time. 2/16/2006 12:00.00AM Rig Release: 3/22/2019 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00001922 Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Descrip8on of Operations _ (hr) (usft) 3/22/2019 00:00 - 01:00 1.00 RIGD P 16,908.00 RUNCMP NIPPLE UPADAPTER FLANGE AND DOUBLE MASTER TREE PER CAMERON REPRESENTATIVE SIMOPS: - LAY DOWN DRILL PIPE WITH OFF-LINE STAND BUILDING EQUIPMENT _ 01:00 - 02:30 1.50 RIGD P 16,908.00 RUNCMP PRESSURE TEST ADAPTER FLANGE/ HANGER VOID 4500 PSI FOR 15 CHARTED MIN - SEE ATTACHED TEST CHART -TESTAPPROVED BY BP WSUP 02:30 - 03:30 1.00 RIGD P 16,908.00 RUNCMP PRESSURE TEST DOUBLE MASTER TREE, 4500 PSI 5 MIN LEAK -TIGHT TEST - FILLTREE WITH DIESELAND HEET - TEST TREE TO 4500 PSI FOR 5 MIN: GOOD TEST 03:30 - 05:00 1.50 RIGD P 16,908.00 RUNCMP CLEAN CELLAR AND SECURE TREE RIG RELEASE AT 05:00 HRS ON 03/22/2019 Printed 4/10/2019 8:47:16AM "All depths reported in Drillers Depths" 0 by North America - ALASKA - BP PBU 16 16-14 16-14C 500292057003 Design: 16-14C Final Survey Report 19 April, 2019 ss Company: North America - ALASKA - BP Project: PBU Site: 16 Well: 16-14 Wellbore: 16-14C Design: 16-14C BP Final Survey Report Local Coordinate Reference: Well 16-14 TVD Reference: ACTUAL KB - P272 @ 85.01 usft MD Reference: ACTUAL KB - P272 @ 85.01usft North Reference: True Survey Calculation Method: _ Minimum Curvature Database: EDM RSK - Alaska PROD - ANCP7 Project PBU, PBU, PRUDHOE —7 Map System: Alaska NAD27 State Plane Zones System Datum: Mean Sea Level Geo Datum: NA027 • OGP-Usa AK [4267.15864] _ Using Well Reference Point Map Zone: NAD27.OGP-Usa AK / Alaska zone 4 [26734.1586, Using geodeec scale factor Site 16, TR -10-15 Site Position: Northing: 5,927,441.990 usft Latitude: 70° 12'15.545 N From: Map Easting: 718,969.880 usft Longitude: 148° 14'4.587 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 1.66 ° Well 16-14, 1614 I Well Position +N/ -S 0.00 usft Northing: 5,929,396.430 usft Latitude: 70° 12' 34.664 N +E/ -W 0.00 usft Easting: 719,306.300 usft Longitude: 148° 13'53.161 W Position Uncertainty 0.00 usft Wellhead Elevation: 37.73 usft Ground Level: 37.33 usft Wellbore 16-14C Magnetics Model Name Sample Data Declination Dip Angle Field Strength (nT) OGGM1999 12/31/2000 27.17 8072 57,359 Design 16-14C - - - - Audit Notes: Version: Phase: ACTUAL Tie On Depth: 7,491.78 Vertical Section: Depth From (TVD) +N/$ +E/ -W Direction (usft) (usft) (weft) (I 45.20 0.00 0.00 334.93 41192019 3:34:07PM Page 2 COMPASS 5000.1 Build 81D BP Final Survey Report Company: North America -ALASKA - BP Local Coordinate Reference: Well 16-14 Project. PBU TVD Reference: ACTUAL KB - P272 @ 85.01 usft Site: 16 MD Reference: ACTUAL KB - P272 @ 85.01 usft Well: 16-14 North Reference: True Wellbore' 16-14C Survey Calculation Method: Minimum Curvature Design: 16-14C Database: EDM R5K - Alaska PROD - ANCP1 Survey Program Date 4/19/2019 - - From To (usft) (usft) Survey (Wellbore) Tool Name Description 118.91 7,491.78 16-14 GyroData (16-14) GYD-CT-CMS Gyrodata cont casing m/s 7,499.00 7,652.7B Survey#1 (16-14C) BLIND Blind drilling 7,685.52 10,249.29 Survey#2(16-14C) MWD+IFR+MS-WOCA MWD +IFR+Multi Station W/O Crustal 10,301.28 16,908.00 Survey#3(16-14C) MWD+IFR+MS-WOCA MWD + IFR +Multi Station W/O Crustal Survey MD Inc Azi TVD TVDSS NIS PJW Northing Easting DLeg V. Sec (usft) (°) (') (usft) (usft) (usft) (usft) (usft) (usft) (°I100usft) (usft) 47.28 0.00 0.00 4728 -37.73 0.00 0.00 5,929,396.430 719,306.300 0.00 0.00 118.86 0.06 193.94 118.66 33.85 -0.04 -0.01 5,929,396.393 719,306.292 0.08 -0.03 218.86 0.12 228.37 218.86 133.85 -0.16 -0.10 5,929,396.270 719,308.205 0.08 -0.10 318.86 0.12 202.99 318.86 233.85 -0.32 -0.22 5,929,396.101 719,306.090 0.05 -0.20 418.86 0.24 195.77 418.86 333.85 -0.62 -0.32 5,929,395.800 719,306.001 0.12 -0.43 518.86 0.31 203.40 518.86 433.85 -1.07 -0.48 5,929,395.346 719,305.850 0.08 -0.77 618.86 0.30 272.76 618.86 533.85 -1.31 -0.85 5,929,395.100 719,305.488 0.35 -082 718.86 0.49 258.43 718.85 633.84 -1.38 -1.53 5,929,395.007 719,304.810 0.21 -060 818.86 0.54 241.67 818.85 733.84 -1.69 -2.36 5,929,394.673 719,303.986 0.16 -0.53 918.86 0.49 244.70 918.85 833.84 -2.10 -3.17 5,929,394.244 719,303.197 0.06 -0.56 1,018.86 0.40 255.44 1,018.84 933.83 -2.37 -3.89 5,929,393.953 719,302.480 0.12 -0.49 1,118.86 0.32 262.19 1,118.84 1,033.83 -2.49 4.50 5,929,393.809 719,301.870 0.09 -0.35 1,218.86 0.32 243.41 1,218.84 1,133.83 -2.65 -5.03 5,929,393.631 719,301.348 0.10 -0.27 1,318.86 0.48 189.88 1,318.84 1,233.83 -3.19 -5.35 5,929,393.084 719,301.043 0.39 -0.82 1,418.86 0.49 182.98 1,416.83 1,333.82 4.03 -5.45 5,929,392.242 719,300.973 0.06 -1,34 1,518.86 0.59 200.28 1,518.83 1,433.82 4.94 -5.65 5,929,391.327 719,300.799 0.19 -2.08 1,618.86 0.59 202.36 1,618.82 1,533.81 -5.90 -6.02 5,929,390.357 719,300.452 0.02 -2.79 1,718.86 0.62 191.56 1,718.82 1,633.81 -6.91 -6.33 5,929,389.343 719,300.178 0.12 -3.58 1,818.86 0.63 168.53 1,818.81 1,733.80 -7.96 -6.33 5,929,388.274 719,300.209 0.25 4.54 1,918.86 0.79 161.04 1,918.81 1,833.80 -9.17 -5.99 5,929,387.094 719,300.577 0.18 -5.76 4/192019 3:34 07P Page 3 COMPASS 5000.1 Build BID bp Final BP Survey Report Company: North America - ALASKA - BP Local Co-ordinate Reference: Well 16-14 Pro)ect: Pau TVD Reference: ACTUAL KB - P272 @ 85.01usft Site: 16 MD Reference: ACTUAL KB - P272 @ 85.01 usft Well 16-14 North Reference: True Wellbore: 16-14C Survey Calculation Method Minimum Curvature Design: 16-14C Database: EDM R5K - Alaska PROD - ANCP1 Survey MD Inc Azi TVD TVDSS NIS EM/ Northing Easting DLeg (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (°/100usft) 2,018.86 0.96 128.86 2,018.79 1,933.78 -10.34 -5.12 5,929,385.942 719,301487 0.51 2,118.86 0.74 132.00 2,118.78 2,033.77 -11.30 -3.98 5,929,385.018 719,302.647 0.22 2,216.86 1.15 148.52 2,218.77 2,133.76 -12.59 -2.88 5,929,383.760 719,303.688 0.49 2,318.86 1.24 145.62 2,318.75 2,233.74 -14.34 -1.84 5,929,382.045 719,304.873 0.11 2,418.86 1.22 147.07 2,418.72 2,333.71 -16.13 -0.65 5,929,380.294 719,306.114 0.04 2,518.86 1.29 138.01 2,518.70 2,433.69 -17.86 0.88 5,929,378.603 719,307.495 0.21 2,618.86 1.46 134,52 2,618.67 2,533.66 -19.59 2.34 5,929,376.922 719,309.206 0.19 2,718.86 1.42 135.84 2,718.64 2,633.63 -21.37 4.11 5,929,375.192 719,311.029 0.05 2,818.86 1.48 139.17 2,818.61 2,733.60 -23.23 5.82 5,929,373.377 719,312.790 0.10 2,918.86 1.62 141.51 2,918.57 2,833.56 -25.32 7.54 5,929,371.344 719,314.573 0.15 3,018.86 1.74 143.38 3,018.53 2,933.52 -27.64 9.33 5,929,369.072 719,316.425 0.13 3,118.86 2.03 147.53 3118.47 3,033.46 -30.35 11.18 5,929,366.414 719,318.360 0.32 3,218.86 2.09 149.06 3,216.41 3,133.40 -33.41 13.07 5,929,363.412 719,320.336 0.08 3,318.86 2.03 152.06 3,31815 3,233.34 -36.54 14.84 5,929,360337 719,322.194 0.12 3,418.86 1.39 150.93 3,418.30 3,333.29 -39.17 16.26 5,929,357.754 719,323.688 0.64 3,518.86 1.35 148.17 3,518.27 3,433.26 41.23 17.47 5,929,355.729 719,324.958 0.08 3,618.86 0.82 158.89 3,618.25 3,533.24 -42.90 18.35 5,929,354.087 719,325.885 0.57 3,718.86 0.81 159.64 3,718.24 3,633.23 -44.23 18.85 5,929,352.772 719,326.427 0.01 3,818.86 0.74 164A0 3,818.23 3,733.22 -45.51 19.27 5,929,351.501 719,326.887 0.09 3,918.86 0.70 151.23 3,918.23 3,833.22 46.67 19.75 5,929,350.359 719,327.391 0.17 4,018.86 2.10 20.02 4,018.21 3,933.20 45.48 20.67 5,929,351.572 719,328.278 2.61 4,118.86 5.44 7.68 4,117.98 4,032.97 -39.06 21.93 5,929,358.026 719,329.352 3.42 4,218.86 9.11 1.37 4,217.16 4,132.15 -26.44 22.75 5,929,370.661 719,329.808 3.75 4,318.86 12.29 7.87 4,315.41 4,230.40 -7.98 24.40 5,929,389.162 719,330.918 3.40 4,343.86 13.12 11.56 4,339.80 4,254.79 -2.56 25.33 5,929,394.603 719,331.694 4.64 4,368.86 13.95 13.70 4,364.10 4,279.09 3.14 26.61 5,929,400.345 719,332.810 3.88 4,393.86 14.73 15.08 4,388.32 4,303.31 9.14 28.15 5,929,406.383 719,334.175 3.41 V. Sec (usft) -7,2C -8.55 -10.14 -1221 -14.33 -16.46 -18,73 -21.10 -23.51 -26.13 -28.99 -32.23 -3580 -39 39 -42.37 -44.7f -46.63 -48.05 -49.39 -50.64 -49.95 -44.67 -33.59 -17.57 -13.06 -8.43 -3.65 4/1912019 3:34:07PM Page 4 COMPASS 5000.1 Build 81D 1#2 BP Final Survey Report Company: North America - ALASKA - BP Local Coordinate Reference: Well 16-14 Project: PBU TVD Reference: ACTUAL KB - P272 a 85.01 usft Site: 16 MD Reference: ACTUAL KB - P272 Q 85.01 usft Well: 16-14 North Reference: True Wellbore: 16-14C Survey Calculation Method: Minimum Curvature Design: 16-14C Database: EDM R5K - Alaska PROD - ANCP1 Survey MD Inc Azi TVD TVDSS NIS E/W Northing Easting DLeg (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (°HOOusft) 4,418.66 15.59 13.36 4,41245 4,327.44 15.48 29.76 5,929,412.765 719,335.594 3.88 4,443.86 16.00 11.23 4,436.51 4,351.50 22.13 31.20 5,929,419.452 719,336.847 2.84 4,468.86 16.78 11.14 4,460.49 4,375.48 29.05 32.57 5,929,426.408 719,338.014 3.12 4,493.86 17.31 10.84 4,484.40 4,399.39 36.24 33.97 5,929,433.639 719,339.201 2.15 4,518.86 17.70 11.45 4,508.24 4,423.23 43.62 35.42 5,929,441.056 719,340.440 1.72 4,543.86 18.35 11.96 4,532.01 4,447.00 51.19 36.99 5,929,448.672 719,341.789 2.68 4,566.86 18.71 12.32 4,555.71 4,470.70 58.96 38.66 5,929,456.485 719,343.234 1.51 4,593.86 19.34 12.12 4,579.35 4,494.34 66.92 40.39 5,929,464.496 719,344.727 2.53 4,618.86 19.80 12.95 4,602.90 4,517.89 75.10 42.21 5,929,472.719 719,346.306 2.15 4,643.86 20.50 13.90 4,626.37 4,541.36 83.47 44.21 5,929,481.149 719,348.063 3.09 4,668.86 20.84 13.35 4,649.77 4,564.76 92.05 46.29 5,929,489.782 719,349.891 1.57 4,693.86 21.67 14.65 4,673.06 4,588.05 100.84 48.48 5,929,498.834 719,351.829 3.82 4,718.86 22.28 15.19 4,696.26 4,611.24 109.88 50.89 5,929,507.739 719,353.975 2.57 4,743.86 23.02 16.11 4,718.32 4,634.31 119.15 53.49 5,929,517,080 719,356.302 3.28 4,768.86 23.96 16.96 4,742.25 4,657.24 128.70 56.32 5,929,526.710 719,358.861 4.00 4,793.86 24.75 17.54 4,765.02 4,680.01 136.55 59.38 5,929,536.640 719,361.632 3.30 4,818.86 25.67 18.19 4,787.64 4,702.63 148.68 62.85 5,929,546.864 719,364.603 3.84 4,843.86 26.38 18.35 4,810.11 4,725.10 159.10 66.09 5,929,557.375 719,367.738 2.85 4,868.86 27.08 18.96 4,832.44 4,747.43 169.75 69.69 5,929,568.128 719,371.024 3.01 4,893.86 27.81 19.96 4,854.62 4,769.61 180.62 73.53 5,929,579.098 719,374.547 3.45 4,918.86 28.84 21.15 4,876.63 4,791.62 191.72 77.69 5,929,590.319 719,378.389 4.70 4,943.86 29.78 21.20 4,898.43 4,813.42 203.13 82.11 5,929,601.854 719,382.476 3.76 4,968.86 30.74 22.48 4,920.02 4,835.01 214.83 86.80 5,929,613.677 719,386.823 4.63 4,993.86 31.49 22.75 4,941.42 4,856.41 226.75 91.77 5,929,625.741 719,391.442 3.05 5,018.86 Mali 23.51 4,962.69 4,877.68 238.84 96.93 5,929,637.974 719,396.253 2.47 5,043.86 32.82 23.91 4,983.80 4,898.79 251.10 102.32 5,929,650.386 719,401.280 3.55 5,068.86 33.10 23.95 5,004.78 4,919.77 263.53 107.84 5,929,662.973 719,406.433 1.12 V. Sec (usft) 141 6.82 12.51 18.43 24.50 3069 37.02 4351 5014 5688 63.77 70.80 77.97 85.26 92.71 100.31 108.13 116 11 124.23 132.45 140.74 14920 157 81 166.50 175.27 184.09 193.01 4/192019 3.34:07PM Page 5 COMPASS 5000.1 Build BID BP Final Survey Report Company: North America - ALASKA- BP Local Coordinate Reference: Well 16-14 Project: PBU TVD Reference: ACTUAL K8 - P272 @ 85.07 usft Site: 16 MD Reference: ACTUAL KB - P272 @ 85.01 usft Well 16-14 North Reference: True Wellbore: 16-14C Survey Calculation Method: Minimum Curvature Design: 16-14C Database: EDM R5K - Alaska PROD - ANCP1 Survey MD Inc Azi TVD TVDSS NIS EIW Northing Easting DLeg V. Sec (usft) V) (°) (usft) (usft) (usft) (usft) (usft) (usft) (Wousft) (usft) 5,093.86 33.61 24.63 5,025.66 4,940.65 276.06 113.49 5,929,675.660 719,411.722 2.53 201.97 5,118.86 34.03 25.01 5,046.43 4,961.42 288.69 119.33 5,929,688.453 719,417.193 1.88 210.93 5,143.86 34.28 24.94 5,067.12 4,982.11 301.42 125.26 5,929,701.342 719,422.747 1.01 219.94 5,168.86 34.41 25.23 5,087.76 5,002.75 314.19 131.24 5,929,714.284 719,428.353 0.84 228.98 5,193.86 34.55 25.38 5,108.36 5,023.35 326.98 137.29 5,929,727.248 719,434.028 0.65 238.01 5,218.86 34.86 25.15 5,128.92 5,043.91 339.86 143.36 5,929,740.291 719,439.727 1.35 247.09 5,243.86 34.50 25.00 5,149.48 5,064.47 352.74 149.39 5,929,753.344 719,445.378 1.48 256.21 5,268.86 34.79 25.03 5,170.04 5,085.03 365.62 155.40 5,929,766.392 719,451.011 1.16 265.33 5,293.86 34.48 25.03 5,190.61 5,105.60 378.49 161.41 5,929,779.435 719,456.646 1.24 27444 5,318.86 34.60 25,29 5,211.21 5,126.20 391.32 167.44 5,929,792.433 719,462.297 0.76 283.51 5,343.86 34.65 25.25 5,231.78 5,146.77 404.17 173.50 5,929,805.449 719,467.985 0.22 292.58 5,368.86 34.63 25.26 5,252.35 5,167.34 417.02 179.57 5,929,818.471 719,473.672 0.08 30165 5,393.86 34.61 25.28 5,272.92 5,187.91 429.87 185.63 5,929,831.485 719,479.359 0.09 310.71 5,418.86 34.46 25.27 5,293.51 5,208.50 442.68 191.68 5,929;844.471 719,485.035 0.60 319.76 5,443.86 34.09 25.22 5,314.17 5,229.16 455.42 197.89 5,929,857.374 719,490.667 1.48 328.75 5,468.86 34.16 25.60 5,334.87 5,249.66 468.08 203.70 5,929,870.211 719,496.315 0.90 337.67 5,493.86 34.52 25.37 5,355.51 5,270.50 480.81 209.77 5,929,883.112 719,502.010 1.53 346.63 5,518.86 34.25 25.51 5,376.14 5,291.13 493.56 215.84 5,929,896.032 719,507.702 1.13 355.61 5,543.86 33.89 25.55 5,396.85 5,311.84 506.20 221.87 5,929,908.839 719,513.368 1.44 364.50 5,568.86 33.89 25.92 5,417.60 5,332.59 518.76 227.92 5,929,921.566 719,519.053 0.83 373.31 5,593.86 34.06 26.10 5,438.34 5,353.33 531.31 234.05 5,929,934.294 719,524.812 0.79 362.09 5,618.86 34.02 25.79 5,459.05 5,374.04 543.90 240.17 5,929,947.049 719,530.567 0.71 390.89 5,643.86 33.90 25.80 5,479.79 5,394.78 556.47 246.25 5,929,959.794 719,536.276 0.48 39970 5,668.86 33.80 25.79 5,500.55 5,415.54 569.01 252.31 5,929,972.502 719,541.969 0.40 40849 5,693.86 34.02 26.11 5,521.30 5,436.29 581.55 258.41 5,929,985.214 719,547.705 1.13 417.27 5,718.86 34.19 26.03 5,542.00 5,456.99 594.14 264.57 5,929,997.979 719,553.497 0.70 426.06 5,743.86 34.35 26.05 5,562.66 5,477.65 606.79 270.75 5,930,010.801 719,559.306 0.64 434.90 4119/2019 3.34:07PM Page 6 COMPASS 5000.1 Build BID BP by Final Survey Report Company: North America - ALASKA - BP Local Coordinate Reference: Well 16-14 Project: PBU TVD Reference: ACTUAL KB- P272 85.01 usft Site: 16 MD Reference: ACTUAL KB- P272 (rD 85.01 usft Well: 16-14 North Reference: True Wellbore: 16-14C Survey Calculation Method: Minimum Curvature Design: 16-14C Database: EDM R5K - Alaska PROD - ANCP1 Survey MD Inc Azi TVD TVDSS NIS ENV Northing Easgng DLeg V. Sec (usft) N (") (usft) (usft) (usft) (usft) (usft) (usft) ('1100usft) (usft) 5,768.86 34.64 26.13 5,583.26 5,498.25 619.51 276.98 5,930,023.691 719,565.161 1.17 443.7P 5,793.86 34.81 26.13 5,603.81 5,518.80 632.29 283.25 5,930,036.653 719,571.058 0.68 452.70 5,818.86 34.93 26.19 5,624.32 5,539.31 645.12 289.55 5,930,049.659 719,576.984 0.50 461.65 5,843.86 34.95 26.34 5,644.82 5,559.81 657.96 295.89 5,930,062.676 719,582.945 0.35 470.60 5,868.86 34.93 26.25 5,665.31 5,580.30 670.80 302.23 5,930,075.691 719,588.912 0.22 479.54 5,893.88 35.18 26.40 5,685.77 5,60076 683.67 308.60 5,930,088.740 719,594.903 1.06 488.50 5,918.86 35.31 26.27 5,706.19 5,621.18 696.60 315.00 5,930,101.849 719,600.924 0.60 497.50 5,943.66 35.73 26.53 5,726.54 5,641.53 709.61 321.46 5,930,115.040 719,607.002 1.79 506.54 5,968.86 36.05 26.56 5,746.79 5,661.78 722.72 328.01 5,930,128.335 719,613.167 1.28 515.65 5,993.86 36.32 26.74 5,766.97 5,681.96 735.91 334.63 5,930,141.713 719,619.402 1.16 524.79 6,018.86 36.68 26.83 5,787.07 5,702.06 749.18 341.33 5,930,155.177 719,625.714 1.46 533.97 6,043.86 36.99 27.03 5,807.08 5,722.07 762.55 348.12 5,930,168.730 719,632.111 1.33 543.20 6,068.86 37.19 27.04 5,827.02 5,742.01 775.96 354.97 5,930,182.352 719,638.571 0.80 552.46 6,093.86 37.53 27.50 5,846.89 5,761.88 789.46 361.92 5,930,196.032 719,645.127 1.76 561.73 6,118.86 38.03 27.56 5,866.65 5,781.64 803.04 369.00 5,930,209.812 719,651.609 2.01 571.03 6,143.86 38.37 27.61 5,886,29 5,801.28 816.74 376.16 5,930,223.717 719,658.566 1.37 580A4 6,168.86 38.66 27.71 5,905.86 5,820.85 830.53 383.39 5,930,237.709 719,665.390 1.19 589.84 6,193.86 38.58 27.86 5,925.39 5,840.38 844.34 390.66 5,930,251.718 719,672.259 0.49 599.26 6,218.86 38.79 27.98 5,944.90 5,859.89 858.14 397.98 5,930,265.732 719,679.171 0.89 608.67 6,243.86 38.95 28.04 5,964.37 5,879.36 872.00 405.35 5,930,279.790 719,686.134 0.66 618.09 6,268.86 39.25 28.06 5,983.77 5,898.76 885.91 412.76 5,930,293.914 719,693.140 1.20 627.55 6,293.86 39.48 28.12 6,003.10 5,910.09 899.90 420.23 5,930,308.113 719,700.197 0.93 637.06 6,318.86 39.52 28.33 6,022.39 5,937.38 913.91 427.75 5,930,322.336 719,707.307 0.56 646.56 6,343.86 39.74 28.37 6,041.64 5,956.63 927.94 435.32 5,930,336.582 719,714.468 0.89 656.07 6,368.86 39.99 28.31 6,060.83 5,975.82 942.05 442.93 5,930,350.901 719,721.662 1.01 665.62 6,393.86 40.45 28.64 6,079.92 5,994.91 956.24 450.62 5,930,365.308 719,728.943 2.03 675.21 6,418.86 40.62 28.89 6,098.92 6,013.91 970.48 458.44 5,930,379.771 719,736.344 0.94 684.80 411912019 3:34: 07PM Page 7 COMPASS 5000.1 Build 61D ee BP Final Survey Report Company: North America - ALASKA - BP Local Co-ordinate Reference: Well 16-14 Project: PBU TVD Reference: ACTUAL KB - P272 @ 85.01 usft Site: 16 MD Reference: ACTUAL KB- P272 @ 85.01 usft Well: 16-14 North Reference: True Waltham: 16-14C Survey Calculation Method: Minimum Curvature Design: 16-14C Database: EDM R5K - Alaska PROD - ANCP1 Survey MD Inc Azi TVD TVDSS N/S E/W Northing Easting DLeg V. Sec (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) ("/100usft) (usft) 6,443.86 40.99 28.95 6,117.84 6,032.83 984.78 466.34 5,930,394.293 719,743.826 1.49 694.40 6,468.86 41.33 29.04 6,136.67 6,051.66 999.17 474.32 5,930,408.910 719,751.380 1.38 704.06 6,493.86 41.41 29.31 6,155.43 6,070.42 1,013.60 482.37 5,930,423.564 719,759.012 0.78 713.72 6,518.86 41.50 29.55 6,174.16 6,089.15 1,028.01 490.50 5,930,438.208 719,766.722 0.73 723.33 6,543.86 41.71 29.89 6,192.86 6,107.85 1,042.43 498.73 5,930,452.857 719,774.529 1.23 73290 6,568.86 41.94 29.89 6,211.49 6,126.48 1,056.88 507.04 5,930,467.545 719,782.413 0.92 742.47 6,593.86 42.33 29.94 6,230.03 6,145.02 1,071.42 515.41 5,930,482.318 719,790.352 1.57 75209 6,618.86 42.55 29.99 6,248.48 8,163.47 1,086.04 523.83 5,930,497.172 719,798.350 0.89 761.76 6,643.86 42.49 30.14 6,266.90 6,181.89 1,100.66 532.30 5,930,512.034 719,806.386 0.47 77142 6,668.86 42.72 30.01 6,285.30 6,200.29 1,115.30 540.78 5,930,526.918 719,814.437 0.99 781.09 6,693.86 42.77 30.02 6,303.66 6,218.65 1,130.00 549.27 5,930,541.851 719,822.495 0.20 790.80 6,718.86 42.78 29.33 6,322.01 6,237.00 1,144.75 557.67 5,930,556.839 719,830.468 1.87 800.60 6,743.86 42.27 27.57 6,340.44 6,25543 1,159.60 565.72 5,930,571.921 719,838.083 5.18 810.65 6,768.86 41.99 25.45 6,358.98 6,273.97 1,174.61 573.21 5,930,587.136 719,845.129 5.80 821.07 6,793.86 41.86 23.93 6,377.58 6,292.57 1,189.78 580.19 5,930,602.508 719,851.662 4.10 831.86 6,818.86 41.69 22.79 6,396.23 6,311.22 1,205.07 586.79 5,930,617.982 719,857.819 3.11 842.91 6,843.86 41.69 22.45 6,414.89 6,329.88 1,220.42 593.18 5,930,633.509 719,863.766 0.90 854.10 6,868.86 41.66 22.46 6,433.57 6,348.56 1,235.78 599.53 5,930,649.048 719,869.666 0.12 865.32 6,893.86 41.72 22.49 6,452.24 6,367.23 1,251.15 605.89 5,930,664.590 719,875.573 0.25 876.55 6,918.86 41.64 22.47 6,470.91 6,385.90 1,268.51 612.25 5,930,680.129 719,881.480 0.32 88777 6,943.86 41.58 22.43 6,489.60 6,404.59 1,281.85 618.59 5,930,695.649 719,887.371 0.26 898.98 6,968.86 4158 22.34 6,508.30 6,423.29 1,297.19 624.90 5,930,711.166 719,893.242 0.24 910.20 6,993.86 41.51 22.22 6,527.01 6,442.00 1,312.54 631.19 5,930,726.684 719,899.079 0.42 92143 7,01111 41.51 22.18 6,545.73 6,460.72 1,327.88 637.45 5,930,742.199 719,904.891 0.11 932.68 7,043.86 41.20 22.08 6,564.50 6,479.49 1,343.18 643.67 5,930,757.674 719,910.666 1.27 943.90 7,068.86 41.26 22.08 6,583.30 6,498.29 1,358.45 649.87 5,930,773.115 719,916.414 0.24 955.10 7,093.86 41.51 22.06 6,602.06 6,517.05 1,373.76 656.08 5,930,788.605 719,922.176 1.00 986.35 4/192019 3:34:07PM Page 8 COMPASS 5000.1 Build 810 by Company: North Amerim- ALASKA -BP Project: PBU Site: 16 Well: 16-14 Reference: Wellbore: 16-14C Well 16-14 Design: 16-14C Survey MD Inc (usft) 7,116.86 41.52 7,143.86 41.33 7,168.86 40.97 7,193.86 40.76 7,218.86 40.77 7,243.86 40.80 7,268.86 40.91 7,293.86 40.99 7,318.86 40.78 7,343.86 40.65 7,368.86 40.79 7,393.86 40.50 7,418.86 40.57 7,443.86 40.34 7,468.86 40.27 7,491.78 40.33 Tie -in -point 7,499.00 40.26 KOP - Top of Whipstock Minimum Curvature 7,528.29 41.15 Interpolated Azimuth 7,558.53 42.31 Interpolated Azimuth 7,591.16 45.01 Interpolated Azimuth EDM R5K - Alaska PROD - ANCP1 7,622.55 47.83 Interpolated Azimuth BP Final Survey Report 4/19/2019 134: 07PM Page 9 COMPASS 5000.1 Build 81O Local Co-ordinate Reference: Well 16-14 TVD Reference: ACTUAL KB - P272 @ 85.01usft MD Reference: ACTUAL KB - P272 @ 85.01 usft North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM R5K - Alaska PROD - ANCP1 Azi TVD TVDSS NIS ENV Northing Easting DLeg V. Sec (°) (USR) (usft) (usft) (usft) (usft) (usft) (°/100usft) (usft) 22.02 6,620.78 6,535.77 1,389.12 662.30 5,930,804.138 719,927.945 0.11 977.62 21.97 6,639.52 6,554.51 1,404.46 668.49 5,930,819.648 719,933.692 0.77 988.89 21.81 6,658.35 6,573.34 1,419.73 674.62 5,930,835.084 719,939.379 1.50 1,000.12 21.76 6,677.25 6,592.24 1,434.91 680.69 5,930,850.442 719,945.006 0.85 1,011.30 21.88 6,696.19 6,611.18 1,450.07 686.76 5,930,865.765 719,950.630 0.32 1,02246 21.80 6,715.12 6,630.11 1,465.23 692.84 5,930,881.093 719,956.263 0.24 1,033.62 21.74 6,734.03 6,649.02 1,480.41 698.90 5,930,896.449 719,961.884 0.47 1,044.80 21.71 6,752.91 6,667.90 1,495.84 704.97 5,930,911.840 719,967.504 0.33 1,056.02 21.60 6,771.81 6,686.80 1,510.84 711.01 5,930,927.217 719,973.098 0.89 1,067.24 21.50 6,790.76 6,705.75 1,526.01 717.00 5,930,942.551 719,978.645 0.58 1,078.44 21.49 6,809.71 6,724.70 1,541.19 722.97 5,930,957.892 719,984.177 0.56 1,089.65 21.41 6,828.67 6,743.66 1,556.34 728.93 5,930,973.214 719,989.689 1.18 1,100.86 21.40 6,847.68 8,762.67 1,571.47 734.86 5,930,988:507 719,995.177 0.28 1,112.05 21.40 6,866.70 6,781.69 1,586.57 740.78 5,931,003.774 720,000.654 0.92 1,123.22 21.36 6,885.76 6,80075 1,601.63 746.67 5,931,018:997 720,006.110 0.30 1,134.36 21.23 6,903.24 6,818.23 1,615.44 752.05 5,931,032.958 720,011.090 0.43 1,144.59 21.21 6,908.75 6,823.74 1,619.80 753.74 5,931,037.358 720,012.653 0.92 1,147.82 20.00 6,930.96 6,845.95 1,637.68 760.46 5,931,055.424 720,018.851 4.06 1,161.16 18.00 6,953.52 6,868.51 1,656.71 767.01 5,931,074.636 720,024.843 5.84 1,175.63 15.50 6,977.13 6,892.12 1,678.28 773.49 5,931,096.384 720,030.693 9.82 1,19242 13.90 6,998.77 6,913.76 1,700.27 779.25 5,931,118.534 720,035.814 9.71 1,209.90 4/19/2019 134: 07PM Page 9 COMPASS 5000.1 Build 81O BP Final Survey Report Company: North America -ALASKA - BP Local Coordinate Reference: Well 16-14 Project: PBU TVD Reference: ACTUAL KB - P272 @ 85.01 usft Site: 16 MD Reference: ACTUAL KB- P272 @ 85.01 usft Well: 16-14 North Reference: True Wellbore: 16-14C Survey Calculation Method: Minimum Curvature Design: 16-14C Database: EDM R5K - Alaska PROD - ANCPI Survey MD Inc Azi TVD TVDSS NIS E/W Northing Easting DLeg V. Sec (usft) C) (°) (usft) (usft) (usft) (usft) (usft) (usft) (°/100usft) (usft) 7,652.78 4949 1060 7,018.74 6,933.73 172244 784.06 5,931,140.838 720,039.974 9.86 1,227.95 Interpolated Azimuth 7,685.52 49.33 9.57 7,040.04 6,955.03 1,746.92 788.41 5,931,165.431 720,043.615 2.44 1,248.27 First Clean Survey 7,717.09 49.17 7.82 7,060.65 6,975.64 1,770.56 792.03 5,931,189.165 720,046.542 4.23 1,268.15 7,748.17 49.13 7,85 7,080.98 6,995.97 1,793.85 795.23 5,931,212.537 720,049.069 0.15 1,287.89 7,779.52 48.83 7.03 7,101.53 7,016.52 1,817.32 798.30 5,931,236.086 720,051.451 2.08 1,307.85 7,812.05 48.85 7.71 7,122.92 7,037.91 1,841.63 801.44 5,931,260.473 720,053.888 1.59 1,328.54 7,904.47 48.01 7.29 7,184.24 7,099.23 1,910.18 810.47 5,931,329.254 720,060.920 0.97 1,386.81 7,998.78 47.98 7.14 7,247.36 7,162.35 1,979.71 819.27 5,931,399.003 720,067.698 0.12 1,446.05 8,093.38 49.14 6.24 7,309.97 7,224.96 2,050.14 827.53 5,931,469.642 720,073.905 1.42 1,506.35 8,188.02 49.94 4.76 7,371.38 7,286.37 2,121.81 834.42 5,931,541.481 720,078.716 1.46 1,568.35 8,282.33 51.23 2.28 7,431.27 7,346.26 2,194.52 838.88 5,931,614.289 720,081.061 2.45 1,632.32 8,377.22 51.17 0.93 7,490.73 7,405.72 2,268.44 840.95 5,931,688.234 720,080.985 1.11 1,698.40 8,471.78 51.94 359.78 7,549.52 7,464.51 2,342.50 84141 5,931,762.268 720,079.289 1.25 1,765.29 8,566.60 51.96 359.08 7,607.96 7,522.95 2,417.16 840.67 5,931,836.875 720,076.378 0.58 1,833.23 8,661.28 52.67 358.09 7,665.64 7,580.83 2,492.06 838.81 5,931,911.690 720,072.350 1.12 1,90186 8,755.13 52.62 358.64 7,722.79 7,637.78 2,566.63 836.68 5,931,986.163 720,068.057 0.47 1,970.31 8,850.00 52.65 358.34 7,780.36 7,695.35 2,642.01 834.70 5,932,061.445 720,063.882 0.25 2,03943 8,944.42 52.61 358.01 7,837.67 7,752.66 2,717.01 832.31 5,932,136.341 720,059.316 0.28 2,108.37 9,039.29 52.22 358.07 7,895.54 7,810.53 2,792.15 829.74 5,932,211.367 720,054.563 0.41 2,177.52 9,133.53 49.64 357.79 7,954.93 7,869.92 2,865.26 827.10 5,932,284.368 720,049.802 2.75 2,244.86 9,228.62 48.01 355.03 8,017.54 7,932.53 2,936.68 822.64 5,932,355.625 720,043.271 2.78 2,311.44 9,324.35 46.07 352.28 8,082.79 7,997.78 3,006.30 814.92 5,932,424.991 720,033.537 2.92 2,37778 9,418.74 44.35 349.86 8,149.28 8,064.27 3,072.46 804.55 5,932,490.819 720,021.246 2.58 2,442.10 9,513.50 42.42 347.88 8,218.15 8,133.14 3,136.32 792.00 5,932,554.285 720,006.855 2.49 2,505.26 9,608.33 40.15 343.87 8,289.41 8,204.40 3,196.98 776.79 5,932,614.474 719,989.886 3.66 2,566.65 4/192019 3:34 07P Page 10 COMPASS 5000.1 Build BID BP bp Final Survey Report Company: North America -ALASKA - BP Local Coordinate Reference: Well 16-14 Project: PBU TVD Reference: ACTUAL KB- P272 @ 85.01 usft Site: 16 MD Reference: ACTUAL KB- P272 @ 85.01 usft Well: 16-14 North Reference: True Wellbore: 16-14C Survey Calculation Method: Minimum Curvature Design: 16-14C Database: EDM R5K - Alaska PROD - ANCP1 Survey MD Inc Azi TVD TVDSS NIS E1W Northing Easting DLeg V. Sec (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (°1100uaft) (usft) 9,702.85 38.47 341.49 8,362.55 8,277.54 3,254.14 758.99 5,932,671.091 719,970.433 2.39 2,625.97 9,796.71 38.12 337.70 8,436.22 8,351.21 3,308.64 738.72 5,932,724.974 719,948.595 2.53 2,683.92 9,890.70 36.02 333.79 8,511.22 6,426.21 3,360.28 715.50 5,932,775.924 719,923.886 3.36 2,740.54 9,984.37 34.86 329.84 8,587.55 8,502.54 3,408.15 689.89 5,932,823.021 719,896.890 2.74 2,79475 10,078.62 35.54 325.34 6,664.58 8,579.57 3,453.98 660.77 5,932,867.983 719,866.456 2.84 2,848.60 10,172.41 35,54 325.22 8,740.89 8,655.88 3,498.79 629.72 5,932,911.871 719,834.118 0.07 2,902.34 10,249.29 35.68 324.95 8,803.40 8,716.39 3,535.49 604.10 5,932,947.616 719,807.443 0.27 2,946.45. 10,301.28 36.63 325.44 8,845.38 8,760.37 3,560.68 586.59 5,932,972.482 719,789.213 1.91 2,976.681 10,334.85 40.24 327.02 8,871.67 8,786.66 3,578.03 575.00 5,932,989.487 719,777.128 11.14 2,997.30 10,366.03 44.40 326.89 8,894.72 8,809.71 3,595.62 563.56 5,933,006.739 719,765.177 13.34 3,018.09 10,398.21 48.20 324.25 8,918.95 8,831.94 3,614.60 550.39 5,933,025.520 719,751.462 13.21 3,041.03 10,428.87 50.34 325.00 8,936.95 8,851.94 3,633.74 536.95 5,933,044.066 719,737.471 7.22 3,063.89 10,460.53 52.34 326.70 8,956.73 8,871.72 3,654.20 523.07 5,933,084.113 719,723.011 7.58 3,088.30 10,492.12 54.89 326.95 8,975.47 8,89046 3,67548 509,16 5,933,084.984 719,708.485 8.10 3,11348 10,523.48 57.89 327.96 8,992.83 8,907.82 3,697.50 495.12 5,933,106.581 719,693.808 9.94 3,139.37 10,554.97 61.27 329.65 9,008.77 8,923.76 3,720.73 481.06 5,933,129.390 719,679,083 11.69 3,166.3E 10,586.79 66.00 330.82 9,022.90 8,937.89 3,745.47 466.92 5,933,153.712 719,664.227 15.23 3,194.77 10,617.72 69.81 329.79 9,034.53 8,949.52 3,770.36 452.72 5,933,178.176 719,649.314 12.70 3,223.33 10,650.38 73.54 328.78 9,044.79 8,959.78 3,797.01 436.88 5,933,204.351 719,632.712 11.79 3,254.18 10,680.65 77.03 327.24 9,052.48 8,967.47 3,821.83 421.37 5,933,228.714 719,616.489 12.54 3,283.23 10,712.00 80.40 327.18 9,058.62 8,973.61 3,847.67 404.73 5,933,254.060 719,599.099 10.75 3,313.70 10,744.87 83.87 326.46 9,063.09 8,978.08 3,874.76 387.02 5,933,260.614 719,580.611 10.84 3,345.73 10,775.69 87.50 325.43 9,065.42 8,980.41 3,900.38 369.70 5,933,305.722 719,562.556 12.16 3,376.28 10,806.87 89.99 326.70 9,066.10 8,981.09 3,926.24 352.30 5,933,331.065 719,544.413 8.96 3,407.07 10,901.90 89.98 325.21 9,066.13 8,981.12 4,004.98 299.10 5,933,408.223 719,488.951 1.57 3,500.94 10,999.27 90.13 323.64 9,066.03 8,981.02 4,084.17 242.45 5,933,485.734 719,430.033 1.62 3,596.67 11,094.05 90.04 324.94 9,065.89 8,980.88 4,161.13 187.13 5,933,561.050 719,372.503 1.37 3,689.82 4/1912019 3:34:07PM Page 11 COMPASS 5000.1 Build 81D BP Final Survey Report Company: North America - ALASKA- BP Local Coordinate Reference: Well 16-14 Project: PBU TVD Reference: ACTUAL KB - P272 @ 85.01 usft Site: 16 MD Reference: ACTUAL KB - P272 @ 85.01 usft Well: 16-14 North Reference: True Wellbore: 16-14C Survey Calculation Method: Minimum Curvature Design: 16-14C Database: EDM R5K - Alaska PROD - ANCPI Survey MD Inc AN TVD TVDSS NIS EIW Northing Easting DLeg V. Sec (usft) C) 1°) (usft) Weft) (usft) (usft) NMI) (usft) (°I100usft) ("it) 11,188.89 8998 323.48 9,065.88 8,980.87 4,238.06 131.67 5,933,636.332 719,314.833 1.54 3,783.00 11,283.31 89.98 325.18 9,065.91 8,980.90 4,314.76 76.61 5,933,711.400 719,257.575 1.80 3,875.81 11,377.50 90.01 324.67 9,065.92 8,980.91 4,391.85 22.49 5,933,786.877 719,201.236 0.54 3,968.57 11,472.59 90.04 324.24 9,065.88 8,980.87 4,489.22 -32.79 5,933,862.607 719,143.735 0.45 4,062.07 11,566.49 90.01 324.88 9,065.84 8,980.83 4,545.72 -87.24 5,933,937.492 719,087.091 0.68 4,154.44 11,661.10 90.01 325.36 9,065.82 8,980.81 4,623.33 -141.34 5,934,013.498 719,030.759 0.51 4,247.66 11,756.34 90.04 326.77 9,065.78 8,980.77 4,702.35 -194.51 5,934,090.933 718,975.323 1.48 4,341.76 11,849.71 90.07 328.36 9,065.69 8,980.68 4,781.15 -244.59 5,934,168.243 718,922.981 1.70 4,434.36 11,944.88 89.98 327.49 9,065.65 8,980.64 4,861.79 -295.12 5,934,247.380 718,870.125 0.92 4,528.82 12,040.18 90.04 327.48 9,065.63 8,980.62 4,942.15 -346.35 5,934,326.216 718,816.590 0.06 4,623.31 12,135.16 89.98 328.72 9,065.61 8,980.60 5,021.90 -397.94 5,934,404.428 718,762.708 0.80 4,717.41 12,229.26 90.10 325.75 9,065.55 8,980.54 5,100.13 -450.24 5,934,481.099 718,708.162 1.04 4,810.43 12,323.96 91.58 324.61 9,064.16 8,979.15 5,177.86 504.30 5,934;557.225 718,651.864 1.97 4,903.74 12,418.17 91.57 325.94 9,061.57 8,976.56 5,255.26 557.95 5,934,633.031 718,595.997 1.41 4,996.58 12,512.05 92.03 326.90 9,058.62 8,973.61 5,333.43 -609.85 5,934,709.660 718,541.852 1.13 5,089.38 12,608.93 92.10 326.14 9,055.20 8,970.19 5,412.52 -662.15 5,934,787.189 718,487.274 0.80 5,183.18 12,701.13 92.43 326.42 9,051.48 8,966.47 5,490.81 -714.41 5,934,863.926 718,432.773 0.46 5,276.23 12,796.02 93.60 326.64 9,046.49 8,961.48 5,569.85 -766.66 5,934,941.415 718,378.243 1.25 5,369.97 12,889.94 91.51 326.30 9,042.30 8,957.29 5,648.06 -818.49 5,935,018.082 718,324.171 2.25 5,462.78 12,984.35 91.63 326.12 9,039.72 8,954.71 5,726.49 -870.98 5,935,094.954 718,269.432 0.23 5,556.06 13,078.77 91.54 326.81 9,037.10 8,952.09 5,805.08 -923.25 5,935,171.982 718,214.895 0.53 5,64939 13,173.74 91.51 326.86 9,034.58 8,949.57 5,884.46 -975.33 5,935,249.813 718,160.540 0.27 5,74336 13,268.36 91.67 324.83 9,031.95 8,946.94 5,962.72 -1,028.43 5,935,326.500 718,105.193 2.15 5,83675 13,362.94 91.70 324.12 9,029.17 8,944.16 6,039.66 .1,083.36 5,935,401.810 718,048.052 0.75 5,929.72 13,456.53 91.63 320.90 9,026.45 8,941.44 6,113.88 -1,140.29 5,935,474.341 717,988.993 3.44 6,021.07 13,551.45 91.54 317.44 9,023.82 8,938.81 6,185.66 .1,202.32 5,935,544.289 717,924.911 3.65 6,112.37 13,646.09 91.60 314.94 9,021.23 6,936.22 6,253.93 -1,267.80 5,935,610.620 717,857.472 2.64 6,201.95 4/192019 3:34:07PM Page 12 COMPASS 5000.1 Build BID RE BP Final Survey Report Company: North America - ALASKA - BP Local Coordinate Reference: Well 1&14 Project: PBU TVD Reference: ACTUAL KB - P272 @ 85.0lusft Site: 16 MD Reference: ACTUAL KB - P272 @ 85.01usft Well: 16-14 North Reference: True Wellbore: 16-14C Survey Calculation Method: Minimum Curvature Design: 16-14C Database: EDM R5K - Alaska PROD - ANCP1 Survey MD Inc Az. TVD TVDSS N/S EIW Northing Essting DLeg V. Sec (usft) (°) (°) (usft) inert) (usft) (usft) (usR) (usft) (°/100usft) (usR) 13,740.28 91.63 312.75 9,018.57 8,933.56 6,319.15 -1,335.70 5,935,673.834 717,787.710 2.32 6,289.80 13,834.75 91.63 311.20 9,015.89 8,930.88 6,382.30 -1,405.91 5,935,734.921 717,715.707 1.64 6,376.75 13,929.49 91.57 309.43 9,013.24 8,928.23 6,443.57 -1,478.11 5,935,794.065 717,641.753 1.87 6,462.84 14,022.33 91.60 307.22 9,010.67 8,925.86 6,501.12 -1,550.91 5,935,849.470 717,567.315 2.38 6,545.81 14,119.10 91.30 306.39 9,008.22 8,923.21 6,559.07 -1,628.37 5,935,905.149 717,488.212 0.91 6,631.13 14,213.45 91.36 307.28 9,006.03 8,921.02 6,615.62 -1,703.86 5,935,959.478 717,411.111 0.95 6,714.34 14,307.27 91.27 308.32 9,003.88 8,918.87 6,673.11 -1,777.98 5,936,014.786 717,335.365 1.11 6,797.81 14,401.29 91.24 309.89 9,001.82 8,916.81 6,732.39 -1,850.92 5,936,071.927 717,260.738 1.67 6,88242 14,494.90 91.33 308.52 8,999.72 8,914.71 6,791.55 -1,923.43 5,936,128.947 717,186.537 1.47 6,966.73 14,590.08 91.36 306.97 8,997.49 8,912.48 6,849.79 -1,998.67 5,936,184.982 717,109.641 1.63 7,051.37 14,685.00 91.27 307.17 8,995.31 8,910.30 6,907.00 -2,074.39 5,936,239.958 717,032.298 0.23 7,135.26 14,778.00 91.36 307.26 8,993.18 8,908.17 6,963.23 -2,148.43 5,936,294.014 716,956.657 0.14 7,217.57 14,873.37 91.36 307.25 - - 8,990.91 8,905.80 7,020.95 -2,224.32 5,936,349.500 716,879.128 0.01 7,302.01 14,968.76 91.30 307.20 6,988.70 8,903.89 7,078.64 -2,300.26 5,936,404.958 716,801.553 0.08 7,386.44 15,063.83 92.07 304.86 8,985.90 8,900.89 7,134.53 -2,377.10 5,936,458.593 716,723.121 2.59 7,469.63 15,158.78 92.00 304.88 8,982.53 8,897.52 7,188.78 -2,454.95 5,936,510.557 716,643.729 0.08 7,551.75 15,252.16 91.39 305.11 8,979.77 8,894.76 7,242.31 -2,531.42 5,936,561.842 716,565.747 0.70 7,632.64 15,347.63 89.55 305.82 8,978.99 8,893.98 7,297.70 -2,609.17 5,936,614.946 716,486.424 2.07 7,715.76 15,441.25 89.55 304.65 8,979.72 8,894.71 7,351.71 -2,685.63 5,936,666.710 716,408.427 1.25 7,797.08 15,536.48 89.02 304.51 8,980.91 8,895.90 7,405.75 -2,764.03 5,936,718.452 716,328.494 0.58 7,879.25 15,631.41 89.79 305.59 8,981.90 8,896.89 7,460.26 -2,841.74 5,936,770.683 716,249.239 1.40 7,961.55 15,725.07 88.99 307.61 8,982.89 8,897.88 7,516.10 -2,916.92 5,936,824.309 716,172.469 2.32 8,043.99 15,819.36 89.02 308.84 8,984.53 8,899.52 7,574.43 -2,990.98 5,936,880.464 716,096.749 1.30 8,12821 15,913.57 88.87 311.00 8,986.26 8,901.25 7,634.87 -3,063.22 5,936,938.780 716,022.791 2.30 8,213.56 16,008.96 90.57 313.35 8,966.73 8,901.72 7,698.91 -3,133.91 5,937,000.734 715,950.279 3.04 8,301.52 16,040.75 90.56 310.26 8,986.42 8,901.41 7,720.10 -3,157.60 5,937,021.224 715,925.982 9.72 8,330.75 16,072.68 90.50 308.15 8,986.12 8,901.11 7,740.28 -3,182.34 5,937,040.677 715,900.668 6.61 8,359.51 4/192019 3:34 07P Page 13 COMPASS 5000.1 Build 81D ,l,*N by �+sH BP Final Survey Report Company: North America - ALASKA - BP Local Co-ordinate Reference: Well 16-14 Project: PBU TVD Reference: ACTUAL KB - P272 @ 85.01usft Site: 16 MD Reference: ACTUAL KB - P272 @ 85.01usft Well: 16-14 North Reference: True Wellbore: 16-14C Survey Calculation Method: Minimum Curvature Design: 16-14C Database: EDM R5K - Alaska PROD - ANCP1 Survey MD Inc Azl TVD TVDSS N1S E1W Northing Easting DLeg V. Sec (usft) (°) (°) (usft) (usft) lush) (usft) (usft) (usft) (°MOoush) (usft) 16,103.75 90.59 306.85 8,985.83 8,900.82 7759.19 -3,206.99 5,937,058.865 715,875482 4.19 8,387.09 16,197.39 90.53 307.76 8,984.91 8,899.90 7,815,94 -3,281.46 5,937,113.424 715,799.390 0.97 8,470.05 16,292.10 90.56 308.06 8,984.01 8,899.00 7,874.13 -3,356.19 5,937,169.416 715,723.015 0.32 8,554.41 16,385.88 90.50 306.18 8,983.14 8,898.13 7,930.72 -3,430.96 5,937,223.808 715,646.635 2.01 8,637.36 16,480.49 90.62 304.21 8,982.22 8,897.21 7,985.24 -3,508.26 5,937,276.062 715,567.781 2.09 8,719.50 16,575.19 90.56 303.45 8,981.24 8,898.23 8,037.96 -3,586.93 5,937,326.472 715,487.625 0.80 8,800.58 16,670.15 90.56 304.53 8,980.31 8,895.30 8,091.05 -3,665.66 5,937,377.245 715,407.390 1.14 8,882.03 16,764.56 90.31 306.32 8,979.60 8,894.59 8,145.77 -3,742.58 5,937,429.705 715,328.910 1.91 8,964.19 16,842.61 87.98 307.26 8,980.76 8,895.75 8,192.50 -3,805.08 5,937,474.602 715,265.089 3.22 9,033.00 16,872.74 87.98 307.93 8,981.82 8,896.81 8,210.87 -3,828.93 5,937,492.271 715,240.708 2.22 9,059.75 16,908.00 87.98 307.93 8,983.07 8,898.06 8,232.53 -3,856.73 5,937,513.114 715,212.298 0.00 9,091.14 Projection 4/192019 3..34:07PM Page 14 COMPASS 5000.1 Build 81D Propel: PBU A `*T -u WELLIDDRE DETAILS: 1&14C fdfEPENCEJWORWI �1• �nrt.nt --- SIN: 18 Wp Fi i&14C ^.IB�IRtlxen® wea t6td, iiue NUT WM: 18.14 a 5zxo � Vatsl( 9)Rtl . ee.&e W�Wan: 1&i4C wWq..m Sekon CVS) Rdle snt-POON.OWE1 1&id DoWgn: 1&140 4IIffi(/p ui.amt MtlYIK1W.l Te On MD: 7491.78 Mwvtl0 NO Rd. ACiMKBMn@UOIM Cdala. Meuwe MrvroJNCWeLe 4 100t0s p North America - ALASKA - BP PBU 16 16-14 16-14C 16-14C 500292057003 AOGCC Offset Well Report 19 April, 2019 Company: North America - ALASKA - BP Project: PBU Reference Site: 16 Site Error: 0.00usft Reference Well: 16-14 Well Error: 0.00usft Reference Wellbore 16-14C Reference Design: 16-14C BP Anticollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 16-14 Mean Sea Level ACTUAL KB - P272 @3 85.01 usft True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum teference 16-14C 'ilter type: NO GLOBAL FILTER: Using user defined selection& fftering criteria To manipulation Method: MD Interval 25.00usft Enor Model: ISCWSA )epth Range: Unlimited Scan Method: Tray. Cylinder North tesulls Limited by: Maximum center -center distance of 500.00usft Error Surface: Elliptical Conic Survey Program Date 4/19/2019 From To Offset Centre to (usft) (usft) Survey(Wetlbore) Tool Name Description 118.91 7,491.78 16-14 GyroData (16-14) GVD-CT-CMS Gyrodata cont.casing mls 7,499.00 7,652.78 Survey#1(16-14C) BLIND Blind drilling 7,685.52 10,249.29 Survey #2 (16-14C) MWD+IFR+MS-WOCA MWD +IFR+Multi Station W/O Crustal 10,301.28 16,908.00 Survey #3 (16-14C) MWD+IFR+MS-WOCA MWD +IFR+Multi Station W/O Crustal Summary Reference Offset Centre to Measured Measured Centre Site Name Depth Depth Distance Offset Well - Wellbore - Design (usft) (usft) (usft) 03 03-04 - 03-04 - 03-04 11,518.86 12,175.00 288.97 03.12 - 03-12 - 03-12 15,621.18 9,425.00 387.00 03 -12 -03 -12A -03-12A 15,851.24 9,500.00 302.65 O9 16 16-10-1&10-16-10 3,941.34 3,925.00 449.90 1&10 -16 -10A -1&10A 3,946.11 3,925.00 449.92 1&11-16-11-1&11 3,918.79 3,900.00 316.67 1&12-1&12-16-12 3,963.79 3,950.00 184.10 1&12 -16 -12A -1&12A 3,966.14 3,950.00 184.12 1&13-1&13-1&13 3,380.99 3,375.00 49.25 16-13-16-13PB1-16-13PB1 3,380.99 3,375.00 49.25 16-13-1&13PB2-16-13PB2 3,380.99 3,375.00 49.25 16-14-1&14-1&14 7,808.83 7,800.00 49.70 16-14 - 16-14A - 16-14A 12,564.39 15,175.00 161.96 16-14-1&148-16-14B 7,811.77 7,800.00 50.38 16-15 - 16-15 - 16-15 1,813.70 1,800.00 119.89 16-15 - 16-15A - 16-15A 1,813.70 1,800.00 119.89 16-15 - 1 &15APB1 - 16-15APB1 1,813.70 1,800.00 119.89 16-16-1&16-1&16 3,056.66 3,050.00 246.12 16-18-1&18-16-18 5,715.68 5,575.00 480.90 16-28 - 16-28 - 16-28 2,514.93 2,500.00 36.05 16-29 - 16-29 - 16-29 2,493.16 2,475.00 176.16 16-29 - 16.29A - 16-29A 2,493.16 2,475.00 176.16 411912019 1:2O52PM Page 2 of 2 COMPASS 5000.1 Build 81D _ North America - ALASKA - BP Pap° 1 oft Cementing Report Common Well Nemo: 18-14 / 02 -- Report no 1 Report date: 3/7/2019 ProJett: PBU - Site: 18 -- - I Spud DateRme: 2/16/2006 Event Type: RE-ENTER- ONSHORE (RON) Start Date: 2728Yd019 End Date: 3/14-2019 AFE No.: _ Contractor PARKER DRILLING CO. Rip Name/No.: PARKER 272 Rig Release: 3/22/2019 X3 -019i (5,676,591.00 ) BPUOI: USA00001922 Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level - . .. ,:..,..d., .......:.. :.. .....- General lMnmlatlbn Job type: Primary Cement jab start date/time: 3/7/2019 10:OOAM Job end dater me. 3!7/2019 12:30PM Cement Company. SCHLUMBERGER Cementer: DANIEL SETTLE Cemented String : INTERMEDIATE CASING 1 Stnng Size. 7.000 (in) String Set TMD: 10,286.00 (usft) Hole Size: 9.875 (In) Pipe Movement Pipe Movement: RECIPROCATING Rotating Time (Start -End). RPM. Rotating Torque (iniVavg/max): (ft-Ibf) Reciprocating Time (Start -End)'. Recip Drag Up/Dov,. - (kip) SPM: Stroke Length: Fluid Name: SPACER Fluids (1 of 2) Slurry Type: SPACER Purpose: SPACER Class: Description: MUD PUSH II Density: 13.00 (ppg) Yield: Mix Water Ratio: Excess: Mix Method: Sacks Used: Water Volume: Excess Slurry Volume: 0.0 (bbl) Density Measured by: DENSOMETER Other Volume: Total Vol in Well: Slurry Volume: 50.0 (bbl) Excess Measured From: MW Type: Density: 10.40 (pi PV: 12.00 (op) YP: 18.000 (Ibf/100ft-) Viscosity: 40.00 (Nqt) Gels 10 Sec: 8.000 (Ibf/100(12) Gels 10 Min: 9.000 (Ibf1100ft-) Fluld Name: CEMENT Fluids (2 of 2) Slurry Type: CEMENT Purpose: PRIMARY Class: G -CLASS Description: LEAD SLURRY Density: 15.80 (ppg) Yield: 1.1600 (ft'/sk) Mix Water Ratio: 5.044 (gallskg4) Excess: 40.00(%) Mix Method: ON -THE -FLY Sacks Used: 469.50 (941b sacks) Water Volume: 56.4 (bbl) Excess Slurry Volume: 27.7 (bbl Density Measured by: DENSOMETER Other Volume: Total Vol in Well: Slurry Volume: 97.0 (bol) Excess Measured From: EST. GAUGE HOLE Mud Type: Density: 10 40 (ppg) PV: 12.00 (cp) YP: 18.000 (Ibf1100ft') Viscosity: 40.00 (s/qt) Gels 10 See: 6.000 (Ibf/1001`12) Gels 10 Min. 9.000 (Ibf/100ft-) Additives Name Type Amount Units Concentration Unit D047 ANTIFOAM AGENT 0.050 GAL/SX D065 DISPERSANT 0.300 %BWOC 0167 FLUID LOSS 0.250 % BWOC D153 ULTRAFINE SiO2 0.200 %BWOC D177 RETARDER 0.020 GAL/SX Printed 4/10/2019 8:39:17AM Printed 4/10/2019 8:39:17AM Papa 2 m 2 North Arnerica - ALASKA - BP Cementing Report Common Well Name: 16-14102 Report no.: 1 Report date: 31`7/2019 Project: PBU Site: lfi Spud Date/Time. 2 /1 612 0 0 6 Event Type. RE-ENTER- ONSHORE (RON) Start Date: 2/28/2019 Entl Dete: 3/14/2019 AFE No.: Contractor: PARKER DRILLING CO. Rig Name/No.: PARKER 272 Rig Release: 3/22/2019 X3 -0197F -C: (5,676,591.00 ) BPUOL USA00001922 Active datum: ACTUAL KB P272 ®82.93usft (above Mean Sea Level) Fluid Teats Thick time Thick Free water Free water Fluid loss Fluid loss Fluid loss Comp Comp Camp Comp Comp Strength Comp Strength (hr) temp. M temp. (cc/30min) temp. press. Strength Strength Strength Strength Time Pressure 2 Temperature 2 (°F) ("F) (°F) (psi) Time 1 Pressure 1 Temperature 1 2 (psi) (°F) min psi 'F min 4.23 0.00 80.00 44.0 137.00 Stages Stage Stage Type Est, Top Est. Bottom Mud Circ. Mud Circ. Top Bottom pm9 Pure ress Float Pm.svre Returns e Circulate CVol to Total Annular no. (usft) (usft) Rate I Press. Plug Plug Bumped Bumped Hem Ham Prior Surface Mud Lost Flow (gpm) (psi) (hr) (bbl) (bbl) After (psi) (min) 1 RIMARY CEMENT 8,288.00 10,286.00 Y Y Y Pumping Schedule Fluid pumped Volume Avg. Max Disp. Slurry Top Slurry Base Start Mix Cmt Start Slurry Pumping end Start Disp Foam Gas Type Gas Vol BH circ. Bh static Pumped Oisp. Rate TMD TMD PmP date/time job Used temp. temp. (bbl) Rate (bbymin) ( isft) (usft) (scf) bbl/min Tests Casing Teat Shoe Test Liner Top Test Test Pressure: 4,000.00 (psi) FIT/LOT: (ppg) Liner Overlap: (usft) Time: 30 (min) Tool: N Positive Test: (pPg) Positive Test Tool: N Cement Found betvesen Shoe and Collar: N Open Hale Length: (uaft) Negative Test: (pPg) Negative Test Tool: N Hours Before Start: (hr) Time before test: (hr) Cmt Found on Tool: N Log/Survey Evaluation Interpretation Summary CBI -Run N Cement Tap: (usft) Under Pressure: (psi) How Determined: Bond Quality: TOC Sufficient: N CET Run: N Job Rating: Bond Quality: If Unsuccessful, Detection Indicator: Temp Survey: N Remedial Cement Required: N Him Prior to Log: (hr) How Determined: Printed 4/10/2019 8:39:17AM Printed 4/10/2019 8:39:48AM Nath America - ALASKA - BP Papa 1 of 2 CemenBng Report Common Well Name: 16-14 / 02 Report no.: 2 Report date: 3/20/2019 Project: PBU Sse: i6 Spud DeteMme' 2/16/2008 Event Type: COM- ONSHORE (CON) Start Date: 3/14/2019 End Date: 3/22/2019 AFE No.: Contractor: PARKER DRILLING CO. Rig Name/No.. PARKER 272 Rig Release: 3/22/2019 X3-0I97F-C: (2,917.40&00 ) BPUOI: USA00001922 Acive datum. ACTUAL KB P272 @62.93ustt (above Mean Sea Level) Oanenl Informatlon Job type: Primary Cement job start date/time: 3/20/2019 12:OOAM Job end datettime: 3/20/2019 1:OOAM Cement Company: SCHLUMBERGER Cementer: STEVE ABBOTT Cemented String: PRODUCTION LINER 1 String Size. 4.500 (in) String Set TMD: 16,906.00 (usft) Hole Size: 6.125 (in) INps Movement Pipe Movement: RECIPROCATING Rotating Time (Start-End). RPM: Rotating Torque (initfavg/max): (ft-lbt) Reciprocating Time (Start-End): Recip Drag Up/Down: - (kip) SPM: Stroke Length: Weil lMlrre: oppi R Polds (1 of 2) Slurry Type: SPACER Purpose: SPACER Class: Description: MUD PUSH 11 Density: 12.00 (ppg) Yield: Mix Water Ratio: Excess: Mix Method: BATCH Sacks Used: Water Volume: Excess Slurry Volume: 0.0 (bbl) Density Measured by: DENSOMETER Other Volume: Total Vol in Well: Slurry Volume: 40.0 (bbl) Excess Measured From: Mud Type: Density: 9.00 (ppg) PV: 0.00 co) YP: 0.000 (I01001t') Viscosity: 0.00 (a/qt) Gels 10 Sec: 0.000 (Ibf/100f -) Gels 10 Min: 0.000 (Ibf1100fP) Weld Mama: CWAMfT Flues (2 of 2) Slurry Type: CEMENT Purpose: PRIMARY Class: G-CLASS Description: LEAD SLURRY Density: 15.00 (ppg) Yield: 1.2600 (ft'/sk) Mix Water Ratio: 5.536 (gaVsk94) Excess 30.00(%) Mix Method: BATCH Sacks Used: 682.00 (941b sacks) Water Volume: 89.9 (bbl) Excess Slurry Volume: 35.3 (bbl) Density Measured by: DENSOMETER Other Volume: Total Vol in Well: Slurry Volume: 153.1 (bbl) Excess Measured From: EST. GAUGE HOLE Mud Type: Density: 9.00 (ppg) PV: 0.00 (cp) YP: 0.000 (Ibf/100ft-) Viscosity: 0.00 (s/qt) Gals 10 Sec: 0.000 (Ibf/100t[-) Gels 10 Min: 0.000 (Ibf/100w) Addltivaa. Name Type Amount Units Concentration Unit D047 ANTIFOAMAGENT 0.020 GAL/SX D085 DISPERSANT 0.300 % BWOC D187 FLUID LOSS 0.500 % BWOC D153 ULTRAFINE S1O2 0.450 % BWOC D177 RETARDER 0.010 GAUSX Printed 4/10/2019 8:39:48AM Printed 4/10/1019 8:39:48AM Papa 2 or2 North America - ALASKA - BP Cementing Report Common Well Neme16-14 / 02 — — — Report no.: 2 Report date: 3/10/2019 Project PBU - - Sde 18 Spud Date(Time'. 2/16/2006 Event Type: COM- ONSHORE (CON) Start Date. 3/14/2019 End Date'. 3/22/2019 �. AFE No.: Contractor. PARKER DRILLING CO. Rig Name/No: PARKER 272 Rig Release. 3/22/2019 X3 -0197F -C: (2,917,406.00 ) BPUOI USAODOO1922 Active datum. ACTUAL KB P272 @82.93usft (above Mean Sea Level) Fluid Tests Thick time Thick Free water Free water Fluid loss Fluid loss Fluid loss Comp Comp Camp Comp Comp Strength Comp Strength (hr) temp. (%) temp. (cc(30min) temp. press. Strength Strength Strength Strength Time Pressure 2 Temperature 2 (°F) (°F) ("F) (psi) Time 1 Pressure 1 Temperature 1 2 (psi) (°F) min(psi) "F min 5.92 0.00 80.00 70.0 1130.00 stag" Stage Stage Type Est Top Est. Bell Mud Circ. Mud Circ. Top Bottom PWg Pressure Hoar Pressure Return Circulate Cmt Vol to Total Annular no. (usft) (usft) Rate Press. Plug Plug eumcea Bumped nem nem Pdor Surface Mud Lost Flow (gpm) (psi) (hr) (bbl)( bbl) After (Pep (mm) 1 RIMARV CEMENT 10,123.00 16,906.00 V V v v Pumping Schedule Fluid pumped Volume Avg. Max DISP. Slurry Top Slurry Base Start Mix Cmt Start Slurry Pumping end Start Dap Foam Gas Type Gas Vol BH circ. Bh static Pumped Disp. Rate TMD TMD Pmp date/time job Used temp. temp. (bbl) Rate (bbllmin) (usft) (usft) O bbl/min Testa Casing Test Shoe Teat Liner Top Test Test Pressure: (psi) FIT/LOT'. (PPg) Liner Overlap: (usft) Time: (min) Tool'. N Positive Test. (ppg) Positive Test Tool: N Cement Found between Shoe and Collar: N Open Hole Length. (usft) Negative Test. (ppg) Negative Test Tool: N Hours Before Start (hr) Time before test: (hr) CPA Found on Tool: N Logrsurvey, Evaluation Interpretation Summary CBL Run: N Cement Top: (usft) Under Pressure: (psi) How Determined: Bond Quality: TOG Sufficient: N CET Run: N Job Rating: Band Quality: If Unsuccessful, Detection Indicator: Temp Survey: N Remedial Cement Required: N Hrs Prior to Log: (hr) How Determined: Printed 4/10/1019 8:39:48AM MEMORANDUM TO: Jim Regg icy 4�/b li P.I. Supervisor FROM: Adam Earl Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, April 15, 2019 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. 16-14C PRUDHOE BAY UNIT 16-14C Sre: Inspector Reviewed By: P.I. Supry a NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 16-14C API Well Number 50-029-20570-03-00 Inspector Name: Adam Ear Permit Number: 218-117-0 Inspection Date: 3/28/2019 ' Insp Num: mitAGE190330140530 Rel Insp Num: BBL Pumped: 5.2 BBL Returned: 5.2 _ OA 40 1 i ao Ao Interval, OTHER P/F P Notes: MIT T, Required witness pre- injection Monday, April 15, 2019 Page 1 of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 16-14C TypeInj N ITVD 8627 Tubing n 39" 2181170 -Type Test SPT Test psi 2157 IA 0 84 79 bl BBL Pumped: 5.2 BBL Returned: 5.2 _ OA 40 1 i ao Ao Interval, OTHER P/F P Notes: MIT T, Required witness pre- injection Monday, April 15, 2019 Page 1 of I MEMORANDUM To: Jim Regg P.I. Supervisor FROM: Adam Earl Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, April 15, 2019 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. 16-14C PRUDHOE BAY UNIT 16-14C Ste: Inspector Reviewed By: P.I. Suprvim— NON -CONFIDENTIAL Comm [Rel e" Name PRUDHOE BAY UNIT 16-14C API Well Number 50-029-20570-03-00 Inspector Name: Adam Earl Permit Number: 218-117-0 Inspection Date: 3/28/2019 sp Num: mitAGE190330141025 Insp Num: Packer 16-14C Type Inj nTVD PTD 2181170 IType Test sPT Test ps BBL Pumped: 88 ' BBL Returned: Interval OTHER P/F Notes: MIT L4 required pre- injection witness lepth Pretest Initial I5 Min 30 Min 45 Min 60 Min 8627 TUbingl 2506 3201- 3208'3200 2157 IA 18 4385 4339 I 4320 8.8 OA 40 48 48 48 P Monday, April 15, 2019 Page I of 1 Well Name PRUDHOE BAY UNIT 16-14C API Well Number 50-029-20570-03-00 Inspector Name: Guy Cook - Permit Number: 218.117-0 Inspection Date: 4/7/2019 Insp Num: mitGDC190407125724 Rel Insp Num: MEMORANDUM State of Alaska Type In T D 8632 Tubi 2388 2388 z396 - zaoz — — — z1s9.zs IA 815 azso �41eo - al57 - T7 Alaska Oil and Gas Conservation Commission -Type Test s Test psi — —1664 — —167 DATE: Thursday, April 11, 2019 TO: Jim Regg / 11 �/� 4f p�i9 SUBJECT: Mechanical Integrity Tests P.I. Supervisor L BP EXPLORATION (ALASKA)INC. 16-14C FROM: Guy Cook PRUDHOE BAY UNIT 16-14C Petroleum Inspector Src: Inspector Reviewed B P.I. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 16-14C API Well Number 50-029-20570-03-00 Inspector Name: Guy Cook - Permit Number: 218.117-0 Inspection Date: 4/7/2019 Insp Num: mitGDC190407125724 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 6 lac `— Type In T D 8632 Tubi 2388 2388 z396 - zaoz — — — z1s9.zs IA 815 azso �41eo - al57 - T7 PTD -Type Test s Test psi — —1664 — —167 p2181170 BBL Pum ed.T 7.3 IBBL Returned 7.3 OA z3 ez ' Interval OTHER -_ P/F _ Notes: Post rig. Per drilling permit as MIT -IA is required to 4000 psi. Testing done with a triplex pump, bleed trailer and digital gauges. Thursday, April 11, 2019 Page 1 of I Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWeIISiteEnginee@bp.com> Sent: Tuesday, April 2, 2019 9:15 AM To: Wallace, Chris D (DOA); AK, OPS EOC Specialists; AK, OPS FS2 DS Ops Lead; Ak, OPS FS2 Facility PTL; Ak, OPS FS2 Field PTL; AK, OPS FS2 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Alatalo, Travis; G GPB FS2 Drillsites; Ohms, Danielle H; Rupert, C. Ryan; Smith, Travis T (CONOCOPHILLIPS); Summers, Matthew Cc: Regg, James B (DOA); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity, AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey, Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: OPERABLE: Injector 16-14 (PTD #2181170) passed MITs post sidetrack 02 WAG Injector 16-14 (PTD #2181170) was recently sidetracked and a new completion string was installed. On 03/28/19 Slickline set the production packer and Fullbore performed an AOGCC witnessed MIT -T to 3,873 psi and MIT -IA to 4,320 psi. The passing pressure tests confirm two barriers to formation and the well is now classified as OPERABLE. Once the well is on injection and thermally stable, an AOGCC witnessed MIT -IA to 4,000 psi will be performed. Note the fluid packed annulus when putting the well on injection. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization -Alaska Office: 907-659-8110 From: AK, GWO %91.11integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Wednesday, JanaNk9, 2019 4:18 PM To:'chris.wallace@alaska.go hris.wallace@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS FS2 DS Ops Lead <AKOPSF psLead@bp.com>; Ak, OPS FS2 Facility PTL <AKOPSFS2FacilityPTL@bp.com>; Ak, OPS FS2 Field PTL <AKOPSF52FieIdPTL com>; AK, OPS FS2 OSM <AKOPSFS20SM1@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp. >; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCT OPSPCCEOCTL@bp.com>; Alatalo, Travis <Travis.Alatalo@bp.com>; G GPB FS2 Drillsites <ggpbfs2drillsites P.com>; Nottingham, Derek <Derek.Nottingham@bp.com>; Ohms, Danielle H <Danielle.Ohms@bp. >; Rupert, C. Ryan <Ryan.Rupert@BP.com>; Stechauner, Bernhard <Bernhard.Stechauner@bp.com>; Summers, Matthew atthew.Summers@bp.com>; Worthington, Jessica <Jessica.Worthington@bp.com> Cc:'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO Comp ' ns Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@ com>; AK, GWO Projects Well Integrity<AKDCProjectsWelllntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrit <AKDCWellintegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwcwellintegrity @bp.com: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@ com> Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G SCANNED p,pR 16 2919 Rixse, Melvin G (DOA) From: Rixse, Melvin G (DOA) Sent: Wednesday, January 23, 2019 10:37 AM To: 'Raese, J. Kyle' Subject: FW: PBU 16-14C PTD (218-117) - CBL depths Kyle, BPXA has AOGCC approval to run CBL from the top of the 4-1/2" liner to the top of cement on the 7" ("'estimated to be —8800' MD), i.e. there will be no requirement to run the CBL across the 4-1/2" liner. As the variance to 20AAC.25.412(b) has been approved, it is imperative to assure to get the CBL log data be as near the top of the 4-1/2" liner (^'10,155' MD) as possible. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains infortnation 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 Mel Rixse at (907-793-1231) or (MeIVIn.Rixse@olalaska.&ov). From: Rixse, Melvin G (DOA) Sent: Wednesday, January 23, 2019 9:03 AM To: 'Raese, J. Kyle' <john.raese@bp.com> Subject: RE: PBU 16-14C PTD (218-117) - CBL depths Kyle, Log the 7" from TOL (4-1/2") to TOC on the 7". Regarding the 4-1/2": Can't you log your liner lap with the 4-1/2" tools? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell 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 Mel Rixse at (907-793-1231) or (Melvin.Rixseaalaska,gov). From: Raese, J. Kyle <lohn.raese@bp.com> Sent: Wednesday, January 23, 2019 8:09 AM fo: Rixse, Melvin G (DOA) <melvin.rixse@alaska.aov> Subject: PBU 16-14C PTD (218-117) - CBL depths Mel, The approved permit requests that the CBL "to log as deep as possible in 4-1/2' and then "identify TOC outside the 7" liner' —see page 9 (operations summary) of the approved permit. We will not be able to log both the 4-1/2" liner and 7" liner in the same wireline run due to centralization requirements. Would it instead be acceptable to log from the 4-1/2" liner top to the top of 7" liner cement? The 4-1/2" x 7" liner lap is planned to be -150'— this portion would not be logged. Thanks, Kyle Raese Drilling Engineer BP Exploration (Alaska) a: 907-564-4629 c:907-301-6405 THE STATE 01ALASKA. GOVERNOR BILL WALKER Kenneth Allen Engineering Team Lead BP Exploration (Alaska), Inc. P.O Box 196612 Anchorage, AK 99519-6612 Alaska Oil and Gas Conservation Commission Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 16-14C BP Exploration (Alaska), Inc. Permit to Drill Number: 218-117 Surface Location: 1534' FNL, 527' FWL, SEC. 24, TI ON, RI 5E, UM Bottomhole Location: 1403' FSL, 3313' FEL, SEC. 11, T1ON, R1 5E, UM Dear Mr. Allen: 333 West 7th Avenue Anchorage, Alaska 99501 Main: 907.297.1433 Fax: 907.276.7542 www.00gcc.olaska.gov Enclosed is the approved application for the permit to redrill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Hollis S. French Chair DATED this o qday of October, 2018. STATE OF ALASKA ASKA OIL AND GAS CONSERVATION COMMISS PERMIT TO DRILL 20 AAC 25.005 Is Type of Work: 1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG 0 . Service - Disp❑ 1c. Specify if well is proposed for: Drill 11 Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑ Service -Wmj ❑ Single Zone ❑ Coalbed Gas p Gas Hydrates Rednll ®' 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: BP Exploration (Alaska), Inc Bond No. 295705380 - PBU 16-14C ' 3 Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 196612 Anchorage, AK 99519.8612 MD: 16914' • TVD: 8964' PRUDHOE BAY, PRUDHOE OIL 4a Location of Well Governmental Section). ( ) 7. Property Designation (Lease Number): ADL 0028332 i+Dk— (XiZ&5Z e. DNR Approval Number: 7p.("/fj 13. Approximate spud date: Surface: 1534' FNL, 527' FAL, Sec. 24, T10N, R15E, UM 2013' FSL, 1122 FWL. Sec, 13, TION, R15E, UM 79-081 March 1, 2019 Top of Productive Horizon: 9. Acres in Property: 2560 14. Distance to Nearest Property: Total Depth: 1403' FSL, 3313' FEL, Sec. 11, TION, R15E, UM 13857 4p Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 67 feet 15. Distance to Nearest Well Open [o Same Pool: o S Surface: x- 719306' y- 5929396 " Zone - ASP 4 GL Elevation above MSL: 37.06 feet 16. Deviated wells: Kickoff Depth: 7614 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 92 degrees Downhole: 3834 ' Surface: 2935 - 18, Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grace Coupling Length MD TVD Mo TVD (including stage data 8-1/2"x9-7 7 26# L-80 VamTop HC 2850' 7450' 6867' 10300' 8840' 465 sx Class'G' 6-1/8" 4-1/2" 12.6# 13Cr85 Van HTTC 6764' 10150' 8717' 16914' 8964' 680 sx Class'G' 19 PRESENT WELL CONDITION SUMMARY (To be completed for Retlrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measuretl): Effect. Depth MD (it): Effect. Depth TVD (ft): Junk (measured): 15307 8990 12200,14825 12200 9047 14625 Casing Length Size Cement Volume MD TVD Conductor/Structural 80 20" 300 sx Permafrost 31 - 111 31 - 111 Surface 2642 13-3/8• 3000 sx Fondu. 1250 sx Permafrost 30-2672 30-2672 Intermediate 8934 9-5/8' 500 sx Clan *G' 27-8963 27-8073 Liner 1143 7" 288 sx Class'G' 8773-9916 7915-8835 Liner 5512 4-1/ 643 sx Class'G' 9795-15307 8741 -8990 Perforation Depth MD (ft): 11548 -15100 Perforation Depth TVD (ft): 9049-8992 Hydraulic Fracture planned? Yes ❑ No m 20. Attachments Property Plat ❑ BOP Sketch EI Drilling Program m Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program a 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein vnll not be deviated Contact Name Raese. J. Kyle from without prior written approval. Authorized Name Allen, Kenneth W Contact Email lohn.mese0op.com Authorized Title Engineering Team Lead Contact Phone *1 9075644629 Authorized Signature /C; b G __ Date .Z� ' Commission Use Only Permitr: Drill Approval Sq cover letter for Other Z/9- ��•7 Number: / ��jj API: 50- 029-20570-03-00 DatePerm Date , 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: Wk� &Tt`SrTo yoact}s'l a r['G 1t] � Samples req'tl: Yes No Mud log req'tl: Yes ❑ No /1 —❑ —/ Vdr o tLe}p �/¢?f-./tN/y�7CD� H2S measures Yes 13 No ❑ Directional svy req'd: Yes ER No ❑ / Q. Pb M0 Spacing Spacing exception req'd: Yes 11 No Gr/ Inclination -only svy req'd: Yes ❑ No 13 II Post initial injection MIT mq'd: Yes ❑ No ❑ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 16 tJ 116 GDW f0�to�LoiY f�ia��n�>��I �kWl�gfl� (M-6Roq (��/ /1� /O• Z r� Form 10-401 Revised 5/2017 This permit is valid t roust 20 AAC 25.005 vomit Form aria Attachments in Duplicate by To: Alaska Oil & Gas Conservation Commission From: Kyle Raese, ODE Date: September 27, 2018 RE: 16-14C Permit to Drill The 16-14C well is scheduled to be drilled by Parker 272 in March 2019. The proposed 16-14C sidetrack will be a horizontal injector targeting the 26P "Victor" Package in the Sadlerochit. The planned well is a two string, ultra-slimhole design using 7" intermediate liner and 4-1/2" production liner. The intermediate liner will be set at the top of the Sadlerochit and the injection interval will be completed with a cemented liner using sliding sleeves. The maximum anticipated surface pressure from the Sadlerochit with a full column of gas from TD to surface is 2,935 psi (8.2 ppg EMW in Sadlerochit at 8,992' TVDss with 0.1 psi/ft gas gradient). The well will be drilled by Parker 272 using their 5,000 psi four preventer BOP stack (3 rams and an annular). The BOP rams will be tested to 4,000 psi and the annular will be tested to 3,500 psi. A detailed operations summary is included with the permit application. If there are any questions concerning information on 16-14C, please do not hesitate to use the contact information below. Kyle Raese Office: (907) 564-4629 Cell: (907) 301-6405 Email: john.raese@bp.com Attachments: Proposed Well Bore Schematic Proposed Pre -Rig Schematic Directional Package BOPE Schematic Area Review & Map Well Head Schematic Tree Schematic 16-14C PTD 1 9/27/2018 Planned Well Summary Well 16-14C We1e Injector Ob'ect ve Sadlerochit Current Status Injector (Shut -In) Estimated Start Date: 02/20/2019 Time to Complete: 24.9 Da s Planned KOP: 7614' MD Planned TD: 16,914' MD / 8,880' TVDss - Rig: Parker 272. GL -RT: 46.94. RTE ref MSL : 84.00 Directional - BHGE WP04 KOP: 7614' MD liorthing Easting Offsets TRS Surface TSAD 5932958.977 3746.1'FSL4753.3' 8,749 Location 5,929,396.430 719,306.300 FEL/ 10N 15E Sec 24 . Planned KOP: 7614' MD Planned TD: 16,914' MD / 8,880' TVDss - Rig: Parker 272. GL -RT: 46.94. RTE ref MSL : 84.00 Directional - BHGE WP04 KOP: 7614' MD Northing Easting TVDss Offsets TRS TSAD 5932958.977 719796.287 8,749 2013.0' FSL 4157 9 10N 15E Sec 13 FEL/ BHL 5937499.017 715224.393 8,880 1403.1' FS L 3313.3' 10N 15E Sec 11 FEL/ Planned KOP: 7614' MD Planned TD: 16,914' MD / 8,880' TVDss - Rig: Parker 272. GL -RT: 46.94. RTE ref MSL : 84.00 Directional - BHGE WP04 KOP: 7614' MD Maximum Hole Angle: -54o in the intermediate section -92 in the production section Close Approach Wells: All offset wells pass BP anti -collision scan criteria, but some offsets must be shut-in to pass scan criteria - reference "Surface and Anti - Collision Issues" section. SurvePro ram: Reference attached directional program. Nearest Pro ert Line: -13,857' Nearest Well within Pool: -126' 16-14C PTD 2 9/27/2018 Formation Tops and Pore Pressure Estimate Farm. Depth De (TV pth Most Likely Pore Pressure (ppg EM SV6 2216 8.4 13-3/8" cs 2608 8.4 SV5 2847 8.4 SV4 3086 8.4 SV3 3617 8.4 SV2 3832 8.4 SV1 4225 8.4 UG4 4735 8.9 UG3 5039 8.9 UG1 5873 8.9 WS2 6690 8.9 WS1 6797 8.9 CM3 6917 9.3 CM2 7575 9.8 CM1 8240 10 THRZ 8544 10 block 8748 10 TSAD 8749 8.19 block 8844 8.19 42N 8845 8.2 block 8884 8.2 42P 8885 8.2 TCGL 8908 8.2 BCGL 8962 8.2 25N 9030 8.2 *toe in 25P 8885 7.32 /b•5/ v -S- 2,C) 16-14C PTD 3 9/27/2018 Casing/Tubing Program Hole Size Casing / Tbg O.D. Wt/Ft Grade Conn Length Top MD / TVDss Bottom MD / TVDss 8-1/2" x 9-7" API FL 26# L-80 Vam Top HC 2,850' 7450'/6787' 10,300' 18756' 7/8" NA <20 8.5-95 CM2 - CM 1 9.8 - 10.2 ' 10-20 (>150'lap) <8 6-1/8" 4 %" 12.6# 13CR-85 Vam HTTC 6,764' 10,150' / 8633' 16,914' / 8880' <20 8.5-9.5 >150' lap) Tubing 4 Yz" 12.6# 13CR-85 Vam Top 1 10,155' 1 Surface 10,155' / 8637' (-5' into liner TBS) Mud Program Intermediate Mud Properties: LSND 6-1/8" Hole Section Depth Interval Density PV (cp) 8-1/2" x Section Hole Depth Interval Density PV (cp) Ib/ P API FL HTHP FL MBT pH KOP - CM3 9.3-95 10-20 20-30 <8 NA <20 8.5-95 CM2 - CM 1 9.8 - 10.2 ' 10-20 20-30 <8 NA <20 8,5-9.5J HRZ - TD 10.4 10-20 20-30 <5 <0 <20 8.5-9.5 Production Mud Properties: Water Based Polymer Fluid 6-1/8" Hole Section Depth Interval Density PV (cp) IWYP API FL HTHP FL MBT pH 7" Shoe - TD 1 8.5-9.O <12 1 12-20 1 <12 1 NA 1 <4 85-9.5 Logging Program 8-1/2" x 9-7/8" Sample Catchers - as Intermediate required by Geology Drilling: Dir/GR/RES Oen Hole: None Cased Hole: Cement Bond Lo 6-1/8" Production I Sample Catchers - as required by Geology Drilling: I Dir/GR/RES - O en Hole: on: Cased Hole: None /dL�% 6�`d/6e See c�%Tae 16-14C PTD 4 9/27/2018 Cement Program Casing Size 7"26#L.80 Vam Top HC Intermediate Liner Lead N/A Lead TOC N/A Basis Tail Oen hole volume + 40% excess + 80' shoe track assumes 150' of 8-1/2" pilot hole Tail TOC 1500' MD above liner shoe Spacer 30 bbls 12.0 ppg Mud Push II Total Cement Lead N/A Volume Tail 96.9 bbls, 544 cult, 465 sks 15.8 lb/gal Class G — 1.17 cuft/sk Temp BHST 185° F Casing Size 4.1/2" 12.8# 13CR-85 HTTC Production Liner Lead N/A Lead TOC N/A Basis Tail Oen hole volume + 30% excess + 80' shoe track + liner la + 200'4" DP x 7" LNR annulus Tail TOC Top of liner Spacer 30 bbls 11.0 ppg Mud Push II Total Cement Lead N/A Volume Tail 152.7 bbls, 857 cult, 680 sks 15.0 lb/gal Class G w/ CaCO3 acid soluble — 1.26 cuft/sk Temp BHST 185° F Surface and Anti -Collision Issues Surface Close Proximity: No wells will be affected by the Parker 272 rig shadow. Sub -Surface Pressure Management: The following wells will be shut-in to prevent direct connection via faulting while drilling: • 03-04 • 03-06 • 03-12 • 03-33 • 03-36 Anti -Collision: All offset wells pass BP anti -collision scan criteria, but some offsets must be shut-in to pass scan criteria: • 03-04: Shut-in during production section drilling • 03-05: Shut-in during production section drilling • 03-12: Shut-in during production section drilling • 03-26: Shut-in during production section drilling Offset well ownership information All offset wells identified within 200 ft of the proposed wellbore are operated by BP 16-14C PTD 5 9/27/2018 Hydrogen Sulfide DS -16 is considered an H2S site. Recent H2S data from the pad is as follows: Faults Formation Where Well Name I H2S Level Date of Reading #1 Closest SHL Well H2S Level 16-28 324 09/29/2005 #2 Closest SHL Well H2S Level 16-15A N/A Suspended #1 Closest BHL Well H2S Level 16-14A N/A Injector #2 Closest BHL Well H2S Level 03-12 260 05/07/2018 #3 Closest BHL Well H2S Level 03-26 450 04/27/2018 #4 Closest BHL Well H2S Level 03-35 200 02/02/2018 Max Recorded H2S on Pad/Facility 16-15 500 05/27/2012 Faults Formation Where MD TVDss Throw Direction and Uncertainty Lost Circ Fault Encountered Intersect Intersect Magnitude Potential Zone 2C 11,050 8,991 15' DTS Med: <300' Low: <25% & >200' Zone 2C 14,900 8,935 10' DTN Low:tt<200 Low: <25% Zone 2C 16,530 8,890 10' DTN Low:fr<200 Low: <25% Drilling Waste Disposal • There is no annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS -04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS -04 for injection. Haul Class I waste to DS -04 and/or Pad 3 for disposal. Contact the GPB Environmental Advisors (659-5893) for guidance. 16-14C PTD 6 9/27/2018 Well Control The 8-1/2" x 9-7/8" and 6-1/8" hole sections will be drilled with well control equipment consisting of 5,000 psi working pressure rams (2), blind/shear rams, and annular preventer capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 4,000 psi (annular to 3,500 psi). BOP test frequency for 16-14C will be 7 days until a window is milled and 14 days thereafter. A function test will be performed every 7 days. Except in the event of a significant operational issue that may affect well integrity or pose safety concerns, an extension to the BOP test period should not be requested. 8-1/2" x 9-7/8" Intermediate Interval Maximum anticipated BHP 3,726 psi at TSAD at 8,749' TVDss 8.19 ppg EMW Maximum surface pressure 2,851 psi at TSAD 0.10psi/ft gas gradient to surface Kick tolerance >25 bbls with 11.5 ppg frac gradient. Kick tolerance Assumes maximum pore pressure (8.96 ppg)' the TSAD and Inte riTest — 6-1/8" hole 10.4 ppg MW. Planned BOP test pressure Rams test to 4,000 psi / 250 psi. Planned completion fluids Annular test to 3,500 psi / 250 psi Inte rit Test— 8-1/2" hole FIT after drilling20'-50' of new hole 7" Casin Test 4,000 psi surface pressure 6-1/8" Production Interval Maximum anticipated BHP 3,834 psi in the SAD at 8,992' TVDss 8.2 ppq EMW Maximum surface pressure 2,935 psi 0.10 psilft gas gradient to surface Kick tolerance Infinite with >9.8 ppg frac gradient. Assumes maximum pore pressure (8.96 ppg) in the SAD and 8.8 ppg MW. Planned BOP test pressure Rams test to 4,000 psi / 250 psi. Annular test to 3,500 psi / 250psi' Inte riTest — 6-1/8" hole FIT after drilling20'-50' of new hole Liner To Packer 4,000 psi surface pressure Planned completion fluids 8.5 ppg seawater / —2,000' TVDss diesel 16-14C PTD 7 9/27/2018 Variance Requests Because the 7" intermediate liner will top set the Sadlerochit and the 4-1/2" liner will be placed within the Zone 2 injection interval, it is requested to set the production packer greater than 200' above the top sliding sleeve. This is a variance from 20 AAC 25.412. The production -- packer is proposed to be set at —10,000' MD (-300' MD above the 7" liner shoe) while the shallowest sliding sleeve is proposed at —10,8 0' MD. ro0ceS! bcYSe V�m C1>L C� LT® t+®Cr CC Prtor o GRl_--v-o �—I�UL A5�, 7a 1 oL .n0 16-14C PTD 8 9/27/2018 Drill and Complete Operations Summary Proposed Drilling Rig Operations 1. MIRU Parker 272. 2. Test BPV from below to 3,500 psi. ✓ ✓ 3. Nipple down dry hole tree. Nipple up BOPE (annular, 4-1/2" x 7" VBR, blind -shear, 2-7/8" x 5" {OGGG VBR) and test to 4,000 psi (annular to 3,500 psi). zI Ad o r n �« v f/ 4. Pull BPV. Circulate out freeze protect with 8.5 ppg seawater. -io t-, �q e5j 5. Pull 4-1/2" tubing from the pre -rig cut at -7,600' MD. 6. Run 9-5/8" mechanical whipstock and 8-1/2" window milling assembly. Orient and set the whipstock on the tubing stub. ------------------------------End of Sundry / Start of Permit to Drill----------------------------- 7. Mill window in the 9-5/8" casing at -7,600' MD plus 20' of new formation. Perform FIT. POOH. �0ir e 8. Run 8-1/2" motor drilling assembly on DP. Include DIR/GR/PWD. Drill to -8,150' MD. POOH. 9. Run 8-1/2" x 9-7/8" RSS drilling assembly with 9-7/8" under -reamer on DP. Include DIR/GR/RES/PWD. Drill to 7" casing point at TSAD (-10,300' MD). Circulate well clean. POOH. 10. Run 7" liner to TD and cement. 11. POOH and LD liner running tool. 12. Pressure test 7" liner to 4,000 psi. Cf%�R7 L D �O'e 30 M"v S 13. Change upper ram to 2-7/8" x 5" VBR and test. 14. Run 6-1/8" motor drilling assembly on DP. Include DIR/GR/RES. 15. Drill out the 7" shoe plus 20' of new formation. Perform FIT. F-/iIQ6�� 16. Drill the 6-1/8" production build to -11,000' MD. POOH. 17. Run 6-1/8" RSS drilling assembly on DP. Include DIR/GR/RES. 18. Drill the 6-1/8" production lateral to TD at -16,914' MD. Circulate well clean, wiper trip as needed and POOH. 19. Run 4-1/2" liner to TD and cement with acid soluble cement. Include -27 NCS Sleeves for future injection stages. Set liner hanger and packer. 7 20. Displace wellbore to clean seawater and POOH. LAG�czEr T1s Dom, l/C 21. Log 7" liner annular cement with CBL (AOGCC injector requirements). z se' xS �TOGinJ 22. Pressure test 4-1/2" liner / liner top packer to 4,000 psi. 2 ;O�lr.rJ G yp�raD %7 23. Run and land 4-1/2" completion.(et packer post -rig) 24. Reverse circulate diesel freeze protection. Allow diesel to U-tube so that T x IA is freeze protected down to -2,000' TVD. 25. Set TWC. 26. Nipple down BOPE. Nipple up adapter flange and dry hole tree and test to 4,500 psi. 27. RDMO Parker 272 Post-Riq Operations 1 V Pull TWC. Tree work as needed. 2 F Circulate completion fluid 3 S Drop B&R 4 F Set packer. MIT -T. MIT -IA - 5 S Pull B&R 6 C Open 2 sleeves near toe. Pump acid to establish ,( _ ( communication with reservoir. (1c7� 7 S SBHPS. Set MCK 8 F AOGCC MIT -IA. V 27 %IOUr �YL-/C�T/Q� 16-14C PTD 9 9/27/2018 16-14C Drillinq Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control / Reservoir Pressures A. Intermediate Hole: The Colville formation is expected to be at 9.3 — 10.0 ppg EMW. The Sadlerochit formation is expected to be at 8.19 ppg EMW at casing point. Pore pressures will be controlled with a 9.3 —10.4 ppg water based mud. B. Production Hole: The Sadlerochit is expected to be at 7.32 — 8.2 ppg EMW. Reservoir pressures will be controlled by using 8.5 — 9.0 ppg water based mud . II. Lost Circulation/Breathing A. Intermediate Hole: There are no expected fault crossings in the intermediate section. Be aware of wellbore breathing risk in the Colville formation. Keep drilling ECDs below hard line. B. Production Hole: There are three expected fault crossings in the production section with low risk of lost circulation. Offset DS -16 wells have experienced only minor lost circulation in this region III. Fault Locations Formation Where MD TVDss Throw Direction and Uncertainty Lost Circ Fault Encountered Intersect Intersect Magnitude N/A Potential Zone 2C 11,050 8,991 15' DTS Med: <300' Low: <25% 260 05/07/2018 #3 Closest BHL Well H2S Level 03-26 & >200' 04/27/2018 Zone 2C 14,900 8,935 10' DTN Low: ft 200 Low: <25% Zone 2C 16,530 8,890 10' DTN Low: ft 200 Low: <25% IV. Integrity Testing Test Point Test Depth Test EMW (lb/gal) 9-5/8" Shoe Window 20'-50' from the 9-5/8" shoe FIT 12.1 ppg 7° Shoe 20'-50' from the 7° shoe FIT 9.8 ppg V. Hydrogen Sulfide / DS -16 is considered an H2S site. Recent H2S data from the pad is as follows: VI. Anti -Collision Issues All offset wells pass BP anti -collision scan criteria, but some offsets must be shut-in to pass scan criteria: • 03-04: Shut-in during production section drilling • 03-05: Shut-in during production section drilling • 03-12: Shut-in during production section drilling • 03-26: Shut-in during production section drilling CONSULT THE DS -16 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. 16-14C PTD 10 9/27/2018 Well Name H2S Level Date of Reading #1 Closest SHL Well H2S Level 16-28 324 09/29/2005 #2 Closest SHL Well H2S Level 16-15A N/A Suspended #1 Closest BHL Well H2S Level 16-14A N/A Injector #2 Closest BHL Well H2S Level 03-12 260 05/07/2018 #3 Closest BHL Well H2S Level 03-26 450 04/27/2018 #4 Closest BHL Well H2S Le el 200 02/02/2018 Max Recorded H2S on Pad/Facility 16-15 500 05/27/2012 VI. Anti -Collision Issues All offset wells pass BP anti -collision scan criteria, but some offsets must be shut-in to pass scan criteria: • 03-04: Shut-in during production section drilling • 03-05: Shut-in during production section drilling • 03-12: Shut-in during production section drilling • 03-26: Shut-in during production section drilling CONSULT THE DS -16 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. 16-14C PTD 10 9/27/2018 16-14C Injector Area of Review The following wellbores are within one-quarter mile 1320 ft of any point alon the planned 16-14C tra ectory within the reservoir section: Top of Oil Top of Oil Top of Well Name Status Pool (TSAD, Pool (TSAD, Top of Top of Cmt Cement Reservoir Zonal Cmt Ops Mechanical MD) TVDss) Cmt (MD)* (TVDss) Determined Status Isolation Summary Integrity B Est. TOC 100 sks 12- P&A (for'A' Volumetrics Paris (annular 13 ppg G 16-14 sidetrack) 9831' 8750' 8443 7575' (no recorded plugged to cement & (lead) & 400 N/A — P&A losses) 8998' MD pert plug) sks 15.8 ppg G tail P&A (for'B' 8773 Cement Penis Est. TOC (annular 288 sks 15.8 16-14A sidetrack) 9903 8760 (TOL) 7849 returns off plugged to cement & ppg G N/A — P&A top of liner 9815' MD erfplug) '( P&A N/A, in- PBA proposed N/A, in -zone N/A, in -zone zone N/A, in -zone N/A, in -zone proposed to N/A, in -zone N/A, in -zone Passing MIT - 16 -14B** (fetrac sidetrack, sidetrack, see sidetrack, sidetrack, sidetrack, plug to • sidetrack, sidetrack, IA to 3700 psi sidetrack) see 16-14A 16-14A see 16- see 16-14A see 16-14A 5' Mpeni 8365' MD see 16-14A see 16-14A (1/22/18) 14A P&A (for 'A' ` Volumetrics Paris Est. TOC (annular 500 sks 15.9 16-17 sidetrack) 10019 8728 8673 7571 (no recorded plugged to cement & ppg G N/A — P&A losses) 9706' MD part plug) N/A, in -zone N/A, in -zone N/A, in- N/A, in -zone N/A, in -zone N/A, in -zone N/A, in -zone Passing MIT - 16 -17A*" Producer sidetrack, sidetrack, see zone sidetrack, sidetrack, sidetrack, Perfs open sidetrack, sidetrack, IA to 2500 psi see 16-17 16-17 see 16-17 see 16-17 see 16-17 see 16-17 see 16-17 (8/20/15) Volumetrics Est. TOC & 800 sks 15.6 Passing CMIT- 03-04 Injector 11792 8751 9292 7286 - (no recorded Perfs open packer @ ppg G TAA to 3652 losses 10739' MD psi 5/21/18 Volumetrics Perfs Est. TOC Partial P&A 03-05 Producer 10294 8675 8448 7244 (no recorded plugged to (annular 900 sks 15.8 with cement losses) 7395' MD cement & ppg G plug at 7395' erfplug) MD 400 sks 12.0 Volumetrics Est. TOC & ppg MTC Passing CMIT- 03-35 Producer 9672 8680 5790 5239 (no recorded Paris open packer @ (lead) & 400 TxIA to 2666 losses) 9311' MD sks 15.8 ppg psi (4/16/18) G tail Volumetrics Est. TOC & sks 15.9 Passing MIT - 03 -26 Producer 10435 8696 9063 7447 (no recorded Paris s open packer @ IA to 2707 psi losses 8497' MD ppg G 12/17/16 Volumetrics Est. TOC & 1500 sks Passing MIT - 09-01A** Producer 10403 8707 7082 6180 (no recorded Paris open packer @ IA to 2500 psi losses 10075' MD 15 G 8 ppg 6/25/15 Volumetrics Est. TOC & 235 sks 15.8 Passing MIT - 03 -33C** InjectorF 10578 867079037 7545 (no recorded Perfs open packer @ IA to 3436 psi losses 10338' MD ppg G 12/6/16 ' Assumes 30% open hole wash-out & 80' shoe track "In -zone sidetrack (listed cement data represents parent wellbore cement status) Volumetrics Est. TOC & 600 sks 15.8 Passing MIT - 03 -12 Injector 9119 8613 8079 7617 (no recorded Perfs open packer @ ppg G IA to 2490 psi losses) 8653' MD 3/11/18 Volumetrics Est. TOC & 500 sks 15.9 Passing CMIT- 03-30 Producer 9140 8643 7811 7389 (no recorded Perfs open packer @ G ppgpsi TAA to 2590 losses 8768' MD 11/27/17 IAxOA Y communication Volumetrics Est. TOC & 115. sks (manageable 03-03 Producer 8690 8627 6472 6409 (no recorded Perfs open p packer @ 15 8 G by bleeds). 1 �4 0 l Fe losses)/ 8229' MD Passing MIT -T to 2569 psi 3L4-S`v -7r Q r G pl e/Yi i L8/if '6E7 l 41 10/5/16 Volumetrics Est. TOC & 231 sks 15.8 Passing MIT - 09 -03A Producer 9013 8633 7494 7256 (no recorded Perfs open packer @ ppg G IA to 3500 psi losses) 8721' MD 3/21/15 Volumetrics Perfs Est. TOC 03-32A P&A (for'B' 9232 8590 7426 6868 (no recorded plugged (annular 285 sks 15.8 N/A — P&A sidetrack) losses) 8571' MDD cement & ppg G erfplug) ' Assumes 30% open hole wash-out & 80' shoe track "In -zone sidetrack (listed cement data represents parent wellbore cement status) P3 -31A aen — _ ss 33 by ° -02AP01 N � 91-03 Aa 0 oAl SOURCES 03-17 aeon MU t me 08 3-33C 1 +40 03-20A.eeao. r n w6 JAPRA 44!709-01`A 1328'Buffer 03•i6C 0340 im 93-30 30 26 \\t 6.20A ec — 03-12A 810346 — 03-30A 4`b eeee 03-06 03-36A 09-19 16.14A 0 03-06 i° s -09 — 16-14C 0]-04 16d5AP81- 16-1 6-16A - 744- " - +J6° 03448 eeor 3-0GA +en -ens Tr6 ♦r i»s z 03.14BL1 zyo 4 e, ne BSAd ' tees 0341 ° -14 s'°7 ane ,03.13 16-18 r I& rsA° a 1 - ] Y tmnn ne / 02 O o] Miles 6s-0zA WORDIMTE SYSTEM by ° -02AP01 N � 4� Aa 0 oAl SOURCES Maln,u,m.eonnne mirn.�neeq nnu ea�me�oeY "16-29APB1 / n.........,.a.,.......,..,.,,.olu,LAMER...........—...............,.. 16-14C Injector Permit Map w6 u 1328'Buffer •� Iw9antl 6.20A ec — 03-12A — 03-30A 09-19 — 83-36A — 16-14C O 1320' Buffer • Wells- Bottom Hole Location Ad. nactive • Ivshak Well Picks - Approved O Wahsolood Boundaries ' WORDIMTE SYSTEM "o. i6-02 4� aria. Za, ua oAl SOURCES Maln,u,m.eonnne mirn.�neeq nnu ea�me�oeY "16-29APB1 / n.........,.a.,.......,..,.,,.olu,LAMER...........—...............,.. rno r •� --- MAP 1 16-1 _ Gray Gen 2 Retro to New Standard NOTE: Below Measurements are Estimated PN 2236000-02-10 MM 509962 New Tree PN 2236000-02-10 MM 509962 93.36" T"50.75" -1/16" 1 RX -39 PN H70525 -65H702 5000# MM 474217 10.5" 13 5/8" o BX -160 178.61" 5000# T PN H-147225-1 0 ,, ''� 12" MM 727334 • I - -0 26.25" 13 5/8" BX -160 5000tt PN N/A MM 25.50, i r 20" RX -74 2000#� ID— PN N/A MM N/A€ j� do-u, o�� (Dt I . � �. � I I 20" 13-3/8" 9-5/8" 4-1/2" Schlumberger -Private Dimensional information reflected on this drawing .,c estimated measurements only. 28 63 a- Weight: 3,200 LBS "MOA40 4-1,1116" 5,000#' ov 0 0 0 9138" Est. 4-1/16" 5.000# 0 n 50.75 L -------j Est. 'fa 7\ 16" 5,00 5,00 00 BP Alaska SK-011583-06 CAMERON #1 -J-6816-4 ,Jeanette ..4-1-05 w by North America - ALASKA - BP PBU 16 16-14 PLAN 16-14C Plan: 16-14C WP04 BP Well Plan Survey Report 27 June, 2018 BA ER 11 ) F IGHES BAT GE company Company: North America - ALASKA - BP Project: PBU Site: 16 Well: 16-14 Wellbore: PLAN 16-14C Design: 16-14C WP04 BP BAT ER BP Well Plan Survey Report UGHES Local Co-ordinate Reference: Well 16-14 TVD Reference: Plan KB (04.00) @ 84 00usft MD Reference: Plan KB (84.00) @ 84.00usft North Reference: - True Survey Calculation Method: Minimum Curvature Database: EDM R5K - Alaska PROD - ANCP1 Project PBU, PBU, PRUDHOE Map System: Alaska NAD27 State Plane Zones System Datum: Mean Sea Level Geo Datum: NAD27' OGP-Usa AK [4267'15864] Using Well Reference Point Map Zone: NAD27' OGP-Usa AK / Alaska zone 4 [26734'1586 Using geodetic scale factor She 16, TR -10-15 She Position: From: Map Position Uncertainty: 0.00 usft Well 1614, 16-14 Well Position -NI-S 0.00 usft +EI -W 0.00 usft Position Uncertainty 0.00 usft Wellbore PLAN 16-14C Magnetics Model Name BGGM2018 Design 16-14C WP04 Audit Notes: Version: Vertical Section: Sample Date 4/1/2019 Phase: Depth From (TVD) (usft) 46.27 Northing: Easting: Slot Radius: Northing: Easting: Wellhead Elevation: Declination 1°) 17.03 PIAN . W -S (usft) 0.00 5,927,441.990 usft Latitude: 718,969.880 usft Longitude: 0.000 in Grid Convergence: 5,929,396.430 usft Latitude: 719,306.300 usft Longitude: 37.73 usft Ground Level: Dip Angle 1°I 80.91 Tie On Depth: +EI -W (usft) 0.00 Field Strength InT) 57,420 592.85 Direction 1°) 334.93 70° 12' 15.545 N 146° 14'4.567 W 1.66 ° 70' 12'34.664 N 148° 13'53 161 W 37.06 usft 6/272018 1:35.36PM Page 2 COMPASS 5000.1 Build 81D BP BAKER by BP Well Plan Survey Report JUGHES Company: North America - ALASKA - BP Project: PBU BLIND Site: 16 MWD Well: 16-14 MWD+IFR+MS-WOCA Wellbore: PLAN 16-14C Design: 16-14C WP04 Survey Tool Program Date 6/27/2018 From To (usft) (usft) Survey(Wellbom) 117.90 7,592.85 16-14 GyroData (16-14) 7,592.85 8,150.00 16-14C WP04 (PLAN 16-14C) 8,150.00 10,300.00 16-14C WP04 (PLAN 16-14C) 8,150.00 10,300.00 16-14C WP04 (PLAN 16-14C) 10,300.00 16,913 76 16-14C WP04 (PLAN 16-14C) 10,300.00 16,913.76 16-14C WP04 (PLAN 16-14C) Planned Survey 720,034.517 MD Inc AN (usft) 11 P) 7,592.85 39.90 20.88 16.146 Actual Survey - TIP 7,600.00 39.94 20.88 7,614.00 40.03 2088. Start DLS 12.60 TFO.50.00 - KOP - 9 5/8" Planned KOP 7,619.89 40.51 20.01 CM3 720,038.703 7,630.00 41.34 18.56 Start 20.00 hold at 7630.00 MD 7,650.00 41.34 18.56 Start DLS 3.00 TFO .55.33 7,700.00 42.21 16.72 7,800.00 44.03 13.23 7,900.00 45.95 9.97 8,000.00 47.95 6.92 8,100.00 50.03 4.05 8,200.00 52.18 1.36 8,267.77 53.67 359.63 Start 756.40 hold at 8267.77 MD 8,300.00 53.67 35963 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Tool Name Description GVD-CT-CMS Gyrodata contcasing m/s BLIND Blind drilling MWD MWD. Standard MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal MWD MWD -Standard MWD+IFR+MS-WOCA MWD + IFR +Multi Station W/O Crustal Well 16-14 Plan KB (84.00) @ 84.00usft Plan KB (84.00) @ 84.00usft True Minimum Curvature EDM R5K - Alaska PROD - ANCP1 TVD TVDSS NIS EM/ Northing Easting DLeg TFace (usft) (usft) (usft) (usft) (usft) (usft) (°1100usft) (°) 6,980.30 6,896.30 1,676.79 775.76 5,931,094.969 720,033.007 0.00 0.00 6,985.78 6,901.78 1,681.08 77740 5,931,099.302 720,034.517 0.61 0.00 6,996.51 6,912.51 1,689.49 780.61 5,931,107.797 720,037.478 0.61 0.00 7,001.00 6,917.00 1,693.05 78193 5,931,111.398 720,038.703 12.50 -50.00 7,008.64 6,924.64 1,699.30 784.12 5,931,117.712 720,040.708 12.50 -49.34 7,023.66 6,939.66 1,711.83 788.33 5,931,130.352 720,044.547 0.00 0.00 7,060.95 6,976.95 1,743.57 798.42 5,931,162.371 720,053.710 3.00 -55.33 7,133.95 7,049.95 1,809.58 816.04 5,931,228.864 720,069.410 3.00 -53.96 7,204.69 7,120.69 1,878.82 830.22 5,931,298.477 720,081.572 3.00 -51.41 7,272.96 7,188.96 1,951.08 840.92 5,931,371.020 720,090.163 3.00 -49.10 7,338.58 7,254.58 2,026.18 848.10 5,931,446.295 720,095.160 3.00 -47.01 7,401.37 7,317.37 2,103.91 851.75 5,931,524.093 720,096.549 3.00 -45.14 7,442.23 7,358.23 2,157.98 852.20 5,931,578.146 720,095.437 3.00 -43.44 7,461.32 7,377.32 2,183.94 852.03 5,931,604.092 720,094.514 0.00 0.00 6/272018 1:35:36PM Page 3 COMPASS 5000.1 Build 81D by BP Well BP Plan Survey Report BAKER gUGHES Company: North America - ALASKA -BP Local Co-ordinate Reference: Well 16-14 Project: PBU TVD Reference: Plan KB (84.00) @ 84.00usft Site: 16 MD Reference: Plan KB (84.00) @ 84.00usft Well: 16-14 North Reference: True Wellbore: PLAN 16-14C Survey Calculation Method: Minimum Curvature Design: 16-14C WP04 Database: EDM R5K - Alaska PROD - ANCP1 Planned Survey MD Inc Azl TVD TVDSS NIS EIW Northing Easling DLeg TFace (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) ('1100usft) (°) 8,400.00 53.67 359.63 7,520.56 7,436,56 2,264.50 851.51 5,931,684.599 720,091.649 0.00 0.00 8,500.00 53.67 359.63 7,579.81 7,495.81 2,345.06 850.98 5,931,765.106 720,088.784 0.00 0.00 8,600.00 53.67 359.63 7,639.05 7,555.05 2,425.62 850.46 5,931,845.613 720,085.920 0.00 0.00 8,633.67 53.67 359.63 7,659.00 7,575.00 2,452.75 850.28 5,931,872.723 720,084.955 0.00 0.00 CM2 8,700.00 53.67 359.63 7,698.29 7,614.29 2,506.18 649.93 5,931,926.120 720,083.055 0.00 0.00 8,800.00 53.67 359.63 7,757.54 7,673.54 2,586.74 849.41 5,932,006.627 720,080.190 0.00 0.00 8,900.00 53.67 359.63 7,816.78 7,732.78 2,667.30 848.88 5,932,087.134 720,077.326 0.00 0.00 9,000.00 53.67 359.63 7,876.03 7,792.03 2,747.86 846.36 5,932,167.641 720,074.461 0.00 0.00 9,024.17 53.67 359.63 7,890.35 7,806.35 2,767.33 848.23 5,932,187.101 720,073.769 0.00 0.00 Start DLS 3.00 TFO .139.88 9,100.00 51.94 357.76 7,936.18 7,852.18 2,827.71 846.87 5,932,247.416 720,070.652 3.00 -139.88 9,200.00 49.72 355.17 7,999.35 7,915.35 2,905.08 842.12 5,932,324.608 720,063.661 3.00 -138.76 9,300.00 47.55 35241 8,065.44 7,981.44 2,979.67 834.03 5,932,398.934 720,053.412 3.00 -137.12 9,400.00 45.46 34845 8,134.27 8,050.27 3,051.29 822.63 5,932,470.186 720,039.932 3.00 -135.29 9,500.00 43.44 346.27 8,205.67 8,121.67 3,119.74 807.93 5,932,538.177 720,023.258 3.00 -133.25 9,600.00 41.53 342.85 8,279.42 8,195.42 3,184.83 789.99 5,932,602.713 720,003.436 3..00 -130.98 9,659.05 40.44 340.71 8,324.00 8,240.00 3,221.62 777.89 5,932,639.131 719,990.274 3.00 -128.46 CM1 9,700.00 39.72 339.17 8,355.33 8,271.33 3,246.38 768.86 5,932 663 620 719,980.521 3.00 -126.85 9,800.00 38.03 335.22 8,433.19 8,349.19 3,304.22 744.58 5,932,720.732 719,954.575 3.00 -125.67 9,900.00 36.49 330.96 8,512.79 8,428.79 3,358.20 717.23 5,932,773.890 719,925.669 3.00 -122.59 10,000.00 35.11 326.41 8,593.91 8,509.91 3,408.17 686.88 5,932,822.950 719,893.882 3.00 -119.20 10,008.66 35.00 326.00 8,601.00 8,517.00 3,412.30 684.11 5,932,827.003 719,890.996 3.00 -115.51 Start 291.28 hold at 10008.66 MD 10,041.62 35.00 326.00 8,628.00 8,544.00 3,427.97 673.54 5,932,842.362 719,879.974 0.00 0.00 TNR2 10,100A0 35.00 326.00 8,675.82 8,591.82 3,455.73 654.81 5,932,869.564 719,860.453 0.00 0.00 6/272018 1:35.36PM Page 4 COMPASS 5000.1 Build BID 0 flBP BAKER bp BP Well Plan Survey Report gYGHES Company: North America -ALASKA -BP Project: PBU Site: 16 Well: 16-14 Wellbore: PLAN 16-14C Design: 16-14C WP04 Planned Survey TVD MD Inc NIS (usft) n Northing 10,200.00 35.00 10,261.36 35.00 BHRZ (usft) 10,291.88 35.00 LCUITSAD (usft) 10,299.94 35.00 Start 40.00 hold at 10299.94 MD 10,300.00 35.00 7- 622.74 10,339.94 35.00 Start Build 12.00 0.00 10,400.00 42.21 10,413.30 43.80 42N 5,932,944.756 10,500.00 54.21 10,510.78 55.50 TCGL 8,749.00 10,600.00 66.21 10,628.21 69.59 BCGL 0.00 10,700.00 78.21 10,798.27 90.00 Start 300.00 hold at 10798.27 MD 10,800.00 90.00 10,900.00 90.00 11,000.00 90.00 11,098.27 90.00 Start DLS 2.00 TFO 27.89 5,932,962.760 11,100.00 90.03 6/27/2018 1:35.56PM Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 16-14 Plan KB (84.00) @ 84.00usft Plan KB (84.00) @ 84.00usft True Minimum Curvature EDM RSK - Alaska PROD - ANCP1 Ai TVD TVDSS NIS EIW Northing Easting DLeg TFace (°) (usft) (usft) (usft) (usft) (waft) (usft) (°I100usft) (°) 326.00 8,757.73 8,673.73 3,503.28 622.74 5,932,916.162 719,827.013 0.00 0.00 326.00 8,808.00 8,724.00 3,532.46 603.06 5,932,944.756 719,806.493 0.00 0.00 326.00 8,833.00 8,749.00 3,546.98 593.27 5,932,958.977 719,798.287 0.00 0.00 326.00 8,839.60 8,755.60 3,550.81 590.69 5,932,962.732 719,793.593 0.00 0.00 326.00 8,839.65 8,755.65 3,550.84 59067 5,932,962.760 719,793.573 0.00 0.00 326.00 6,872.37 8,788.37 3,569.83 577.86 5,932,981.371 719,780.217 0.00 0.00 326.00 8,919.27 8,835.27 3,600.87 558.92 5,933,011.795 719,758.384 12.00 0.00 326.00 8,929.00 8,845,00 3,608.40 551.84 5,933,019.167 719,753.094 12.00 0.00 328.00 8,985.79 8,901.79 3,662.57 515.30 5,933,072.254 719,714.997 12.00 0.00 326.00 8,992.00 8,908.00 3,669.88 510.37 5,933,079.417 719,709.857 12.00 0.00 326.00 9,035.39 8,951.39 3,734.39 466.86 5,933,142.629 719,664.494 12.00 0.00 326.00 9,046.00 8,962.00 3,756.05 452.25 5,933,163.858 719,649.260 12.00 0.00 326.00 9,065.89 8,981.89 3,813.18 413.71 5,933,219.843 719,609.084 12.00 0.00 326.00 9,075.97 8,991.97 3,894.08 359.15 5,933,299.118 719,552.194 12.00 0.00 326.00 9,075,97 8,991.97 3,895.51 358.18 5,933,300.521 719,551.187 0.00 0.00 326.00 9,075.97 8,991.97 3,978.41 302.26 5,933,381.763 719,492.886 0.00 0.00 326.00 9,075.97 8,991.97 4,061.32 246.34 5,933,463.004 719,434.585 0.00 0.00 326.00 9,075.97 8,991.97 4,142.79 191.39 5,933,542.842 719,377.291 0.00 0.00 326.02 9,075.97 8,991.97 4,144.22 190.42 5,933,544.245 719,376.285 2.00 27.89 Page 5 COMPASS 5000.1 Build 81D EEO Company: North America - ALASKA - BP Project: PBU Site: 16 Well: 16-14 Wellbore: PLAN 16-14C Design: 16-14C WP04 Planned Survey MD Inc (usft) V) 11,129.28 90.55 Start 2210.06 hold at 11129.28 MD 11,200.00 90.55 11,300.00 90.55 11,400.00 90.55 11,500.00 90.55 11,600.00 90.55 11,700.00 90.55 11,800.00 90.55 11,900.00 90.55 12,000.00 90.55 12,100.00 90.55 12,200.00 90.55 12,300.00 90.55 12,400.00 90.55 12,500.00 90.55 12,600.00 90.55 12,700.00 90.55 12,800.00 90.55 12,900.00 90.55 13,000.00 90.55 13,100.00 90.55 13,200.00 90.55 13,300.00 90.55 13,339.34 90.55 Start DLS 3.00 TFO .88.65 13,400.00 90.59 BP BAKER BP Well Plan Survey Report HUGHES Local Co-ordinate Reference: Well 16-14 TVD Reference: Plan KB (84.00) @ 84.00usft MD Reference: Plan KB (84.00) @ 84.00usft North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM R5K - Alaska PROD - ANCP1 Azi TVD TVDSS NIS ENV Northing Easting DLeg. TFace V) (wft) (usR) )usR) (usft) )usft) (usft) (°NOOusft) n 326.29 9,075.82 8,991.82 4,168.54 174.12 5,933,568.076 719,359.279 2.00 27.89 326.29 9,075.14 8,991.14 4,227.36 13487 5,933,625.737 719,318.341 0.00 0.00 326.29 9,074.19 8,990.19 4,310.55 79.37 5,933,707.268 719,260.455 0.00 0.00 326.29 9,073.23 8,989.23 4,393.73 23.88 5,933,788.800 719,202.569 0.00 0.00 326.29 9,072.27 8,988.27 4,476.91 -31.62 5,933,870.331 719,144.683 0.00 0.00 326.29 9,071.32 8,987.32 4,560.09 -87.12 5,933,951.863 719,086.797 0.00 0.00 326.29 9,070.36 8,986.36 4,643.27 -142.61 5,934,033.394 719,028.911 0,00 0.00 326.29 9,069.40 8,985.40 4,726.46 -198.11 5,934,114.926 718,971.025 0.00 0.00 326.29 9,068.45 8,984.45 4,809.64 -253.61 5,934,196.457 718,913.139 0,00 0.00 326.29 9,067.49 8,983.49 4,892.82 -309.10 5,934,277.989 718,855.253 0.00 0.00 326.29 9,066.53 8,982.53 4,976.00 -364.60 5,934,359.520 718,797.367 0.00 0.00 326.29 9,065.58 8,981.58 5,059.18 -420.09 5,934,441.052 718,739.481 0.00 0.00 326.29 9,064.62 8,980.62 5,142.37 -475.59 5,934,522.583 718,681.595 0.00 0.00 326.29 9,063.67 8,979.67 5,225.55 -531.09 5,934,604.115 718,623.709 0.00 0.00 326.29 9,062.71 8,978.71 5,308.73 -586.58 5,934,685.646 718,565.823 0.00 0.00 326.29 9,061.75 8,977.75 5,391.91 -642.08 5,934,767.178 718,507.937 0.00 0.00 326.29 9,060.80 8,976.80 5,475.10 -697.58 5,934,848.709 718,450.051 0.00 0.00 326.29 9,059.84 8,975.84 5,558.28 -753.07 5,934,930.241 718,392.165 0.00 0.00 326.29 9,058.88 8,974.88 5,641.46 -808.57 5,935,011.773 718,334.279 0.00 0.00 326.29 9,057.93 8,973.93 5,724.64 -864.06 5,935,093.304 718,276.393 0.00 0.00 326.29 9,056.97 8,972.97 5,807.82 -919.56 5,935,174.836 718,218.507 0.00 0.00 326.29 9,056.01 8,972.01 5,891.01 -975.06 5,935,256.367 718,160.621 0.00 0.00 326.29 9,055.06 8,971.06 5,974.19 -1,030.55 5,935,337.899 718,102.735 0.00 0.00 325.29 9,054.68 8,970.68 6,006.91 -1,052.39 5,935,369.974 718,079.962 0.00 0.00 324.47 9,054.08 8,97008 6,056.83 -1,086.84 5,935,416.864 718,044.070 3.00 -88.65 6/272018 1:35.36PM Page 6 COMPASS 5000.1 Build 81D b BP BAKERp BP Well Plan Survey Repoli UGHES 1 11 Company: North America - ALASKA - BP Project: PBU Site: 16 Well: 16-14 Wellbore: PLAN 16-14C Design: 16-14C WP04 Planned Survey MD Inc Azi (usft) NIS 13,500.00 90.66 13,600.00 90.73 13,700.00 90.79 13,800.00 90.85 13,900.00 90.91 14,000.00 90.97 14,049.10 91.00 Start DLS 2.00 TFO 68.88 14,100.00 91.37 14,135.25 91.62 Start 2778.52 hold at 14135.25 MD 14,200.00 91.62 14,300.00 91.62 14,400.00 91.62 14,500.00 91.62 14,600.00 91.62 14,700.00 91.62 14,800.00 91.62 14,900.00 91.62 15,000.00 91.62 15,100.00 91.62 15,200.00 91.62 15,300.00 91.62 15,400.00 91.62 15,500.00 91.62 15,600.00 91.62 15,700.00 91.62 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 1614 Plan KB (84.00) @ 84.00usft Plan KB (84.00) @ 84.00usft True Minimum Curvature EDM R5K - Alaska PROD - ANCP1 306.51 TVD TVDSS NIS -1,667.48 EM Northing Eastng DLeg TFace 9,038,35 (usft) (usft) (usft) 5,936,002.602 (usft) (usft) (usft) (°/100u3ft) (°) 321.47 9,052.99 8,968.99 6,136.65 717,284.047 -1,147,06 5,935,496.898 717,981.569 3.00 -88.67 318.47 9,051.78 8,967.78 6,213.20 0.00 -1,211.36 5,935,571.553 717,915,071 3.00 -88.70 31547 9,050.45 8,966.45 6,286.29 0.00 -1,279.56 5,935,642.625 717,844.759 3.00 -88.74 312.47 9,049.02 8,965.02 6,355.71 306.61 -1,351.53 5,935,709.919 717,770.825 3.00 -88.78 309.47 9,047.47 8,963.47 6,421.26 9,021.39 -1,427.02 5,935,773.251 717,693.472 3.00 -88.82 306.47 9,045.83 8,961.83 6,482.78 8,934.56 -1,505.83 5,935,832.447 717,612.912 3.00 -88.87 305.00 9,044.98 8,960.98 6,511.45 7,136.91 -1,545.68 5,935,859.951 717,572.247 3.00 -88.92 305.95 9,043.93 8,959.93 6,540.98 -2,469.90 -1,587.12 5,935,888.265 717,529.970 2.00 68.88 306,61 9,043.01 8,959.01 6,561.83 5,936,575.116 -1,615.52 5,935,908.278 717,500.975 2.00 68.90 306.51 9,041.18 8,957.18 6,600.43 -1,667.48 5,935,945.351 717,447.918 0.00 0.00 306.61 9,038,35 8,954.35 6,660.04 -1,74272 5,936,002.602 717,365.982 0.00 0,00 30661 9,035.52 8,951.52 6,719.65 -1,827.97 5,936,059.854 717,284.047 0.00 0.00 306.61 9,032.70 8,948.70 6,779.26 -1,908.21 5,936,117.105 717,202.112 0.00 0.00 306.61 9,029.87 8,945.87 6,838.87 -1,988.45 5,936,174.357 717,120.177 0.00 0.00 306.61 9,027.04 8,943.04 6,898.48 -2,068.69 5,936,231.608 717,038.242 0.00 0.00 306.61 9,024.21 8,940.21 6,958.09 -2,148.93 5,936,288.859 716,956.306 0.00 0.00 306.61 9,021.39 8,937.39 7,017.70 -2,229.17 5,936,346.111 716,874.371 0.00 0.00 306.61 9,018.56 8,934.56 7,077.30 -2,309.42 5,936,403.362 716,792.436 0.00 0.00 306.61 9,015.73 8,931.73 7,136.91 -2,389.86 5,936,460.614 716,710.501 0.00 0.00 306.61 9,012.91 8,928.91 7,196.52 -2,469.90 5,936,517.865 716,628.566 0.00 0,00 306.61 9,010.08 6,926.08 7,256.13 -2,550.14 5,936,575.116 716,546.631 0.00 0.00 306.61 9,007.25 8,923.25 7,315.74 -2,630.38 5,936,632.368 716,464.695 0.00 0.00 306.61 9,004.42 8,920.42 7,375.35 -2,710.62 5,936,689.619 716,382.760 0.00 0.00 306.61 9,001.60 8,917.60 7,434.96 -2,790.86 5,936,746.871 716,300.825 0.00 0.00 306.61 8,998.77 8,914.77 7,494.57 -2,871.11 5,936,804.122 716,218.890 0.00 0.00 6272018 1:35:36PM Page 7 COMPASS 5000 1 Build 81D by TVD Company: North America - ALASKA - BP Project: PBU Northing Site: 16 DLeg Well: 16-14 ('j Wellbore: PLAN 16-14C (usft) Design: 16-14C WP04 (usft) Planned Survey (usft) MD Inc (°) (usft) r) 8,995.94 15,800.00 91.62 15,900.00 91.62 16,000.00 91.62 16,100.00 91.62 16,200.00 91.62 16,300.00 91.62 16,400.00 91.62 16,500.00 91.62 16,600.00 91.62 16,700.00 91.62 16,800.00 91.62 16,900.00 91.62 16,913.76 91.62 TD at 16913.76 - 4 112' 8,903.46 Casing Points -3,192.07 BP BP Well Plan Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: BAKER JUGHES Well 16-14 Plan KB (84.00) @ 84.00usft Plan KB (84.00) @ 84.00usft True Minimum Curvature EDM R5K - Alaska PROD - ANCP1 AS TVD TVDSS N/S ENV Northing Easting DLeg TFace ('j (usft) (usft) (usft) (usft) (usft) (usft) r/100usf) (°) 306.61 8,995.94 8,911.94 7,554.18 -2,951.35 5,936,861.373 716,136.955 0.00 0.00 306.61 8,993.11 8,909.11 7,613.79 -3,031.59 5,936,918.625 716,055.019 0.00 0.00 306.61 8,990.29 8,906.29 7,673.40 -3,111.83 5,936,975:876 715,973.084 0.00 0.00 306.61 8,987.46 8,903.46 7,733.01 -3,192.07 5,937,033.128 715,891.149 0.00 0.00 306.61 6,984.63 8,900.63 7,792.62 -3,272.31 5,937,090.379 715,809.214 0.00 0.00 306.61 8,981.80 8,897.80 7,852.23 -3,352.56 5,937,147631 715,727.279 0.00 0.00 306.61 6,978.98 8,894.98 7,911.84 -3,432.80 5,937,204.882 715,645.343 0.00 0.00 306.61 8,976.15 8,892.15 7,971.45 -3,513.04 5,937,262.133 715,563.408 0.00 0.00 306.61 8,973.32 8,889.32 8,031.06 -3,593.28 5,937,319.385 715,481.473 0.00 0.00 306.61 8,970.49 8,886.49 8,090.67 -3,673.52 5,937,376.636 715,399.538 0.00 0.00 306.61 8,967.67 6,883.67 8,150.26 -3,753.76 5,937,433.888 715,317.603 0.00 0.00 306.61 8,964.84 8,880.84 8,209.89 -3,834.01 5,937,491.139 715,235.667 0.00 0.00 306.61 8,964.45 - 8,880.45 8,218.09 -3,845.05 5,937,499.017 715,224.393 0.00 0.00 Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (In) (in) 10,300.00 8,839.65 7' 7.000 9.875 16,913.76 8,964.45 41/2' 4.500 6.125 7,614.00 6,996.51 95/8"Planned KOP 9,625 12.250 6127/2018 1:3596PM Page 8 COMPASS 5000.1 Build 81D ElP BA. ICER by BP Well Plan Survey Report UGHES Company: North America - ALASKA - BP Local Coordinates Local Co-ordinate Reference: Well 16-14 Project: PBU (usft) (usft) TVD Reference: Plan KB (84.00) @ 84.00usft Site: 16 1,676.79 775.76 MD Reference: Plan KB (84.00) @ 84.00usft Well: 16-14 7,630.00 7,008.64 North Reference: True Wellbore: PLAN 16.14C 1,711.83 788.33 Survey Calculation Method: Minimum Curvature Design: 16-14C WP04 9,024.17 7,890.35 Database: EDM R5K - Alaska PROD - ANCP7 Formations 8,601.00 3,412.30 684.11 10,299.94 8,839.60 3,550.81 Measured Vertical 8,872.37 Dip 577.66 10,798.27 Depth Depth 359.15 Dip Direction 9,075.97 4,142.79 (usft) (usft) Name Lithology 174.12 13,339.34 9,659.05 8,324.00 CM1 14,049.10 9,044.98 6,511.45 10,261.36 8,808.00 BHRZ 6,561.83 -1,615.52 16,913.76 10,628.21 9,046.00 BCGL 10,510.78 8,992.00 TCGL 7,619.89 7,001.00 CM3 8,633.87 7,659.00 CM2 10,413.30 8,929.00 42N 10,041.62 8,628.00 THRZ 10,291.88 8,833.00 LCU?SAD Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +EI -W (usft) (usft) (usft) (usft) 7,592.85 6,980.30 1,676.79 775.76 7,614.00 6,996.51 1,689.49 780.61 7,630.00 7,008.64 1,699.30 784.12 7,650.00 7,023.66 1,711.83 788.33 8,267.77 7,442.23 2,157.98 852.20 9,024.17 7,890.35 2,767.33 848.23 10,008.86 8,601.00 3,412.30 684.11 10,299.94 8,839.60 3,550.81 590.69 10,339.94 8,872.37 3,569.83 577.66 10,798.27 9,075.97 3,894.08 359.15 11,098.27 9,075.97 4,142.79 191.39 11,129.28 9,075.82 4,168.54 174.12 13,339.34 9,054.68 6,006.91 -1,052.39 14,049.10 9,044.98 6,511.45 -1,545.68 14,135.25 9,043.01 6,561.83 -1,615.52 16,913.76 8,964.45 8,218.09 -3,845.05 Comment 16-146 Actual Survey - TIP Start OLS 12.50 TFO -50.00 - KOP Start 20.00 hold at 7630.00 MD Start OLS 3.00 TFO -55.33 Start 756.40 hold at 8267.77 MD Start OLS 3.00 TFO -139.88 Start 291.28 hold at 10008.66 MD Start 40.00 hold at 10299.94 MD Start Build 12.00 Start 300.00 hold at 10798.27 MD Start OLS 2.00 TFO 27.89 Start 2210.06 hold at 11129.28 MD Start DLS 3.00 TFO -88.65 Start US 2.00 TFO 68.88 Start 2778.52 hold at 14135.25 MD TD at 16913.76 62712018 1: 35:36PM Page 9 COMPASS 5000.1 Build 61D BP BAKER by BP Well Plan Survey Report JUGHES Company: North America -ALASKA - BP Local Co-ordinate Reference: Well 16-14 Project: PBU ND Reference: Plan KB (84.00) @ 84.00usft Site: 16 MD Reference: Plan KB (84.00) @ 84.00usft Well: 16-14 North Reference: True Wellbore: PLAN 16-14C Survey Calculation Method: Minimum Curvature Design: 16-14C WP04 Database: EDM R5K- Alaska PROD - ANCP1 Checked By: Approved By: Date: 6/272018 1:35..36PM Page 10 COMPASS 5000.1 Build 81D North America - ALASKA - BP PBU 16 16-14 PLAN 16-14C 16-14C WP04 Anticollision Summary Report 27 June, 2018 BA ER BAT a GE company BP BA, ICER bp Anticollision Report rjUGHES 0 GEaanpaw Company: North America - ALASKA - BP Project: PBU Reference Site: 16 Site Error: O.00usft Reference Well: 16-14 Well Error: O.00usft Reference Wellbore PLAN 16-14C Reference Design: 16-14C WP04 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output emors are at Database: Offset TVD Reference: Well 16-14 Plan KB (84.00) @ 84.00usft Plan KB (84.00) @ 84.00usft True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference 16-14C WP04 From Filter type: NO GLOBAL FILTER. Using user defined selection 8 filtering criteria (usft) Survey (Wellbore) Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,592.8510 16,913.76usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,886.75usft Error Surface: Elliptical Conic Survey Tool Program Date 6/27/2018 From To (usft) (usft) Survey (Wellbore) 117.90 7,592.85 16-14 GymData (16-14) 7,592.85 8,150.00 16-14C WP04 (PLAN 16-14C) 8,150.00 10,300.00 16-14C WP04 (PLAN 16-14C) 8,150.00 10,300.00 16-14C WP04 (PLAN 16-14C) 10,300.00 16,913.76 16-14C WP04 (PLAN 16-14C) 10,300.00 16,913.76 16-14C WP04 (PLAN 16-14C) Tool Name Description GVD-CT-CMS Gyrodata contcasing m/s BLIND Blind drilling MWD MWD- Standard MWD+IFR+MS-WOCA MWD + IFR +Multi Station W/O Crustal MWD MWD - Standard MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 6/272018 11,1602AM Page 2 of 4 COMPASS 5000.1 Build 61D BP by Anticollision Report BAF�UGHES GE company Company: North America - ALASKA - BP Project: PBU Reference Site: 16 Site Error: O.00usft Reference Well: 16-14 Well Error: O.00usft Reference Wellbore PLAN 16-14C Reference Design: 16-14C WP04 Summary Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well 16-14 Plan KB (84.00) @ 84.00usft Plan KB (84.00) @ 84.00usft True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum 09 09-01 - 09-01 A - 09-01A 09.01 - 09-01APB1 - 09-01APB1 09-03 - 09-03A - 09-03A 09-03 - 09-03A - Plan#7 09-03AApproved 16 16-11 - 16.11 - 16-11 16-12 - 16-12 - 16-12 16-13 - 16-13 - 16-13 16-13 - 16-13PBI - 16-13PBi 18-13 - 16-13PB2 - 16-13PB2 16-14 - 16-14 - 16-14 16-14 - 16-14A- 16-14AyrZ. n 16-14 - 16-148 - 16-146 16-15 -16-15 - 16-15 16-15 - 16-15A- 16-15A 16-15 - 16-15APB1 - 16-15APB1 16-17 -16-17 - 16-17 16-17 - 16-17A- 16-17A 16-18 - 16-18 -16-18 16-28 - 16-28 - 16-28 13,642.85 Reference Offset Centre to No -Go Allowable Pass - Major Risk 13,684.15 Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Pass - Major Risk Offset Well - Wellbore - Design (usft) (usft( (usft) 230.90 (usft) Pass - Major Risk 03 Out of range 03-04 - 03-04 - 03-04 /®_ 12,081.97 11,800.00 754.23 30.59 753.72 Pass - Minor 1/100 03-05-03-05-03-05 13,113.59 10,700.00 668.76 33.75 659.91 Pass - Minor 1/100 03-12-03-12-03-12 (jv ��(a/2/�..-r15,999.10 9,475.00 411.71 51.74 410.89 Pass Minor V700 03 -12 -PLAN 03 -12A -03-12A WP04 �r h18,098.82 9,325.00 441.34 55.47 440,37 Pass Minor 1/100 03-26 - 03-26 - 03-26 OG �// <J X13 829 11 10 675 00 622.27 27.97 621 T+ Paee _ na'nn. vmn_ 03-30-03-30-03-30 15,827.01 9,475.00 881.24 575.78 305.79 Pass - Major Risk 03 -30 -Plan 03 -30A -03-30A WP12 16,688.54 9,525.00 683.44 635.64 49.80 Pass - Major Risk 03 -33 -03 -33C -03-33C 14,772.76 14,204.00 697.61 548.86 172.62 Pass - Major Risk 03-35-03-35-03-35 14,132.36 9,950.00 744.77 315.47 430.23 Pass - Major Risk 03 -35 -PLAN 03-35-03-35A WP01 14,173.88 9,850.00 760.55 314.61 450.23 Pass - Major Risk 03 -36 -03 -36A -03-36A 16,889.31 9,82500 1,423.77 540.69 96547 Pass - Major Risk 03-36 - 03-36A - Plan #6 16,885.80 9,699.98 1,407.99 560.97 953.37 Pass - Major Risk 09 09-01 - 09-01 A - 09-01A 09.01 - 09-01APB1 - 09-01APB1 09-03 - 09-03A - 09-03A 09-03 - 09-03A - Plan#7 09-03AApproved 16 16-11 - 16.11 - 16-11 16-12 - 16-12 - 16-12 16-13 - 16-13 - 16-13 16-13 - 16-13PBI - 16-13PBi 18-13 - 16-13PB2 - 16-13PB2 16-14 - 16-14 - 16-14 16-14 - 16-14A- 16-14AyrZ. n 16-14 - 16-148 - 16-146 16-15 -16-15 - 16-15 16-15 - 16-15A- 16-15A 16-15 - 16-15APB1 - 16-15APB1 16-17 -16-17 - 16-17 16-17 - 16-17A- 16-17A 16-18 - 16-18 -16-18 16-28 - 16-28 - 16-28 13,642.85 11,775.00 1,125.00 307.94 83420 Pass - Major Risk 13,684.15 11,830.00 1,124.87 303.72 832.59 Pass - Major Risk 16,907.83 11,200.00 1,574.37 257.21 1,316.94 Pass - Major Risk 16,912.46 11,150.00 1,593.04 230.90 1,361.78 Pass - Major Risk Out of range Out of range 7,592.85 7,425.00 1,425.54 581.43 1,329.39 Pass - Major Risk 7,592.85 7,425.00 1,425.54 581.43 1,329.39 Pass - Major Risk 7,592.85 7,425.00 1,425.54 581.59 1,329.24 Pass -Major Risk 7,91061 7,900.00 29.35 0.00 29.35 Pass-NOERRORS 7,914.34 7,900.00 30.05 0.00 30.05 Pass-NOERRORS ✓ 7,913.52 7,900.00 29.89 0.00 29.89 Paw -NOERRORS Out of range Out of range Out of range 11,426.46 10,450.00 779.10 189.73 589.36 Pass - Major Risk 11,367.57 10,175.00 840.75 186.57 658.53 Pass - Major Risk 7,603.84 7,950.00 1,268.92 170.00 1,112.38 Pass - Major Risk Out of range 6/272018 11: 15,02AM Page 3 of COMPASS 5000.1 Build 81D BP BA ER 0 by Anticollision Report IUGHES GE cwn01�Y Company: North America - ALASKA - BP Project: PBU Reference Site: 16 Site Error: O.00usff Reference Well: 16-14 Well Error: O.00usft Reference Wellbore PLAN 16-14C Reference Design: 16-14C WP04 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output effore are at Database: Offset TVD Reference: Well 16-14 Plan KB (84.00) @ 84.00usft Plan KB (84.00) @ 84.O0usft True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference Depths are relative to Plan KB (84.00) @ 84.00usit Coordinates are relative to 16-14 Offset Depths are relative to Offset Datum Coordinate System is Alaska NAD27 State Plane Zones, NAD27' OGP-Use AK Central Meridian is 150° 0'0.000 W " Grid Convergence at Surface is 1.66" 5] Ladder Plot MeaAUMC 160300O usftlin) $ 0332,03-32A,03-32AV1 $ 16-13,16-13PB7, 16-13PBI V0 -X- 03-32,0332,0332V4 $ 16-14,16-14,16-14VlO -dr 03-33,03-33C,03-33CVO $ 16-14,16-14A, 16-14A V11 $ 0336,03-36A,03-36AV5 $ 16-14,16-14B, 16-14B V5 $ 0336,03-36A, Plan K6 V2 -F 16-15,16-15,16-15V7 $ 0903,09-03A,09-03AVO -A- 16-15,16-15A, 16-15A VO $ 09-03,09-03A, Piti D9 -03A Approved VO $ 16-15,16-15APB1, 16-15AP61 V0 �- 16-10,16-1 OA, 16-10A V3 $ 16-18,16-18,16-18V1 $ 16-10,16-10,16-10V1 $ 09-01,09-01APB1,09-01APB1 V0 Jam- 9ad1 1n-11 1n-11 k/1 i 1l 11 nehlA noel A%in 1 -e,- 0330,03-30,03-30V5 $ 16-17,16-17A, 16-17A V0 -X- 16-17,16-17,16-17V1 -� 16-29,16-29,16-29V1 $ 16-29,16-29A, 16-29A VO $ 16-16,16-16,16-16V1 $ 0326,03-26,03-26 V4 $ 0335, PLAN 0335,03-35AVVP01 VO $ 0335,0335,03-35Vl i nvo of enm2»e ni toe rnonn vn 6272018 11 15,02AM Page 4 of4 COMPASS 5000,1 Build 81D C W SECTION DETAILS Projeod: Pau She: 16 Well: 16.14 Wellbore: PLAN16.16 Phan:16140 WWT&1VPLAN 146161 Sec MO Inc Ali TVD +NAS +E1 -W Dleg TFace VSW 1 7592.8539.90 20.88 6980.30 1676.79 775.75 0.00 0.00 1190.02 2 7614.00 40.03 20.88 6996.51 1669.49 780.61 0.51 0.00 1199.47 3 7630.00 41.34 18.56 700&64 1699.30 784.12 12.50 30.001206.87 4 7650.00 41.34 18.56 7023.66 1711.83 788.33 0.00 0.00 1216.43 5 8267.77 53.67 359.63 7442.73 2157.98 85220 3.00 35.33 1593.46 6 9024.17 53.67 359.63 7890.35 2767.33 8411,23 0.00 0.00 2147.08 7 10008.66 35.00 326.00 8001.00 3412.30 684.11 3.00 -139.88 2800.82 8 10299.94 35.00 326.00 8839.60 3550.81 590.69 0.00 0.00 296587 9 1033&94 35.00 326.00 8872.37 3569.83 577.86 0.00 0.00198&53 10 10798.27 90.00 326.00 9075.97 3894.08 359.15 12.00 0.00 3374.91 11 11098.27 90.00 326.00 9075.97 4142.79 191.39 0.00 0.00 3671.28 12 11129.28 90.55 321129 9075.82 416&54 174.12 2.00 27.89 3701.92 13 13339.34 90.55 32&29 9054.68 6006.91 .1052.39 0.00 0.90 5886.82 14 14049.10 91.00 305.00 9044.98 6511.45 -1545.68 3.00 .6.65 655287 15 14135.25 91.62 306.61 9043.01 6561.83 -1615.52 2.00 6&88 6628.09 16 16913.76 91.62 306+61 8964.45 8218.09 3045.05 0.00 0.00 9073.11 16-14BACNaIS.n,-TIP Smrt DCS 1250 TED -5000-KOP S7&n 2006holda1763000 MD 5Nn DLS30OTFO-3533 SIer175p40hoWA826777MD StanDLS3 00TF0-139188 NbYlrcbivN[M M9nl[WR:l1LL 6herp Si<i99v yPrvk m9 Ale 4r1q% MM.S(iGM1�'. ANNOTATIONS WELLBORE DETAILS: PIAN 16144C REffi16rILEIKFo9Mitpx Parent Wellbore. i6-14 Do-adreklN'El IRM: weneA4,T-Wh Tie on MD'. 7592.85 E>a1.W�s9 PotE®IDVD1 Re.- EW DIANg1 nonrysl Fe,, sbLloo0x.0a051 Neea,WOePPPa-- P'.Ke(640D)@94IX411 Cakubbn xe. W. -C- .a TVD MD Amotftn 6980.30 7592.85 16.14BACWWSurvey-TIP 6996.51 7614.00 StadDL512.50TFO.50.W-KOP 7008,64 7630.00 Std20.00 hold 47630.001VID 7023.66 7650.00 SWRDL53.O0TFO-55.33 744223 8267.n Stwt756,40 holdat8267.77MD 7890.35 9024.17 SMOLS3.00TFO-139.88 HOLDS 10008.66 SIM291.281old a110008.66MD 8839.60 10299.94 Sta1140.00hdd a110299.94MD 887237 10339.94 Ste iId12.00 9075.97 10798.27 StM300.00 Wide! 10798.27 MD 9075.97 11098.27 SIMDLS 2.08TF027.09 9075.82 11129.28 StM2210.06hoMa111129.28MD 9054.68 13339.34 Stvt DLS 3.00TF048.65 9044.98 14049.10 StWtDLS 2.00TF068.88 9043.011413515 SW2n8.52 hold at 14135.25 MD 8964.45 16913.76 TO16913.76 16-14C WP04 CM2" \\ ' Sun29118h01d411000866MD SIa14000 holdW 1029994 MD g6LP\ S1M Bu11d 1200 CMI 8001300.00 hold a 10798.27 MD THR2 SNn6LS300T702719 SAD \ SIen221004 ha1dal�)J12,9.128 MD ti I6-IJH ,e3 .a -rAi Stan DLS 300 TFO-88.65 SmnDL5200 TF06998 S.277852holda 1413515 MD BA<ER 0 F�UGHES West( -)/East(+) 10!16913,76 0roondU.1, 97,06 IN -S +E1 -W mm', EDO, IaMWde LOIpIWM &Df �y1�2„ 0.00 0.00 5@8396.430 710]06300 70'12.34S64N I48'13'S].161W SUNEYPROGR 16-IJCWPoJ Date 20187.6.1510000 00 Valdaed'. Yea Vadon: Iph Flan DaphTo 8u9ey8Ran T9o1 117.90 793285 1614Gylo0aM(1614) GYDL-Cms 7592.85 8150.00 1616 WP04PLAN 1614gMIND 8ISOM 10303.00 WC AIP)4"16140) MWD 8I%W 10300.00 Ili WP041PLAN 16146) MWD ffl 48A'tt1CA 10330.00 16913.76 W,IC 011PLAN16140) MWD 10330.00 10013.78 1616WP041PLAN16140) MWNFR�CCA CPSINGOETAILS TVD MO Nara Slze 6996.51761000951WPI.-d KOP 9.625 8639.6510300.00 7- 7.000 8564.4516913.76 41/7. 4.500 Prajee : PSU Sib: 16 Wal: 1614 0 by W411aara' IMD 16-14C �,J Pbna6-14C WPd1P1uawPUNi6-iMPLANi6-14L) fi-14C AEFDEKEIfORW1NN Cow4wblNE)Palee� NIM IA-ILLueNMVe@vtl r;9nAi&ffj ITVUI IEeleeraA. Ppn AB191P0®MWuA �=A==Ns)xexieme slm-IOAAx.0.➢Ofl5 Mmune Oepn FeMerm. PYn NBlA1➢0@A4➢Yi¢A CrtuObn Mcowe lNmunCuveWa �I UGHES Plan KB (84.00) U 84.ODwX EasOn0 (400 usNin) AOGCC BOTTOM OF ROTMY BEAN CHOICE UNE: 3-1/8' SM RANGED MW WL GTE mw J -1/B' w MNGED NY1/8' SA FUE( HOSE GTE VALVE CEUM MD WELL ARE FOR REFEREE DEPENDEM ON M REQUIREMENTS 6012 BOP C/L WELL if NIPME UP SPACER SPOOL 13 5/8' w FLAME TOP 13 5/8' w FIANLYD BOROM SPACER SPOOL 13 5/9' w FIMNCE TOP 13 5/B' w FTmAGED BOTIUM MOLE MODED ADAPTER 13 5/8' w FLANGED TOP 11' w FLANGED BOTTOM EASING SPOOL ASSEMBLY It' 5M FLANGED TOP 11' 514 FLANGED BOROM WIND HEAD ASSEMBLY 11' 511 FARM TOP STACK (DRAFT FLDMBD% BELL NPPIL 3T D8. PIPE SGL WEDEO TO THE BOTIN OF THE FLOWBM JO -0/6' IWER M TRINE NMTABIE RUBBER SEAL WELL BELL NIPPIi IS' OR UPPER. 18' M LONER Y OASNG FlLL OUTLET (OTY a 2) 13 5/8' w wam m EIARM 16' REAPER SW -0 -GRIP (1 G) T DR. 510. OUIIET (1 FA) Y DEA M. WAFT DUTCH LOCK DOWN FGNGE ANMILVE ROP: 13-5/e' w 5!R'FER w 13-5/8' 5M STUDDED TOP 13-5/8' 5M TIMM BOTTOM RMI TYPE BOP: 13 5/8' 59 NOY' 6012 DOUBLE BDP 13 5/B' 5M SIUDEO TOP 13 5/6' w FLANGED BOTTOM W/ 3-1/2' MANLNL LOGICS W/ 11' METER ORRLNG CRO55: 13 5/8' SM MOM TOP 13 5/8' w FWIGED BOTTOM W (2) 3 1/8' SM SIDE OURETS KILL WE 2-1/16' w FLEX WSE 2-1/16' 5M R 3-1/B' w D.SA 3-1/8' 511 FLAAEU MAMML DATE VMVE 3-1/8' w FLANGED NYDG0IS DATE mw EGM TYPE BOP. 13 5/8 5M NOV 6012 SINGLE BOP 13 5/B' w MOM TOP 13 5/e' w HJNGEO BDTTOM 8.3.17 L.C.) = 4-1/16' CNV WELLHEAD= ACTUATOR= VETCOGRAY __.__. BAKBt OKB. ELEV = 70' REEaEV= 67' BF. ELEV = 37.73 KOP= 4200' Max Angie = 93' @ 13355' Datum MD= 9960' Datum TVD = 88001SS Minimum ID = 3.725" @ 9793' 4-1/2" HES XN NIPPLE IV*IPSTOCK(02/14/06) I TBG, 12.69,13 -CR, D=3.958' 7" LNR 26#. L-80. D = 6.276' 4-12" LNR 12.60, L-80, D = 3.958' PERFORATION SUMMARY REL LOG: MWD GR ON 0225/06 ANGLE AT TOP PERF: 91' @ 11548' Note: Refer to Production DB for historical p 2-7/8" 6 11548 -11580 O 2-7/8" 6 11750-11782 O 2-7/8" 6 11968- 12000 O 2-7/8" 6 12440 - 12530 C 2-4/5" 6 13400- 13425 C 2-4/5" 6 13425 - 13450 C 2-4/5" 6 13450-13475 C 24/5" 6 13475 - 13500 C 2-7/8' 6 14150 - 14250 C 2-7/8' 6 15000 - 15100 C SA NOTES: WELL REQUIRES A SSSV WHEN 16-14B ON ML WELL ANGLE> 70° @ 10189'. AS OF 3121106, POSSIBLE SOLIDS IN TOP OF LNR DOE TO MILLING ON RIG 2193' I-14-1/2' HES X NP, D = 3.813" 19-5/8` X 7" BKR PKR & HNGR D = 6.25' 1 17"X 4-1/2' BKR S-3 PKR D = 3.875' 1 14-12' H6 XN NP, D = 3.725" 1 9795' 17'X 5'BKR ZXP LNR TOP PKR w/ TIEBACK SLV, D= 5.25' / BAD TT NOT LOGGED 9805' 9815' 7' x 5" BKR FLEX -LOC, LNR HNGR w /5' RS PACKOFF NP, D = 4250' 9921' 9927'5' X 4-1 /2' XO, D = 3.950' M ILLOUT WINDOW (16-146) 9916' - 9921' 1 14625' 1 LNR 12.6#, L-80 BT -M, .0152 bpf, D = 3.958" 1--1 15307' RATE RE1/ BY COMMENTS DATE REV BY COAMBYTS 07/09/81 014GINAL COMPLETION 1020/16 ATO/JMD MILL CBPS/SET CIBP/ADPERFS 04/13/98 SIDETRACK(16-14A) 0627/17 LLG1JMD SETPXNPLUG(06/23/17) 03H0/06 N21ES SIDETRACK (16-14B) 10/24/17 RCB/JhD RAL®PXNR.UG(10/23/17) 05/15/12 TTIMJMD CBA' PERF (05/09 - 11/12) 07/30/18 JN 1JMD ADDED REF & BF ELEV 05/05/14 ALWJMD CBR'ADPERF(04126-27/14) 05/30/14 JKD'JMD ADDED PERIF SYMBOL FISH: 2 4-1/2' CBPS MILL® & PUSHED DH (10/16/16) 1 14625' 1 PRIAHOE BAY UNT YVELL: 16-146 PERMIT No:'2060030 API No: 50-029-20570-02 TION R15E 1534' FNL & 526' F1M. BP Exploration (Alaska) WIFE= 4-1/16' CNV WELLHFAD= V_ErOD GRAY ACTUATOR= BAKER OKB. B.EV H 15176' BF. ELI V = 40.43 KOP= 4200' Malt Angle = 93' @ 13355' Llatum MD=--- 9960' Datum TVD= 88W'SS SAFE NOTE: WELL 70,@ 1 0 REQUIRES PROPOSED 16-14B CWN91; ON ML WELL ANGLE 70" � 10189'. AS OF 3121106, P&A POSSIBLE SOLIDS IN TOP OF LNR DUE TO MILLING ON 1 13-3/8' CSG. 729. L-80 BTG D - 12.347' 1 cslrsiz.:.r¢nn:.r.�a�.y:.iu.>ra>.��>•i��,��s'i'i'i'i'r'e` Minimum ID = 3.726" @ 9793' 4-1l2" HES XN NIPPLE 9-5/8' 412' TBG 12.6#, L-80 TCI, .0152 bpf, D = 3.958'9805' ' I4-12- TBG, 12.60,13 -CR D = 1958- - 8978 T LNR, 26#, L-80, D = 6.276' 10444' 41/Y LNR, 12.6#, L-80, D= 3.958' H 15176' PERFORATION SLU ARY O REF LOG: KIND GR ON 0225/06 6 ANGLE AT TOP PEW: 91' @ 11548' C Note: Refer to Roduction DB for historical pert data 2-7/8' 6 11750-11782. O 2-7/8' 6 11968-12000 O 2-7/8' 6 12440- 12530 , C 2-4/5' 6 13400-13425 - C 2-4/5' 6 13425-13450, C 2415' 6 13450 - 13475' C 2-415' 6 13475 -1350' C 2-7/8' 6 14150 - 14250 • C 2-716" 6 1500 - 1510 . C CUr TBG X 412' SKR S-3 PKK D = 1/2' HM X NP. D=3.813' 9795 7- X 5' BKR ZXP LN2 TOP PKR W 1 TIEBACK SLV, D= 5.25' 9606' 412' WL6G, D = 3.958' BMD TT NOT LOGO 9815' 7' x 5' BKR FLEX -LOC, LNR MGR w 15' RS PACKOFF NP, D = 4.250" 9827' 5- X 4-12' XO. D = 3.950' MILLOUT WINDOW (16-146) 991V - 9921' 1 4-12- UDR 12.6#, L-80 BT -M, .0152 Cpf, D = 3.956 - DATE REV BY OCM ENTS DATE REV BY 1 C016114911T5 07109181 ORIGINAL COMPLETION 1020/16 ATO/JKD KLL CBPSISET CBP/ADPERFS 04113198 SIDETRACK (16-14A) 0627117 LLG/JU SETPXNFiIUG(06/23/17) 03/10106 MMS SIDETRACK (16-148) 1024117 RCB/AAD RAU-EDPXNPLIUG(10/23/17) 0 15/12 TTWWJKD CBFV F137F (0 - 11112) 0626118 KP/JMD BUILT PROPOSED P&A 05/05;14 ALM'JMD CER'A03EW(0426-27/14) 05130114 J D1JKD ADDED PERF SY MIOL J FISH: 2 4-12' CEPS KILLED 8 RUSHED OH (10/16116) 14625 412' CIBP PRUDiOE BAY LIMIT MILL: 16-148 PHLA4r No: `1060030 AN Ne: 50-029.20570-02 T10N, R15E� 1534' FIML & 526' F1Aa BP Exploration (Alaska) TREE= VALL EAD = VETCO GRAY ACTUATOR= BAKER OKB- 0" 4-1/2'VYLEG.D=3.958' BF. E_EV = 40.43 KOP- 4200' Max Angle = _" @ DUWm MD= _ Dabim TVD = 8800'SS PROPOSED REV 1 72N, L-80 BTC, D= 12.347' �9-5/8' SLB WIIPSTOCK 9-5/8' CSG, 479, L-80 BTC, D = 8.681' —7 T TOC —1 Minimum ID = @ I4-1/2- TBG, 12.69, 13CR-85 VAM [UP, .0152 bpf, D = 3.958' 7' LNR 269. L-80 VAM TOP HC, .0383 bpf, D = 6.276' 4-1/2' LNR 12.69, 13CR45 HTTC, .0152 bpf, D = 3.958' I 10155' I 16-14C SAFETY ON ML WELLEEANGLE> : WELL R @VIRES A MAX CLSy Lr @ _'. CHROME TBG 8 LNR 9100' 4-1/2' HES XP. D = 3.81 7460' MLLOLIT WINDOW (16-14C) 7614' - 7630- 14-1/2' VIES 630' 14-12'HES X NP. D=3.813' 1 HES TNT PKR D = X NIP D=3.813' J—i7' X 5' WFD LTP w /TEBACK NO JWFD HGR, D =HGR, D = _' SEATSZ 4-1/2'VYLEG.D=3.958' OIC ELMD TT LOG(aED _/_/_ 27 NCC PRACPORT SLVS 10- 1890" NO Df8'fH SEATSZ ACRALSZ OIC DATE 27 NA SIDETRACK(16-14A) 26 WES NA 25 NA JMD BLIT PROPOSED 24 KR/JMD NA 23 NA 22 NA 21 NA 20 NA 19 NA 18 MA 17 NA 16 NA 15 NA 14 NA 13 N4. 12 NA 11 NA 10 NA 9 NA 8 NA 7 NA 6 NA 5 NA 4 NA 3 NA 2 NA 1 NA DATE REV BY COM I]w S DATE REI BY COMMENTS 07AMBI ORIGINAL COMPLETION 04113MB SIDETRACK(16-14A) 03110106 WES SIOETRACK(16-148) SIDETRACK(16-W) 06/25/18 JMD BLIT PROPOSED 06/25/18 KR/JMD BUILT PROPOSED REV 1 PRU DHOE BAY L1M' WELL: 16-M PERMIT ND: API Pb: 504029-20570-03 TION, R15F, 1534' FN- 8 525 PAL BP Expioration (Alaska) Rixse, Melvin G (DOA) From: Raese, J. Kyle <john.raese@bp.com> Sent: Wednesday, October 10, 2018 8:00 AM To: Rixse, Melvin G (DOA) Cc: Lastufka, Joseph N; Allen, Kenneth W Subject: RE: PBU 16-14C PTD(218-117) request Drill Pipe Size(s) Mel, Answers to your questions: 1. 5" DP (intermediate hole); 5" x 4" tapered DP (production hole) 2. A more detailed plan for Post -Rig Step #6 is outlined below: a. Background: The bottom two sleeves will likely be the first to be placed on injection. An acid treatment will be conducted to dissolve the cement near the sleeve, allowing communication to the reservoir. After the acid job is complete, an injectivity test will be conducted. If the well does not have injectivity, then a flowback to a portable unit with N2 lift may be required. b. CT fluid treatment sequence for each sleeve i. Inject 10 bbl, 15% HCI acid ii. Inject -50 bbl, 1% KCI (injectivity test #1) iii. Inject 10 bbl, 15% HCI acid iv. Inject -50 bbl, 1% KCI (injectivity test #2) 3. Well 03-03 (part of AOR) has a production casing impairment somewhere between the surface casing shoe and surface, or there is an impairment of the wellhead seals between IA and OA. This is confirmed by IA and OA gas sampling in 2009 (OA gas samples have gas lift composition). The re -pressurization is manageable by bleeds. Kyle Raese Drilling Engineer BP Exploration (Alaska) o: 907-564-4629 c: 907-301-6405 From: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Sent: Tuesday, October 9, 2018 1:35 PM To: Raese, J. Kyle <john.raese@bp.com> Cc: Lastufka, Joseph N <Joseph.Lastufka@bp. com> Subject: PBU 16-14C PTD(218-117) request Drill Pipe Size(s) Kyle, I am reviewing your PTD request for PBU 16-14C. Two questions: 1. What drill pipe sizes will you be utilizing? 2. Will BP submit a more detailed procedure, i.e., a 10-403, for post rig operations prior to placement on injection? a. If not, I need more detail regarding the service coil work for the acid job and sleeve opening. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office Rixse, Melvin G (DOA) From: Raese, J. Kyle <john.raese@bp.com> Sent: Wednesday, October 10, 2018 8:00 AM To: Rixse, Melvin G (DOA) Cc: Lastufka, Joseph N; Allen, Kenneth W Subject: RE: PBU 16-14C PTD(218-117) request Drill Pipe Size(s) Mel, Answers to your questions: 1. 5" DP (intermediate hole); 5" x 4" tapered DP (production hole) 2. A more detailed plan for Post -Rig Step #6 is outlined below: a. Background: The bottom two sleeves will likely be the first to be placed on injection. An acid treatment will be conducted to dissolve the cement near the sleeve, allowing communication to the reservoir. After the acid job is complete, an injectivity test will be conducted. If the well does not have injectivity, then a flowback to a portable unit with N2 lift may be required. b. CT fluid treatment sequence for each sleeve i. Inject 10 bbl, 15% HCl acid ii. Inject -50 bbl, 1% KCI (injectivity test #1) iii. Inject 10 bbl, 15% HCl acid iv. Inject -50 bbl, 1% KCI (injectivity test #2) 3. Well 03-03 (part of AOR) has a production casing impairment somewhere between the surface casing shoe and surface, or there is an impairment of the wellhead seals between IA and OA. This is confirmed by IA and OA gas sampling in 2009 (OA gas samples have gas lift composition). The re -pressurization is manageable by bleeds. Kyle Raese Drilling Engineer BP Exploration (Alaska) o: 907-564-4629 c:907-301-6405 From: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Sent: Tuesday, October 9, 2018 1:35 PM To: Raese, J. Kyle <john.raese@bp.com> Cc: Lastufka, Joseph N <Joseph.Lastufka@bp.com> Subject: PBU 16-14C PTD(218-117) request Drill Pipe Size(s) Kyle, I am reviewing your PTD request for PBU 16-14C. Two questions: 1. What drill pipe sizes will you be utilizing? 2. Will BP submit a more detailed procedure, i.e., a 10-403, for post rig operations prior to placement on injection? a. If not, I need more detail regarding the service coil work for the acid job and sleeve opening. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office Davies, Stephen F (DOA) From: Raese, J. Kyle <john.raese@bp.com> Sent: Tuesday, October 2, 2018 8:10 AM To: Davies, Stephen F (DOA) Cc: Allen, Kenneth W Subject: RE: PBU 16-14C (PTD 218-117 - Question Steve, We plan to flowback for clean-up only if there is poor injectivity following the acid treatment. Best, Kyle Raese Drilling Engineer BP Exploration (Alaska) o: 907-564-4629 c: 907-301-6405 From: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Sent: Monday, October 1, 2018 3:01 PM To: Raese, J. Kyle <john.raese@bp.com> Subject: PBU 16-14C (PTD 218-117 - Question Kyle, Will the planned PBU 16-14C injection well be pre -produced for 30 days or more, or will it simply be flowed back for a brief period to clean up the well? Thank you, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.daviesPalaska.aov. Remark: AOGCC PTD No. 218-117 Coordinate Check 1 October 2018 INPUT Geographic, NAD27 PBU 16-14C Latitude: 70 12 34.66400 Longitude: 148 13 53.16100 OUTPUT State Plane, NAD27 5004 -Alaska 4, U.S. Feet 1/1 NorthingN. 5929396.4 05 EastI ngfX: 719306.318 Convergence: 1 39 51.01733 Scale Factor: 0.999954636 Corpscon v6.0.1, U.S. Army Corps of Engineers TRANSMITTAL LETTER CHECKLIST WELL NAME: tea. PTD:/ Zld9 � /� -7 Development /Service Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: 04Za Z, POOL:l�p Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50 - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - -� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a 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 throu target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging ✓ Requirements er 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 PRUDHOE BAY, PRUDHOE OIL-640150 PTD#-Program i70 Company BP EXPLORATION (ALASKA) INC. Initial ClassfFype Name: PRUDHOE BAY UNIT 16-14(: SER Well bore se SER PEND 890 Administration 17 Nonconven. gas conforms to AS31.05.030Q. 1. A),(j.2.A-D) - - - - - _ _ NA _Well _/ __GeoArea Unit — _1_16.50 On/Off Shore Qn Annular Dispo 1 Permit fee attached NA - - - ..... - .. - - 2 Lease number appropriate _ _ _ Yes - - Surface Location lies within ADL0028332; Top Prod Int & TD lie within ADL0028.327. 3 Unique well name and number Yes _ - - - - 4 Well located in.a defined pool. - Yes PRUDHOE BAY, PRUDHOE OIL POOL - 64015, governed by CO 341F 5 Well located proper distance from drilling unit boundary. - .. - - - _ Yes _ CO 341F, Rule 2:- There shall be no restrictions as to well. spacing. except that no pay shall be 6 7 Well located proper distance from other wells. Sufficient acreage available indrillingunit_ Yes opened_ in a well closer than 500 feet to.the boundary of the. affected. area. Planned well conforms to 8 - _ _ _ _ _ _ _ _If, deviated, is wellbore plat included _ - - - _ _ _ _ _Yes Yes CO 341 F, Rule 2._ - - - - 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 ------ ------- SFD 10/2/2018 12 Permit can be issued without administrative approval , - - - . _ Yes 13 Can permR be approved before 15-day wait. _ _ _ - - - . _ _ Yes _ - - - - - - 14 Well 10cated within area and. strata authorized by. Injection Order # (put 10# in.comments). (For. Yes - Prudhoe Bay Unit, Eastern Operating Area. is governed by AID 4Gissued10/15/2015. 15 All wells within 1/4 mile area-of review identified (For service well only) - - .. Yes _ - _ PBU 03-03, 03-04, 03-05, 03-12.03_-26, 03-30, 03-32A, 03-33C, 03-35, 09-01A, 09-031i5l, 16-1416-14A16-17- 16 Pre-produced injector: duraticn.of pre produgtion less than 3 months (For service well only) - - No , . - Engineering 18 Conductor string _pr0vrded. _ _ _ _ _ _ .. - NA - _ Sidetrack from existing 9 5/8 - intermediate casi ng .Surface casing. protects all.known USDWs - _ - - NA - _ _ ..------- -- - ....Sidetrack from existing 9-5/8" intermediate casing 20 CMT vol adequate. to te conductor &surf csg - - ... - - - - - . - NA _ . Sidetrack from existing 9-5/8" intermediate. casing 21 fie-in long CMT vol adequate to tie-in long string s surf csg .. - _ - _ . NA - _ - _ Sidetrack from existing 9-5/8" intermediate. casing 22 ri CMT will cover all known Productive horizons - - - - - - - - - - - - - - - - _ Yes - . _ _ Intermediate liner cement coverage -960' TVD above TSAQ 23 Casing designs adequate for C, T, B &. permafrost_ _ - _ Yes 24 Adequate tankage or reserve pit - - -- - - - - - - - - - - - - - - - - . Yes - - Parker 272 to drill 25 If.a re-doll, has a 10-403 for abandonment been approved _ ... - _ . _ _ . - - _ Yes - - - -Sundry 318-366.. 26 Adequate ed wellbore sepadoes Yes _ - - 4 collision risk failures identified in prod hole, those wells will be shut in whiledrilling 27 terreq it meet regulations- Drilla ertfl required, does it meet regulations _ _ _ - NA - - - . Sidetrack from existing IC casing Appr Date 28 Drilling fluid program schematic equip list adequate_ _ _ - _ . - _ _ -YesIVIGR 10/10/2018 29 BOPEs do they meet regulation _ Yes - VBRs-to cover 4-1/2" and 5" DP and 4-1/2" and 7" liners- 30 BOPE press rating appropriate; test to-(put psig in comments). . . . . ... . . . . .... . . . Yes .. - 31 Choke manifold complies w/API RP-53 (May $4)- _ - -Yes 32 Work will occur without operation shutdown_ _ . _ _ _ _ _ _ _ .. - _ - Yes 33 presence of H2S gas probable- - - - - . _ Yes .. - .. H2$ measures in-place echanical condition of wells within AOR verified (For service well only) - - - - - - - - - - - - - Yes . - - _ - .. - AOR wells attached Geologyata.presented +36 Permit can be issued w/o hydrogen_ sulfide measures _ _ _ _ _ _ _ _ _ No - - . - - - DS 16 wells _are.H2S-bearing, H2S measures are required. on potential overpressure zones Yes Planned mud weights appearadequateto controlthe operator's forecast of estimated pore Appr Datismic analysis of shallow gas zones - - - _ - _ NA_ . pressures. _ _ Should higher.pore_pressures be encountered, BP has.immediate access to nearby, fluid facilities.. SFD 10/1/2018 38 Seabed condition survey (if off-shore) - - - _ - - _ - - - - . _ _ NA39 -mixing - on ac name phony for weekly. progress reports [exploratory only] _ NA - - - - - - Geologic Commissioner: Engineeringpu Date. Commissioner: Date Date D--r5 m missi e /0 / i Of IS 4��- 1 D tt.� �ufl,