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Home My WebLink About217-1257. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU S-200A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 217-125 50-029-22846-01-00 15739 Conductor Surface Intermediate Production Liner 6825 76 2686 14102 1725 14900 20" 9-5/8" 7" 4-1/2" 6935 48 - 124 48 - 2734 46 - 14148 13966 - 15691 48 - 124 48 - 2712 46 - 6582 6483 - 6832 None 470 4760 5410 7500 14900, 15091, 15484 1490 6870 7240 8430 14530 - 15587 4-1/2" 12.6# 13cr85 44 - 13973 6818 - 6846 Structural 4-1/2" HES TNT Perm Packer 13849 6425 Torin Roschinger Operations Manager Tyson Shriver tyson.shriver@hilcorp.com 907-564-4542 PRUDHOE BAY, AURORA OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028256, 0028257, 0028258 44 - 6487 N/A N/A 476 329 3133 197 1724 274 1450 1350 320 280 N/A 13b. Pools active after work:Aurora Oil No SSSV Installed 13849, 6425 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 4:15 pm, Jul 22, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.07.22 16:02:41 - 08'00' Torin Roschinger (4662) DSR-7/29/24WCB 9-30-2024 RBDMS JSB 072524 ACTIVITY DATE SUMMARY 4/24/2024 ***WELL FLOWING UPON ARRIVAL*** (profile mod) R/U HES 759 SLICKLINE UNIT ***CONT WSR ON 4/25/24*** 4/24/2024 T/I/O = 1099/1250/250- Assist SL w/ FP. Pumped 2 bbls 60/40 into FL, pressured FL to 1500 psi. Pumped 3 bbls 60/40 and 36 bbls Crude into TBG. SL in control of well and pad op notified upon LRS departure. 4/25/2024 ***CONT WSR FROM 4/24/24*** (profile modification) DRIFTED W/ 3.60" CENT, 3.0" SAMPLE BAILER TO DEVIATION @ 14,770' SLM (bailer empty) ***WELL LEFT FLOWING UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** 7/13/2024 LRS #1 1.75" Coil Tubing - Job Scope = Drift, Set CIBP Road from H Pad to S Pad. MIRU. Start weekly BOP test ***Job continued 7/14/24*** 7/13/2024 TFS U4 (Assist coil) Rig up and fluid pack coil. Pumped 3 bbls of KCL down the coil *Job continues to 7-14-24* 7/14/2024 LRS #1 1.75" Coil Tubing - Job Scope = Drift, Set CIBP Complete weekly BOP test, Pass. MU NS MHA and 3.6" nozzle drift. RIH tag CBP @ 15,022' CTM. Paint Flag @ 14,800' CTM. POOH. MU NS 4.5" CIBP. RIH. Corr Depth @ Flag. Set 4.5" CIBP @ 14,900'. POOH. FP well 38 bbls diesel. RDMO. ***Job Complete*** 7/14/2024 *Job continues from 7-13-24* TFS U4 (Assist Coil) Pumped 3 bbls of 50/50 followed by 180 bbls of KCL down the bakside to kill well for coil. Pumped 41 bbls of KCL, 3 bbls of 60/40, and 37 bbls of diesel down coil to assist as needed. Well left in control of coil upon departure Daily Report of Well Operations PBU S-200A g MU NS 4.5" CIBP. RIH. Corrg@ Depth @ Flag. Set 4.5" CIBP @ 14,900'. POOH. CIBP is correctly shown on the WBS below. -WCB Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 02/09/2024. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD #API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023 S-200A 217125 500292284601 7 9/19/2023 Well Name PTD # API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024 DATA SUBMITTAL COMPLIANCE REPORT 10/26/2018 Permit to Drill 2171250 Well Name/No. PRUDHOE BAY UN AURO S -200A Operator BP EXPLORATION (ALASKA) INC. API No. 50-029-22846-01-00 MD 15693 TVD 6832 REQUIRED INFORMATION Completion Date 12/26/2017 Mud Log No,/ Completion Status 1-0I1- Current Status 1-0I1- UIC No Samples No„/ DATA INFORMATION List of Logs Obtained: MWD/GR/RES,CEMENT EVALUATION/MWD/GR/RES/DEN/NEU Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No ED C 28900 Digital Data ED C 28900 Digital Data ED C 28900 Digital Data ED C 28900 Digital Data ED C 28900 Digital Data ED C 28900 Digital Data ED C 28900 Digital Data ED C 28900 Digital Data ED C 28900 Digital Data ED C 28900 Digital Data ED C 28900 Digital Data AOGCC Pagel of 3 Directional Survey Yes V' (from Master Well Data/Logs) Interval OH/ Start Stop CH Received Comments 2704 15693 12/22/2017 Electronic Data Set, Filename: S- 200A_BHI_OTK_MEM_Composite FE Drilling Data.las 12/22/2017 Electronic File: S-200A_BHI_OTK_2MD_Memory Drilling Log.cgm 12/22/2017 Electronic File: S- 200A_131-1I_OTK_2TVDSS_Memory Drilling Log.cgm 12/22/2017 Electronic File: S-200A_BHI_OTK_5MD_Memory Drilling Log.cgm 12/22/2017 Electronic File: S- 200A_BHI_OTK_5TVDSS_Memory Drilling Log.cgm 12/22/2017 Electronic File: S - 200A BH1_OTK_MEM_Composite FE Drilling Data.dlis 12/22/2017 Electronic File: S-200A_BHI_0TK_2MD_Memoryk F Drilling Log.pdf 12/22/2017 Electronic File: S - 200A 131-11_OTK_2TVDSS_Memory Drilling Log.pdf 12/22/2017 Electronic File: S-200A_BHI_OTK_5MD_Memory . f- Drilling Log.pdf 12/22/2017 Electronic File: S - 200A 131-11_OTK_5TVDSS_Memory Drilling Log.pdf 12/22/2017 Electronic File: S-200A_BHI_Final Survey Report.pdf Friday, October 26, 2018 is Is DATA SUBMITTAL COMPLIANCE REPORT 10/26/2018 Permit to Drill 2171250 Well Name/No. PRUDHOE BAY UN AURO S -200A Operator BP EXPLORATION (ALASKA) INC. API No. 50-029-22846-01-00 MD 15693 TVD 6832 Completion Date 12/26/2017 ED C 28900 Digital Data ED C 28900 Digital Data ED C 28900 Digital Data Log C 28900 Log Header Scans ED C 28943 Digital Data ED C 28943 Digital Data ED C 28943 Digital Data ED C 28943 Digital Data ED C 28943 Digital Data Log C 28943 Log Header Scans ED C 29217 Digital Data ED C 29217 Digital Data ED C 29217 Digital Data ED C 29217 Digital Data ED C 29217 Digital Data ED C 29217 Digital Data Completion Status 1 -OIL 0 0 12656 6334 8257 6304 0 0 15580 13686 15582 13710 Current Status 1 -OIL UIC No 12/22/2017 Electronic File: S-200A_BHI_Final Survey Report.txt 12/22/2017 Electronic File: S-200A_BHI_Final Surveys.csv 12/22/2017 Electronic File: S-200A_BHI_Final Surveys.xls 2171250 PRUDHOE BAY UN AURO S -200A LOG HEADERS 1/12/2018 Electronic Data Set, Filename: BPXA_S- 200A_ IBC _ CBL_17Nov2017_ConPr_R04_L001U p_Main.las 1/12/2018 Electronic Data Set, Filename: BPXA_S- 200A_ IBC _ CBL_ 17Nov2017_ConPr_R06_L001U p_Repeat.las 1/12/2018 Electronic File: BPXA_S- 200A IBC_ CBL_ 17Nov2017_ConCu_R04_L001 Up_Main.dlis 1/12/2018 Electronic File: BPXA_S- 200A_IBC_ CBL_ 17Nov2017_ConCu_R06_L001 Up_Repeat.dlis 1/12/2018 Electronic File: BPXA_S- 200A_IBC_CBL_17Nov2017_Rev-1.pdf 2171250 PRUDHOE BAY UN AURO S -200A LOG HEADERS 5/3/2018 Electronic Data Set, Filename: S- 200A_16Feb2018_SCMT_MAIN PASS UP 30 FPM MEM 030PUC.las 5/3/2018 Electronic Data Set, Filename: S - 200A 16Feb2018 SCMT REPEAT—PASS—UP 30 FPM_MEM_031 PUC.Ias 5/3/2018 Electronic File: S- 200A_16Feb2018_SCMT_MAIN _PASS—UP 30 FPM_MEM_030PUC.DLIS 5/3/2018 Electronic File: S- 200A_16Feb2018_SCMT_REPEAT_PASS_UP 30 FPM MEM 031PUC.DLIS 5/3/2018 Electronic File: S -200A 16-Feb- 20118—Mem—Field Print—Coil Flag.PDF 5/3/2018 Electronic File: S -200A_16 -Feb - P 2018 Mem Field Print SCMT.PDF AOGCC Page 2 of 3 Friday, October 26, 2018 • DATA SUBMITTAL COMPLIANCE REPORT 10/26/2018 Permit to Drill 2171250 Well Name/No. PRUDHOE BAY UN AURO S -200A Operator BP EXPLORATION (ALASKA) INC. API No. 50-029-22846-01-00 MD 15693 TVD 6832 Completion Date 12/26/2017 Completion Status 1 -OIL Current Status 1 -OIL UIC No Log C 29217 Log Header Scans 0 0 2171250 PRUDHOE BAY UN AURO S -200A LOG HEADERS Well Cores/Samples Information: Name INFORMATION RECEIVED Completion Report Production Test Information Y / NA Geologic Markers/Tops Y COMPLIANCE HISTORY Completion Date: 12/26/2017 Release Date: 10/6/2017 Description Comments: Compliance Reviewed By: Sample Interval Set Start Stop Sent Received Number Comments Directional / Inclination Data Mechanical Integrity Test Information Y / NA Daily Operations Summary 0 Date Comments Mud Logs, Image Files, Digital Data Y /lam Core Chips Y / IA Composite Logs, Image, Data Files) Core Photographs Y / r Cuttings Samples Y / SIA Laboratory Analyses Y NA Date: — AOGCC Page 3 of 3 Friday, October 26, 2018 0 0 Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax 21 7125 EhED Delivered to: a I • • I 3 -May -18 HAY "!/ '� AOGCC 03May18-JW04 H8 201 ATTN: Natural Resources Technician II CC Alaska Oil & Gas Conservation Commision 29 2 17 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 &MV ELL NAME 09-29A API # ' 50-029-21422-01 SERVICE ORDER k.- # DQMD-00029 FIELD NAME PRUDHOE BAY SERVICE DESCRIPTION Memory DELIVERABLE DESCRIPTION CBUSCMT DATA TYPE FINAL FIELD DATELOGGED 17 -Jan -18 COLOR PRINTS 1 CDs 1 09-51A 50-029-22320-01 DUJJ-00030 PRUDHOE BAY WL USIT-CBL Rev1 FINAL FIELD 4 -Feb -18 1 1 NK -14B 50-029-22668-02 DQMD-00031 RAVEN Memory Cement Eval FINAL FIELD 5 -Feb -18 1 1 16-21A 50-029-21518-01 DQMD-00032 PRUDHOE BAY Memory SCMT FINAL FIELD 7 -Feb -18 1 1 S -200A 50-029-22846-01 DQMD-00033 AURORA Memory SCMT FINAL FIELD 16 -Feb -18 1 1 N -18A 50-029-20906-01 DODJ-00123 PRUDHOE BAY WL (PROF FINAL FIELD 12 -Mar -18 1 1 D -13A 50-029-20449-01 DQMD-00038 PRUDHOE BAY Memory CBL/SCMT FINAL FIELD 30 -Mar -18 1 1 Transmittal Receipt A Transmittal Receipt signature confirms that a package (box, P •� � envelope, etc.) has been received and the contents of the X.4 package have been verified to match the media noted above. The Print Name Signaturjbo Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this Please return via courier or sign/scan and email a copySchlumberger and BP point. Alaska PTSPrintCenter slb.com AKGDMtNTERNAL b.com SLB Auditor- -TC.J Schlumberger -Private is 0 RECEIVED b STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing ❑ Operatio❑ Suspend ❑ Perforate 0 Other Stimulate 11 Alter Casing 11n sh o Change Cmc ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Stratigraphic ❑ Exploratory ❑ Service ❑ 5. Permit to Drill Number: 217-125 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 6. API Number: 50-029-22846-01-00 7. Property Designation (Lease Number): ADL 028257, 028258 & 028256 8. Well Name and Number: PBU S -200A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, AURORA OIL 11. Present Well Condition Summary: Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 26 Total Depth: measured 15693 feet Plugs measured 15091, 15484 feet 15. Well Class after work: true vertical 6832 feet Junk measured None feet Effective Depth: measured 15091 feet Packer measured 13849 feet true vertical 6896 feet Packer true vertical 6425 feet Casing: Length: Size: MD: TVD: Burst: Structural Conductor 76 20" 48-124 48-124 1490 Surface 2686 9-5/8" 48-2734 48-2712 6870 Intermediate 14102 7" 46-14148 46-6582 7240 Production Liner 1725 4-1/2" 13966 - 15691 6483-6832 9020 Perforation Depth: Measured depth: 14530 - 15587 feet True vertical depth: 6818-6846 feet Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 4-1/2" 12.6# 13Cr85 44-13973 4-1/2" HES TNT Perm Packer 13849 12. Stimulation or cement squeeze summary: Intervals treated (measured): 14530'- 14562' 15015'- 15025' Treatment descriptions including volumes used and final pressure: See Attachment 44-6486 6425 Collapse: 470 4760 5410 8540 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 26 438 3452 1145 254 Subsequent to operation: 1584 1103 3218 1365 428 14. Attachments: (required Per 20 AAc 25.070.25.071, &25.283) 15. Well Class after work: % Daily Report of Well Operations 0 \�\�\ Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ Ve 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Authorized Title: Authorized Signature: Form 10-404 Revised 04/2017 f"D y�J 4�26I�D! 8 Date:.L V74- Sundry Number or N/A if C.O. Exempt: 317-491 Contact Name: Wages, David Contact Email: David.Wages@bp.com Contact Phone: 907.564.5669 110"1101 Submit Original Only Daily Report of Well Operations S -200A ACTIVITYDATF SUMMARY ***WELL S/I ON ARRIVAL*** (Fracturing) UNABLE TO PASS ST #4 (6,886' MD) W/ 4-1/2" WHIDDON CATCHER SUB. DRIFT TO 7,000' SLM W/ 4-1/2" BRUSH, 3.00" S -BAILER (No issues or sample). SET 4-1/2" KEYLESS X -CATCHER AT 13,908' SLM / 13,955' MD. PULL BK-OGLV FROM ST #4 (6,886' MD). 3/24/2018 ***JOB IN PROGRESS, CONTINUED ON 3/25/18 WSR*** ***CONTINUED FROM 3/24/18 WSR*** (Fracturing) PULL BK-LGLV FROM ST #6 & SET BK-DGLV AT ST #6 (3,512' MD). LRS LOADED IA W/ 130 BBLS OF INHIBITED SW & 45 BBLS OF CRUDE (FP). SET BK-DGLV AT ST #4 (3,512' MD). PULL EMPTY 4-1/2" KEYLESS X -CATCHER FROM 13,908' SLM / 13,955' MD. LRS LOADED TUBING W/ 320 BBLS OF CRUDE. LRS PERFORMED SUCCESSFUL MIT -IA TO 3,548 PSI. 3/25/2018 ***WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS*** T/1/0=1150/1350/200 Temp=S1 (LRS Unit 72 -Assist Slickline: Load and Test) Pumped 3 bbls 60/0 meth, 137 bbls of inhibited seawater and 45 bbls crude down IA for load. Pumped 9 bbls crude down IA to pressure up on dummy to be sure it was set. S/L pulled catcher. Pumped 2 bbls of 60/40 meth and 320 bbls of crude into the TBG. MIT -IA ***PASSED*** at 3548 psi. (3600 psi Max Applied) IA lost 37 psi / 1st 15 min and 15 psi / 2nd 15 min. IA lost a total of 52 psi during the 30 min test. Pumped 6.3 bbls of 70* F crude to achieve test pressure. Bled back 4.5 psi to S/L had control of the well and WFO notified upon our departure. IA/OA OTG. 3/25/2018 FWHP= 740/448/65. (LRS Unit 70 - Assist Coiled Tubing: Heat Uprights) Heat UR 087 w/ 260 bbls 1% 3/27/2018 kcl/Safelube to 140*F. ***Continued on 03-28-18 WSR*** ***Continued from03-27-18 WSR*** (LRS Unit 70 -Assist Coiled Tubing: Heat Upright) Rig Up to UR 4490 w/ 260 bbls 1 % kcl/Safelube to 140* for CTU. Started to circulate fluid and noticed lack of valve integrity on UR. Notified WSL and fluid support. Fluid support will 3/28/2018 swap out UR. CTU 9 1.75" CT ***Continue from 3/28/18*** Continue rig up. Function test BOPs on well. Pump 1.188" drift ball. Make up and RIH with 3.700" nozzle and 2.875" GR/CCL logging carier. Log from tag at 15462CTM to 13800. Paint flag at 15100. Log data shows a +26' correction, making corrected EOP @ flag = 15116.35'. Log tied into HAL Coil Flag 24 -DEC -2017. RIH with CBP and set middle element at 15092, top of plug 15091.19'. POOH and freeze protect with an additional 21 bbl. Lay down bops in prep for weekly bop test. 3/29/2018 ***Job in Progress*** Heat/Roll frac tanks 3/29/2018 End ticket, ***job continued on 03/30/18 *** CTU 9 1.75" CT ***Continue from 3/28/18*** Continue rig up. Function test BOPs on well. Pump 1.188" drift ball. Make up and RIH with 3.700" nozzle and 2.875" GR/CCL logging carier. Log from tag at 15462CTM to 13800. Paint flag at 15100. Log data shows a +26' correction, making corrected EOP @ flag = 15116.35'. Log tied into HAL Coil Flag 24 -DEC -2017. RIH with CBP and set middle element at 15092, top of plug 15091.19'. POOH and freeze protect with an additional 21 bbl. 3/29/2018 ***Job in Progress*** • Daily Report of Well Operations S -200A Job continued from 03-29-18 **** Assist frac by holding IA pressure. Heat Frac tanks/Heat dsl/ transfer to SLB tanker. Maintain 2000 psi during fracturing operations 3/30/2018 RDMO: Valves & Pressure = FRAC **"SLB Frac Crew*** Job Scope: Fracture treatment targeting Kuparuk C sands <<< InterAct Publishing >>> 3/29 Rig up SLB frac equipment, 3/30 LRS Roll tanks to 90 deg. F and support frac rigged up to IA. Performed equipment testing per BP RP 100218 Pressure Testing. Found problem with Inlet metering on PCM and could not repair on location. Decision to shut down operation and take PCM back to shop to repair issue. ...Job delayed will continue in morning... 3/30/2018 CTU 9 1.75" CT ***Continue from 3/28/18*** Objective: Frac support. Cont FCO, composite bridge plug, adperf Perform weekly bop test. Frac unable to perform stage 1 due to mixing pod flowmeter failure/issue. Frac postponed until tomorrow. Continue standby. 3/30/2018 ***In progress*** CTU #9 1.75" 0.156WT. Objective Frac support. Cont FCO, composite bridge plug and adperf Continue standby for Frac crew to perform stage 1. Assist frac crew with pumping 29.5bbl of 12% HCI. Continue standing by for first stage frac. Frac was able to get entire stage 1 off with no issues. —3bbls sand left on top of plug. Plan to forgo FCO and log/drift. Grease/service entire tree. Remove tree cap, nipple up BOPs. Continue ru for drift/log. 3/31/2018 ***In progress*** ***SLB Frac Crew*** Job Scope: Fracture treatment targeting Kuparuk C sands <<< InterAct Publishing >>> MIRU PCM and continue. Performed equipment testing per RP 100218 Pressure Testing. Pump 100 bbis of 28# linear gell, 50 bbl pill of 281b cross-link gel chased with 228 bbls of 281b linear gel. Treating pressures higher than ideal. Shut down, conferred with town team, decision made to pump 15% HCL. Pump 30 bbl pill of 15% HCL and shut down halfway through perforations seeing good response on WHP stop pumps and soak for 20 min. Continue pumping HCL through perfs and shut down for another 20 min. Pump 100 bbl 0.5 PPA Scour Stage using JOrdan 16/30 sand @ 20 bpm with hard shut down monitoring well till closure. Data analysis showed FG = 0.67 psi/ft, leak -off coef = 0.003, ISIP= 1850 psi CP= 1560 psi. Pumped second 0.5 PPA scour stage using 2000 lbs of Jordan 16/30 sand, NWBF reduced by 1400+ psi after Acid and two scour stages. Redesign pump schedule based on data analysis and pump frac as per design using max pressue of 4500 psi during frac to dictate rate, max rate during treatment was 29.1 bbls/min. Pumped 1 PPA flat stage then ramp from 1 PPA up to 8 PPA then a Flat 8 PPA until 100,000 bls of 16/20 carbo was behind pipe. Last 50,000 lbs of propant was; CBL, resin coated carbo bond lite. Slow pump rate and shut down watching WHP for 15 min. 100,000 lbs behind pipe and 1,008 lbs left in Liner. Est. sand top @ 14818' with unbroken gel. Secure well and hand over to Coiled Tubing. Stage one of two 3/31/2018 complete. TWO= frac/275/141. Assist with frac (Fracturing) Hold and maintain IA pressure during fracing procedures 3/31/2018 *** Job continued on 04/01/18 *** 0 • Daily Report of Well Operations S -200A CTU #9 1.75" 0.156WT. Objective Frac support. Cont FCO, composite bridge plug and adperf Continue RU for drift/log run. MU HES memory gr/ccl inside 2.875" carrier+3.70 ported nozzle. Displace well to safelube at min rate while rih. Tag top of sand at 14965CTM. Log up to 13600. Flag pipe at 14600. Pump pipe displacement pulling OOH. Log shows a +45.5' correction, making corrected EOP at flag = 14636.19'. Make up and RIH with 2.875" X 32' MaxForce 6spf pert gun. Load/launch 1/2" AL ball with 60/40, taking returns to OTT's, holding 400psi backpressure. Perforate 14531-14563. Pumped 15bbl 60/40 cap on well while POOH. 4/1/2018 ***In progress*** **** Job continued from 04-01-18 **** Assit with frac/Heat frac tanks/Heat dsl. Hold IA pressure. At the request of CTU WSL, pressure IA up. Maintain 1800 psi to 2000 psi. 4/2/2018 FWHP=2000/495/201 CTU still on well upon departure. CTU #9 1.75" 0.156WT. Objective Frac support. Cont FCO, composite bridge plug and adperf RD spend 2.88" gun. MU/RIH with WFD 4.5" CBP. Set CBP at 14700 (ME). Top of plug 14699.19'. Perform injectivity test Pressure broke over at 4000psi. Final injection achievable with the coil pump: 3.1 bpm at 4185psi, coil pump was out of horsepower. POOH. LD CBP setting BHA. Stack down off of well and prep for pumping 50bbl acid pill. Frac pumped without issues, —200' of carbolite left in well/on top of perfs/cbp. Unable to commence milling due to P272 being on losses and no trucks available for fluids. KCL supply is very limited as well. Stack back up on well and prepare to lay in FP while we wait for trucking/fluids. Remove tree cap, NU BOPs. 4/2/2018 ***In progress*** ***SLB Frac Crew*** Job Scope: Fracture treatment targeting Kuparuk C sands <<< InterAct Publishing >>> Performed equipment testing per RP 100218 Pressure Testing. CT to load wellbore with 50 bbls of 15% HCL. Frac pumps took over and pumped acid down to perforations stopped and let soak for 20 min. Pump following stages: 150 bbl PAD of 28# cross-link gell, 100 bbl scour w/ 0.5PPA 16/20 carbo lite. 150 bbl PAD of 28# cross-link gel, 50 bbl 1 PPA Flat 45 bbl stage, 1 PPA Flat up to 8 PPA Flat, 50 bbl stages 8PPA-11 PPA, 112 bbl 12PPA Flat. Data analysis showed FG = 0.67 psi/ft, leak -off coef = 0.003, ISIP= 1800 psi CP= 1630 psi. NWBF reduced by —500 spi after Acid stage. max rate during treatment was 32.2 bbls/min. 136,000 bls of 16/20 carbo lite an Carbo Bond was put behind pipe. Est 1500 lbs sand left in Liner. Est. sand top @ —14330' with cross-link gel. Secure well and 4/2/2018 hand over to Coiled Tubing. Stage two of two complete. CTU #9 1.75" 0.156WT. Objective Frac support. Cont FCO, composite bridge plug and adperf NU bops, cut pipe for chrome mgmt, chain inspection, c/o packoffs, MU DJN bha to RIH and FP well to 2500'. Standby for trucking to be freed up by P272. Make up and RIH with 3.700" 5 -blade junk mill BHA. Tag top of sand at 14298. Begin milling. Find upper CBP at 14675 (up weight). Correct depth and flag pipe (white). Corrected EOP at flag = 14673.06. Mill upper CBP. Continue milling lower CBP. 4/3/2018 ***In progress*** CTU #9 1.75" 0.156WT. Objective Frac support. Cont FCO, composite bridge plug and adperf NU bops, cut pipe for chrome mgmt, chain inspection, c/o packoffs, MU DJN bha to RIH and FP well to 2500'. Standby for trucking to be freed up by P272. Make up and RIH with 3.700" 5 -blade junk mill BHA. Tag top of sand at 14298. Begin milling. Find upper CBP at 14675 (up weight). Correct depth and flag pipe (white). Corrected EOP at flag = 14673.06. Mill upper CBP. Continue milling lower CBP. 4/3/2018 ***In progress*** i • Daily Report of Well Operations S -200A CTU #9 1.75" 0.156WT. Objective Frac support. Cont FCO, composite bridge plug and adperf Continue trying to mill lower CBP at 15,098'. After 12 hours of milling, decide to bit trip. While POOH pipe was detained throughout 8000-6000 all returns were lost. Worked pipe free and POOH, varying amounts of returns were established on the way out of hole 0-100%. Lay down milling BHA and see significant wear on entire mill. It is evident that there is a significant amount of carbolite left in the well. Decision from town to jet all GLMs with all returns going to formation. MU and RIH with 2.35" SJN and jet all mandrels and nipples with gel. POOH. Freeze protect we] with 33bb1 of 60/40. RDMO 4/4/2018 ""*In progress*"" CTU #9 1.75" 0.156WT. Objective Frac support. Cont FCO, composite bridge plug and adperf Finish RDMO 4/5/2018 *""Job Complete*"'' Hydraulic Fracturing Fluid Product Component Information Disclosure 'tart Date: End Date: State: County: I Number.- tor umber:for Name: I Number: Latitude: .ongitude: Datum: leral Well: than Well: True Vertical Depth: Total Base Water Volume (gal).- Total gal):Total Base Non Water Volume: 3/31/2018 4/2/2018 Alaska Beechey Point 50-029-22846-01-00 BP America Production Company S -200A 70.35539100 -149.04231800 NAD27 NO NO 6,785 256,730 0 Hydraulic Fracturing Fluid Composition: Fr6c Focus Cherykal Discbsure Registry "tolfc*10% C(: C)il & GAS • U Chemical Maximum Maximum Abstract Ingredient Ingredient Trade Name Supplier Purpose Ingredients Service Concentration Concentration Comments Number in Additive in HF Fluid (CAS #) (% by mass)** (% by mass)** Water Schlumberger N/A Water (Including Mix 7732-18-5 88.89580 Water Supplied by Client)* M275 Schlumberger Bactericide Listed Below • U J218 Schlumberger Breaker Listed Below W054 Schlumberger Demulsifier Listed Below S123 Schlumberger Activator Listed Below H036 Schlumberger Acid Listed Below J475 Schlumberger Breaker Listed Below A264 Schlumberger Corrosion Inhibitor Listed Below M002 Schlumberger Additive Listed Below S526-1620 Schlumberger Propping Agent Listed Below L065 Schlumberger Scale Inhibitor 0 0 Is Listed Below J580 Schlumberger Gelling Agent Listed Below L058 Schlumberger Iron Control Agent Listed Below L071 Schlumberger Clay Control Agent Listed Below S012-1630 Schlumberger Propping Agent Listed Below F103 Schlumberger Surfactant Listed Below J604 Schlumberger Crosslinker Listed Below S522-1620 Schlumberger Propping Agent Listed Below Items above are Trade Names with the exception of Base Water. Items below are the individual Ceramic materials and wares, chemicals ingredients. 66402-68-4 90.96421 10.10085 Quartz, Crystalline silica 14808-60-7 2.13759 0.23736 Guar gum 9000-30-0 2.11817 0.23521 0 Is 0 Hydrochloric acid 7647-01-0 1.31679 0.14622 2-hydroxy-N,N,N- trimethylethanaminium chloride 67-48-1 1.30430 0.14483 Ulexite 1319-33-1 0.45445 0.05046 Ethylene Glycol 107-21-1 0.41626 0.04622 Diammonium peroxidisulphate 7727-54-0 0.34656 0.03848 Propan-2-ol 67-63-0 0.20253 0.02249 2-Propenoic acid, polymer with sodium phosphinate 129898-01-7 0.14325 0.01591 Alcohols, c11-15- secondary, ethoxylated 68131-40-8 0.10727 0.01191 2-butoxyethanol 111-76-2 0.09512 0.01056 Ethoxylated C11 Alcohol 34398-01-1 0.08737 0.00970 Vinylidene chloride/methylacrylate copolymer 25038-72-6 0.06177 0.00686 Sodium Tetraborate Decahydrate 1303-96-4 0.05023 0.00558 Ethoxylated Alcohol 68131-39-5 0.04742 0.00527 Sodium hydroxide (impurity) 1310-73-2 0.04374 0.00486 Methanol 67-56-1 0.03106 0.00345 Sodium chloride 7647-14-5 0.02893 0.00321 Sodium erythorbate 6381-77-7 0.02503 0.00278 Diatomaceous earth, calcined 91053-39-3 0.01457 0.00162 Calcium Chloride 10043-52-4 0.01462 0.00162 but-2-enedioic acid 110-17-8 0.01196 0.00133 Fatty acids, tall-oil 61790-12-3 0.00858 0.00095 Undecanol 112-42-5 0.00761 0.00084 Thiourea, polymer with formaldehyde and 1- phenylethanone 68527-49-1 0.00709 0.00079 0 E Non -crystalline silica 7631-86-9 0.00531 0.00059 (impurity) Alcohols, C14-15, 68951-67-7 0.00336 0.00037 ethoxylated (7EO) Methyl oxirane polymer 9003-11-6 0.00335 0.00037 with oxirane Magnesium nitrate 10377-60-3 0.00291 0.00032 Ethoxylated propoxylated 30846-35-6 0.00248 0.00028 4-nonylphenol- formaldehyde resin Alcohol, C7 -9 -iso, C8, 78330-19-5 0.00229 0.00025 ethoxylated Propargyl alcohol 107-19-7 0.00224 0.00025 Alcohol, C9 -11 -iso, C10, 78330-20-8 0.00214 0.00024 ethoxylated Magnesium silicate 14807-96-6 0.00189 0.00021 hydrate (talc) 2,2"-oxydiethanol 111-46-6 0.00155 0.00017 (impurity) 5 -chloro -2 -methyl -2h- 26172-55-4 0.00156 0.00017 isothiazolol-3-one Magnesium chloride 7786-30-3 0.00146 0.00016 Alcohol, C11-14, 78330-21-9 0.00149 0.00016 ethoxylated poly(tetrafluoroethylene) 9002-84-0 0.00080 0.00009 Hexadec-1-ene 629-73-2 0.00075 0.00008 Poly(oxy-1,2- 25322-68-3 0.00073 0.00008 ethanediyl),a-hydro-w- hydroxy- Ethane -1,2 -diol, ethoxylated Diutan 595585-15-2 0.00060 0.00007 Diutan gum 125005-87-0 0.00060 0.00007 Benzyllauryldimethylam 139-07-1 0.00051 0.00006 monium chloride Heavy aromatic naphtha 64742-94-5 0.00048 0.00005 2-methyl-2h-isothiazol-3- 2682-20-4 0.00047 0.00005 one Potassium chloride 7447-40-7 0.00046 0.00005 (impurity) E * Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water ** Information is based on the maximum potential for concentration and thus the total may be over 100% *** If you are calculating a percentage of total ingredients do not add the water volume below the green line to the water volume above the green line Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Data Sheets (MSDS) X11 i Octadec-1-ene 112-88-9 0.00037 0.00004 Acetic acid, potassium salt 127-08-2 0.00032 0.00004 Ammonium, diallyldimethyl-, chloride, polymers 26062-79-3 0.00038 0.00004 Cristobalite 14464-46-1 0.00029 0.00003 Dimethylbenzylmyristyla mmonium chloride 139-08-2 0.00018 0.00002 Naphthalene (Impurity) 91-20-3 0.00006 0.00001 Acetic acid (impurity) 64-19-7 0.00005 0.00001 Potassium oleate 143-18-0 0.00004 Benzyldimethylammoniu m chloride 122-18-9 0.00004 1,2,4 Trimethylbenzene (impurity) 95-63-6 0.00004 Formaldehyde 50-00-0 0.00003 * Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water ** Information is based on the maximum potential for concentration and thus the total may be over 100% *** If you are calculating a percentage of total ingredients do not add the water volume below the green line to the water volume above the green line Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Data Sheets (MSDS) X11 i • scmumbergep FracCAT Treatment Report: S -200A Stage 1 Well : S -200A Field : Aurora Formation : Kuparuk C Well Location 1,860 County : Prudhoe Bay State :Alaska Country : United States Prepared for Client : BP Exploration Alaska Client Rep Tyson Shriver Date Prepared : March 31, 2018 Prepared by 107,854 Name : Alexander Martinez Division : Schlumberger Phone : 561 389 5006 0 - Pressure (All Zones) Initia Initial Wellhead Pressure (psi) 563 Surface Shut in Pressure(psi) 1,834 Calibration Surface ISIP (psi) 1,860 Final Surface ISIP (psi) 2,020 Maximum Treating Pressure (psi) TotalsTreatment Zones Total Slurry Pumped (Water+Adds+Proppant) bbls 4,519 4386.8 Total YF128FIexD Past Wellhead (bbls) 1275.4 Total WF128 Past Wellhead (bbls) 2,962 Water (with chems) to displace acid (bbls) 0 Total Proppant Pumped (lbs.) 109,720 Total Proppant in Formation (lbs.) 107,854 Total 12% HCl Pumped (bbls) 30.0 Total 16/20 Carbolite Pumped (Ibs) 45,755 Total 16/30 Sand Pumped (Ibs) Total Chemical Additives Invoiced 5,720 Past WH Total 16/20 CarboBond Pumped (Ibs) Invoiced 58,245 Past WH F103 (gal) 80 80 M275 (lbs.) 48 40 L065 (gal) 131 131 J475 (lbs.) 578 578 L071 (gal) 241 241 J134 (lbs.) 10 0 J604 (gal) 155 155 M002 (lbs.) 68 68 J580 (lbs.) 4005 3,864 J218 (Ibs) 165 165 S123 (gal) 47 47 Disclaimer Notice This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. schlumbepoep Client: BP Exploration Alaska Well: S 200A Formation: Kuparuk C District: Prudhoe Bay Country: United States Executive Summary: On March 30th, equipment was primed and pressure tested the high pressure equipment. After the safety meetingthe PCM operator went out to mix gel and quickly found that the suction flowmeter was not functioning. That flowmeter is absolutely crucial to mixing gel on the fly. After 2 hours of trouble -shooting from the electronics technician and the mechanic, the decision was made to rig down the PCM and bring it back to the shop in Deadhorse so the maintenance team could work on it overnight. Through the night the maintenance team had the problem diagnosed to be a shorted cable from the flowmeter to the data acquisition box. The cable was replaced, PCM function tested in the shop and brought back out on the morning of the 311t The PCM was rigged back in by 09:00 and the PCM operator confirmed that the flowmeter functioned as required by pulling on a few bbls of water and confirming same with the flowmeter. The safety meeting began at 10:00, followed by the injection test at 10:30. Injectivity was less than desirable however on the first injection formation breakdown was observed around 3,800psi. Two more injections were performed, shortly after 11:30 BP made the decision to call out 30 bbls of 12% HCI acid, in order to dissolve some cement and open up the perforations. The acid tube arrived on location at 15:00 and spotted on the CT side, since the plan was for CT to spot the acid in the well and have the frac pumps chase it down to the perforations. By 16:00 CT had finished spotting the acid. When frac had pumped half of the acid into the formation, BP made the decision to shutdown and let the acid soak on bottom. There was approximately 800 psi gradual pressure decline as the acid hit the perforations. After waiting 20 minutes for the acid to soak and then came back online to displace the remaining 15 bbls of acid and attemptto get maximum rate afterward. Once we were able to sustain rate at 15 bbl/min BP made the decision to begin crosslink fluid and follow it with a 1,000 lbs sand scour at 0.5 PPA of 16/30 sand. As the sand hit bottom there was a 500 psi pressure decrease and we were able to increase rate up to 18 bbl/min before shutting down to get an ISIP and analyze the pressure decline. Upon shutdown we saw a water -hammer effect and it was the first so far of the treatment, an indication that communication between the well and the fracture improved. BP made the decision to pump another sand scour for a total of 2,300 lbs of 16/30 sand and there was nearly a 1,000 psi pressure drop allowing rate to be increased to 23 bbl/min before shutting down and getting another ISIP and analyze pressure decline. Fluid efficiency was estimated to be around 27% and BP made the decision to proceed with the main frac, yet with a more conservative frac design, limiting the maximum proppant concentration to 8PPA. The main fracture treatment went as planned. It started with a 2,200 lbs sand scour that consumed the remainder of the BP owned 16/30 sand. The proppant ramp began and we transition from 16/20 CarboLite to 16/20 CarboBond Lite seamlessly at the 8PPA step to finish out the sand ramp. There was a total of 46,000 lbs of 16/20 CarboLite and 58,000 lbs of CarboBond Lite pumped. The well was underflushed by the planned 3 bbl volume. scmumbroep Job Plots: Pressure Test 7000 6000 5000 4000 3000 2000 1000 0 09:37:45 09:44:25 • 0 Client: BP Exploration Alaska Well: S -200A Formation:Kuparuk C District: Prudhoe Bay Country: United States Tr. Pressure BP Exploration Alaska Annulus Pressure S -200A Slurry Rate March 31, 2018 Prop Con 20 25 BH Prop Con Stage 1: Injection 5000 ,iniection 4000 3000 2000 1000 0 10:21 :46 09:51:05 Time - hh:mm:ss 10:55:06 11:28:26 Time - hh:mm:ss 09:57:45 0 10:04:25 A] — Tr. Pressure 20 15 S -200A Slurry Rate 15 3. 10 20 16 — BH Prop Con 10 3. 0 5 15 12 5 0 10:04:25 A] — Tr. Pressure BP Exploration Alaska Annulus Pressure S -200A Slurry Rate March 31, 2018 — Prop Con 20 16 — BH Prop Con Waren n' Lines 14 15 12 10 10 8 6 5 4 2 0 0 12:01:46 12:35:06 0 Schlumberger 5000 4000 3000 2000 1000 0 13:28:14 Stage 1: Injection 5000 4000 N 3000 CL 0 M N 0- 2000 1000 0 15:32:33 133839 Stage 1 acid and scour 16:14:13 13:49:04 0 140954 Client: BP Exploration Alaska Well: S -200A — Tr. Pressure Formation: Kuparuk C District: Prudhoe Bay Alaska Annulus Pressure Country: United States — Tr. Pressure BP Exploration Alaska — Annulus Pressure S -200A Slurry Rate March 31, 2018 — ProgCon 20 16 40 — BH Prop Con — Flus acid away BH Prop Con 14 15 12 30 12 10 M 10 8 3 co 25 a 10 D 3 6 rr o 5 4 3 2 0 0 8 13:49:04 13:59:29 140954 Time - hh:mm:ss — Tr. Pressure BP Exploration Alaska Annulus Pressure S -200A Slurry Rate March 31, 2018 — Prop Con -- -- 40 16 — Flus acid away BH Prop Con 35 14 30 12 M co 25 a 10 D rr o 3 � 20 8 n 0 n �Cid soak 15 a 6 D 5' 10 4 5 2 t 0 0 16:55:53 17:37:33 18:19:13 Time - hh:mm:ss i • Schlumberger Client: BP Exploration Alaska Well: S -200A Formation:Kuparuk C District: Prudhoe Bay Country: United States - Stage 1 scour Tr. Pressure BP Exploration Alaska Annulus Pressure S -200A Slurry Rate March 31, 2018 Prop Con 5000 —- - -- 40 16 BH Prop Con r��• rn 3000 CL a 2000 1000 0 18:19:20 5000 4000 rn 3000 CL 18:52:40 Stage 1 Main Treatment 19:26:00 19:59:20 Time - hh:mm:ss Tr. Pressure - Annulus Pressure Slurry Rate Prop Con BH Prop Con 35 14 16 30 12 14 m i i 30 �25 T 10 Cr o 3 v n 20 8 0 25 T 0 n � 15 a 6 D 3 -10 4 5 �2 20 O 0 0 20:32:40 a- 2000 1000 0 20: c Time - hh:mm:ss BP Exploration Alaska S -200A March 31, 2018 40 16 -35 14 i i 30 -12 m m 25 T -10 rr o 9 v n 20 8 0 r) D 15 a 6 3 10 4 [5 �2 0 �0 • Schlumberger Section 1: As Measured Pump Schedule 0 Client: BP Exploration Alaska Well: S -200A Formation: Kuparuk C District: Prudhoe Bay Country: United States Ste p Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) MeasuredAs Pump Time (min) Pump Fluid Name Schedule Fluid Volume (gal) Proppant Name Pox Conic IPPA) IPPA) Prop (PPA) Prop Mass (lb) 1 Inject test 101.1 12.7 8.8 WF128 4248 0 0 0 2 In et test 47.8 8.2 6.2 WF128 2008 0 0 0 3 Inject test 241.4 7.7 30.2 WF128 10139 0 0 0 4 Inject test 15.8 3 5.3 WF128 664 0 0 0 5 Warming lines 1.8 3.8 4.4 WF128 76 0 0 0 6 In ect test 17.9 4.8 9.3 WF128 752 0 0 0 7 Acid (CT spot) 30 2 0.1 12% HCI 1260 0 0 0 8 Chase acid 213.2 6 35.7 WF128 8954 0 0 0 9 Shutdown Acid soak 0 0 20.0 0 0 0 0 10 Disp acid 225.8 12.4 18.2 WF128 9484 0 0 0 11 XL Pad 28.8 14.8 1.9 YF128FIexD 1210 0 0 0 12 0.5 PPA 71.8 15 4.8 YF128FIexD 2974 0.9 0.5 959 13 LG Disp 322.1 15.8 20.4 WF128 13570 0 0 0 14 Shutdow 0 0 0.0 0 0 0 0 15 XL Pad 32.2 10.7 1 3.0 YF128FIexD 1352 0 0 0 16 0.5 PPA 120.3 16.2 7.4 YF128FIexD 4935 0.7 0.5 2483 17 LG Disp 318.5 17.3 18.4 WF128 13377 0 0 0 18 Shutdow 0 0 0.0 0 0 0 0 19 Warming lines 25 6 4.2 WF128 861 0 0 0 20 Shutdow 0 1 0 0.0 0 0 0 1 0 21 Stg 1 Pad 150 6.3 24.3 YF128FIexD 6300 0 0 0 22 0.5 PPA 100 6.5 16.3 YF128FIexD 4218 16/30 Sand 0.8 0.5 2277 23 Pad 150 14.2 10.6 YF128FIexD 6301 0 0 0 24 1.0 PPA 50 14.7 3.4 YF128FIexD 2098 16/20 CarboLite 0 1.1 1688 25 1.0 PPA 45.9 14.8 3.1 YF128FIexD 1908 16/20 CarboLite 1.9 1.1 2175 26 2.0 PPA 45.5 15.1 3.0 YF128FIexD 1890 16/20 CarboLite 2.9 1 2.2 3786 27 3.0 PPA 46.1 15.1 3.1 YF128FlexD 1935 16/20 CarboLite 3.9 3 5169 28 4.0 PPA 45.5 15.1 3.0 YF128FlexD 1908 16/20 CarboLite 4.9 4 6466 29 5.0 PPA 45.9 15.1 1 3.0 YF128FlexD 1926 16/20 CarboLite 5.9 5 7660 30 6.0 PPA 46.2 15 3.1 YF128FlexD 1941 16/20 CarboLite 6.9 6 8812 31 7.0 PPA 46.6 15.5 3.0 YF128FlexD 1957 16/20 CarboLite 7.9 7 1 10000 32 8.0 PPA CBL 44.5 17.7 2.5 YF128FlexD 1869 16/20 CarboBond 8.2 8 12263 33 8.0 PPA 173.1 16.1 11.4 YF128FlexD 1 7186 16/20 CarboBond 8.1 8 45982 34 Flush YF 40 16.7 2.4 YF128FIexD 1658 0 0 0 35 FLUSH 1544 22.5 1 75.9 WF128 60271 0 0 0 • Schlumberger 0 Client BP Exploration Alaska Well: S -200A Formation:Kuparuk C District: Prudhoe Bay Gauntry: United States Average Treating Pressure: 4160 psi Stage Pressures Minimum Treating Pressure: 86 psi Average Injection Rate: Step N Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Minimum Treating Pressure Pressure (psi) (psi) 1 Inject test 12.7 13.6 4207 4519 584 2 1 nj et test 8.2 9 3931 4133 1723 3 Inject test 7.7 9.3 4192 4477 86 4 Inject test 3 5 1510 86 86 5 Warming lines 3.8 3 2946 3867 1464 6 Inject test 4.8 5.1 3524 3844 1108 7 Acid (CT spot) 2 - - - - 8 Chase acid 6 7.4 4277 4470 1917 9 Shutdown Acid soak 0 0 1321 2945 1020 10 Disp acid 12.3 15 4102 4458 1445 11 XL Pad 14.8 15 4392 4479 4340 12 0.5 PPA 15 15.1 4360 4429 4206 13 LG Disp 15.8 18.5 4297 4439 2285 14 Shutdow 0 0 1380 2013 1229 15 XL Pad 11.4 16 3485 4281 1321 16 0.5 PPA 16.2 16.7 4142 4318 3976 17 LG Disp 17.3 22.5 4117 4439 2191 18 Shutdow 0 0 1366 2701 1096 19 Warming lines 6 2.8 2181 2327 1763 20 Shutdow 0 0 1282 2034 1118 21 Stg 1 Pad 6.3 7.4 4344 4464 1921 22 0.5 PPA 6.5 12.3 3983 4448 1637 23 Pad 14.2 14.9 4358 4447 4146 24 1.0 PPA 14.7 14.7 4392 4404 4370 25 1.0 PPA 14.8 15 4385 4457 4348 26 2.0 PPA 15.1 15.1 4352 4386 4299 27 3.0 PPA 15.1 15.1 4367 4396 4340 28 4.0 PPA 15.1 15.1 4402 4416 4389 29 5.0 PPA 15.1 15.1 4414 4435 4390 30 6.0 PPA 15 15 4324 4426 4136 31 7.0 PPA 15.5 17.1 4053 4249 3894 32 8.0 PPA CBL 17.7 18.2 4274 4357 4225 33 8.0 PPA 16.1 18.1 4115 4363 1390 34 Flush YF 16.7 16.7 4218 4267 1 4149 35 FLUSH WF 1 22.5 29.1 4104 1 4419 1 1228 Average Treating Pressure: 4160 psi Maximum Treating Pressure: 4519 psi Minimum Treating Pressure: 86 psi Average Injection Rate: 8.9 bbl/min Maximum Injection Rate: 13.6 bbl/min Average Horsepower: 927.1 hhp Maximum Horsepower: 1486.5 hhp Maximum Prop Concentration: 0.0 PPA LJ Schlumberlgep Section 2: Job Messages 0 Client: BP Exploration Alaska Well: 5-200A Formation: Kuparuk C District: Prudhoe Bay Country: United States # Time Message Log Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 16:52:50 Reset Executed Steps 0 0 0 0 0 2 16:52:50 Reset Executed Steps 0 0 0 0 0 3 07:41:09 CREW ARRIVE LOCATION 07:00 79 93 0 0 0 4 07:59:20 FIRING PUMPS 81 93 0 10.5 0 5 09:07:02 PRIMING POD ON FP 81 92 0 0 0 6 09:10:18 LINES FILLED OVERTOP 114 92 0 0 0 7 09:13:27 PRIMING PUMP 1 AS PER FPC 129 92 0 4.4 0 8 09:15:49 PRIMING PUMP 2 AS PER FPC 130 92 0 4.5 0 9 09:20:18 PRIMING PUMP 3 AS PER FPC 247 93 0 6.9 0 10 09:21:06 PRIMING PUMP 4 AS PER FPC 246 92 0 6.7 0 11 09:26:27 PRIMING PUMP 5 AS PER FPC 376 92 0 4.6 0 12 09:27:48 PRIMING PUMP 6 AS PER FPC 312 92 0 4.6 0 13 09:47:33 EQUALIZIN PSI ON EACH PUMP BOTH SIDES OF CHECK VALVES 6101 92 0 0 0 14 09:55:16 LINE CHECK PASS NO LEAKS 6354 92 0 0 0 15 09:57:30 MIXING GEL ON PCM 4355 92 0 0 0 16 09:59:37 Remark 130 92 0 0 0 17 10:36:05 Start Inject test Automatically 1517 1642 0 0 0 18 10:36:05 Start Propped Frac Automatically 1517 1642 0 0 0 19 10:36:05 Start Stage 1 Desi Automatically 1517 1642 0 0 0 20 1 10:36:21 Started Pumping 1511 1647 0 0 0 21 10:39:00 Activated Extend Stage 3946 1910 11.3 12.6 0 22 10:46:24 SHUTDOWN INJECTION TEST 2161 1793 101.1 0 0 23 10:53:45 Deactivated Extend Stage 1842 1789 101.1 0 0 24 10:53:45 Start DF YF128 Manually 1842 1789 101.1 0 0 25 10:56:11 GOOD XL SAMPLE 3924 1959 115.9 7.7 0 26 10:59:23 Activated Extend Stage 4118 1 1976 144.6 9 0 27 11:00:00 SHUTDOWN GEL STOPPED MIXING 2902 1907 148.9 0 0 28 11:07:27 Deactivated Extend Stage 2000 1795 148.9 2 0 29 11:07:27 Start In ect test Manually 2000 1795 148.9 2 0 30 11:07:53 START LG FLUSH DUE TO HIGH FRICTION 3094 1907 150.1 3.3 0 31 11:08:22 Activated Extend Stage 3474 1929 151.7 4 0 32 11:18:04 Stage at Perfs: Inject test 4289 1989 232.5 8.1 0 33 11:19:45 CONTINUE WF FOR BREAKDOWN 4194 1979 246.4 8.4 0 34 11:29:59 Sta a at Perfs: Inject test 4357 2000 333.6 7.4 0 35 11:30:11 XL BH 4357 2000 335.1 7.4 0 36 11:36:29 Stage at Perfs: Inject test 4436 1996 381.5 7.3 0 37 11:37:38 SHUTDOWN WF FLUSH 4284 1986 389.9 7.4 0 38 12:12:27 WARMING LINES DOWN WELL 1374 1679 390.3 0 0 39 12:16:27 ALL PUMPS MIN RATE WARMING LINES 3780 1866 399.7 5 0 40 12:17:40 SHUTDOWN WARMING LINES 3440 1858 405.8 2.6 0 41 12:23:19 WELL CLOSED 1655 1690 405.8 0 0 42 13:32:30 PRIMING PUMP 5 AS PER FPC 113 1 1600 407.6 2.6 0 43 13:42:29 LOW PT ON PUMP 5 154 1595 407.6 0 0 44 13:48:47 WELL OPEN WARMING LINES DOWNHOLE 1000 1592 407.6 0 0 45 13:52:05 Started Pumping 3721 1820 407.6 5.2 0 46 13:55:37 SHUTDOWN WARMING LINES 3381 1786 425.5 0.3 0 47 14:11:33 WELLHEAD CLOSED 87 1599 425.5 0 0 48 14:15:13 JACID TRANSPORT LEAVES THE SHOP 1 86 1593 425.5 0 0 Schlumberger Client: BP Exploration Alaska Well: 5 200A Formation: Kuparuk C District: Prudhoe Bay Country: United States # Time Message11 Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. IPPA) 49 14:38:43 Started Pumping 86 1569 425.5 0 0 50 14:38:57 Deactivated Extend Stage 86 1569 425.5 0 0 51 14:38:57 Start Inject test Manually 86 1569 425.5 0 0 52 14:42:00 Started Pumping 85 1567 425.5 5 0 53 14:42:11 Stopped Pumping 86 1567 426.5 5 0 54 15:02:33 ACID TRANSPORT ARRIVE LOCATION 85 1558 426.5 0 0 55 Reset Executed Steps 0 0 0 0 0 56 Reset All Totals 0 0 0 0 0 57 1 16:08:36 Start Inject test Automatically 1891 1657 1 0 0 0 58 16:08:36 Start Propped Frac Automatically 1891 1657 0 0 0 59 16:08:36 Start Sta e 1 Desi Automatically 1891 1657 0 0 0 60 16:08:36 Started Pumping 1891 1657 0 0 0 61 16:08:46 Start Stq 1 Pad Automatically 2012 1666 0.1 1 0 62 16:31:26 at Perfs: Inject test 4442 1862 140.6 5.9 0 63 16:31:27 _Stage Stage at Perfs: 8.0 PPA 4444 1861 140.7 5.8 0 64 16:33:05 Start 0.5 PPA Automatically 4424 1 1862 150.2 5.8 0 65 16:33:05 Started Pumping Prop 4424 1862 150.2 5.8 0 66 16:44:16 Stopped Pumping Prop 2964 1764 213.2 0.2 0 67 16:44:16 Stopped Pumping 2964 1764 213.2 0.2 0 68 17:04:24 Started Pumping 1249 1572 213.2 0 0 69 17:04:24 Started Pumping Prop 1249 1572 213.2 0 0 70 17:09:30 Start Pad Automatically 4151 1807 250.3 12.3 0 71 17:12:33 Stage at Perfs: 8.0 PPA 4319 1824 290.4 13.8 -0.1 72 17:19:25 Stage at Perfs: 9.0 PPA 4383 1866 390.9 14.7 0 73 17:20:03 Start 1.0 PPA Automatically 4373 1872 400.3 14.7 0 74 17:23:27 Start 1.0 PPA Automatically 4361 1989 450.3 14.7 0 75 17:26:32 Start 2.0 PPA Automatically 4364 2030 496.1 15 0.3 76 17:29:31 Stage at Perfs: 10.0 PPA 4342 2092 541.1 15 0 77 17:29:33 Start 3.0 PPA Automatically 4337 2092 541.6 15.1 0.1 78 17:32:37 Start 4.0 PPA Automatically 4409 2109 587.9 15.1 0 79 17:32:50 Sta e At Perfs 4406 2105 591.2 15.1 0 80 17:35:38 Start 5.0 PPA Automatically 4416 2133 633.4 15.1 0 81 17:35:52 Stage At Perfs 4406 2135 636.9 15.1 0 82 17:38:40 Start 6.0 PPA Automatically 4412 2137 679.1 15 0 83 17:38:53 Stage At Perfs 4419 2129 682.4 15 0 84 17:41:46 Start 7.0 PPA Automatically 4109 2099 725.5 15 0 85 17:41:59 Stage At Perfs 4069 2095 728.7 15 0 86 17:44:46 Start 8.0 PPA CBL Automatically 4248 2093 772.1 17.2 0 87 17:44:53 Sta a At Perfs 4256 2098 774.1 17.4 0 Start 8.0 PPA Automatically 4354 2094 1 816.5 18.1 0 r17:47:16 1 17:47:27 Stage At Perfs 4331 2088 1 819.8 17.8 0 • scmumbelep FracCAT Treatment Report: S -200A Stage 2 Well : S -200A Field : Aurora Formation : Kuparuk C Well Location 1,830 County : Prudhoe Bay State :Alaska Country : United States Prepared for Client : BP Exploration Alaska Client Rep : Tyson Shriver Date Prepared : April 2, 2018 Prepared by 137,074 Name : Alexander Martinez Division : Schlumberger Phone : 561 389 5006 Pressure (All .- Initial Wellhead Pressure (psi) 1,013 Surface Shut in Pressure(psi) 1,590 Calibration Surface ISIP (psi) 1,830 Final Surface ISIP (psi) 1,800 Maximum Treating Pressure (psi) TotalsTreatment Zones Total Slurry Pumped (Water+Adds+Proppant) (bbls) 4,415 1,980.2 Total YF128FIexD Past Wellhead (bbls) 1,136 Total WF128 Past Wellhead (bbls) 418.8 Water (with chems) to displace acid (bbls) 281.9 Total Proppant Pumped (lbs.) 139,445 Total Proppant in Formation (lbs.) 137,074 Total 12% HCI Pumped (bbis) 50.1 Total 16/20 Carbolite Pumped (Ibs) 58,245 Total 16/30 Sand Pumped (Ibs) Total Chemical Additives Invoiced 0 Past VVH Total 16/20 Carbol3ond Pumped (Ibs) Invoiced 81,200 Past VVH F103 (gal) 77 77 M275 (lbs.) 40 38 L065 (gal) 74 74 J475 (Ibs.) 357 357 L071 (gal) 266 266 J134 (lbs.) 10 0 J604 (gal) 127 127 M002 (lbs.) 47 47 J580 (Ibs.) 1913 1,819 J218 (Ibs) 110 110 S123 (gal) 39 39 Disclaimer Notice This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. • U Client: BP Exploration Alaska Well: S -200A Formation: Kuparuk C District: Prudhoe Bay Country: United States SWUMbelep Client BP Exploration Alaska Well: S 200A Formation Kuparuk C District: Prudhoe Bay Country: United States Executive Summary: On April 2°d, 2018 Schlumberger performed stage 2 propped fracture treatment on S -200A. The night before CT had run in hole and perforated zone 2. The morning of the 2n1 CT was setting a plug between zone 1 and zone 2. Upon setting the plug CT performed an injection test and were experiencing high pressures at low rates so BP made the decision to call out 50 bbls of 12% HCI acid. Upon firing up the frac equipment in the morning, the sand chief wouldn't start and it was determined that it needed a new starter. The starter was hotshotted from Deadhorse and replaced in the early afternoon without causing any downtime. CT was back on surface in the early afternoon and frac began priming pumps and pressure testing. After a safety meeting CT began spotting the 50 bbls of acid in the well. Once the acid was in the pipe, the frac pumps came online to chase acid down to the perforations with fresh water, containing 1 gpt F103, 2gpt L071 and 1 gpt L065.25 bbls of the acid was pumped past the perfs and then pumps were shutdown to let the acid soak for 25 minutes. After the soak we came back online with the frac pumps in an effort to get maximum rate. With the first pump trip at 4,500 psi, pressure allowed us to get to approximately 19 bbls/min before shutting down to get an ISIP. In total there was approximately a 500 psi pressure drop from the HCI acid. The decision was made to pump a 2,000 lbs sand scour with 16/20 CarboLite and again we saw another 500 psi pressure drop from the scour. We shutdown to monitor decline, which did not allow to pick a unique closure event, rather several steps were observed, possibly from different layers of the reservoir closing on the sand scour. From here BP made a plan to pump the remaining sand on surface that was left over from stage 1 which included 58,000 lbs of CarboLite (including the scour) and 81,000 lbs of CarboBond Lite for a total of 139,000 lbs. Overall the main frac went well with no major issues to report, all the proppant was pumped. Towards the end of flush, BP made the decision to drop rate further in an attemptto pinch off the frac yet pressure kept declining. Flush was completed with the 3 bbls planned underflush. scmumbe"Op Job Plots: Pressure Test 7000 6 5 n 4 m a e 3 o. 2 1 18 Tr. Pressure Annulus Pressure Slurry Rate Prop Con 0 Client: BE Exploration Alaska Well: S -200A Formation: Kuparuk C District: Prudhoe Bay Country: United States 5000 4000 a 3000 CL m N m 0 2000 1000 0 16:41:24 Time • hh:mm:ss Stage 2: Acid Displacement Tr. Pressure Annulus Pressure — Slurry Rate Prop Con BI I Prop Con BP Exploration Alaska S -200A April 2, 2018 40 16 35 14 30 12 A d m 25 c a 10 3 20 c a n 8 ° � 15 Q v v 6 D 3 10 4 -5 t- 2 0 16.0502 0 BP Exploration Alaska S -200A April 2, 2018 –20 16 14 12 10 v 0 ,s 0 8 0 17 6 D 4 2 0 17:02:14 17:23:04 17:43:54 Time • hh:mm:ss 10 18:04:44 0 schlumbopgop 5000 4000 w 3000 a w O 0 2000 1000 0 18:0 5000 40 Stage 2: Sand Scour Tr. Pressure Annulus Pressure Slurry Rate Prop Con • Client: BP Exploration Alaska Well: S -200A Formation: Kuparuk C District: Prudhoe Bay Country: United States BP Exploration Alaska S -200A April 2, 2018 40 35 30 A m m 25 v c 3 20 N r1 15 v 3 10 5 0 1:54 Time - hh:mm:ss — Tr. Pressure Stage 2: Main Treatment — Annulus Pressure — Slurry Rate — Prop Con _ SH Prop Corr BP Exploration Alaska S -200A April 2, 2018 40 I 35 F I 30 k ;Ai m 25 v v 3 20 � N n 15 6 3 3 10 5 0 a 20 10 1 Time - hh:mm:ss 16 14 12 10 'o v n 8 0 V 6 D 4 2 0 16 14 12 10 'o 0 8 0 T 6 D 4 2 0 0 Schlumbopgop 40 c 30 m C9 Z 20 a y N E 10 U 0- 0 1655:26 Additives: Stage 2 17:45:26 18:35:26 Time - hh:mm:ss • Client: BP Exploration Alaska Well: S -200A Formation: Kuparuk C District: Prudhoe Bay Country: United States — Slurry Rate gp Exploration — CFLD Rate S -200A PCM Visc April 2, 2018 — J475 Conc — — J218 Conc L065 Conc 16 -10 — F103 Conic 9 — J604 Conc L071 Conc 14 — U028 Conc 8 — S123 Conc 12 ,- 00 7CL � c 10 c(o 6 n 0 N o 0 Er 6 N 4 v w -3 cc 4 � 2 �2 1 0 �0 19:25:26 20:15:26 • Schlumberger Section 1: As Measured Pump Schedule 0 Client: BP Exploration Alaska Well: S -200A Formation: Kuparuk C District: Prudhoe Bay Country: United States MeasuredAs Pump Schedule Step I Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (Ib) 1 Spot Acid 281.9 12.5 24.3 Water+ chems 11841 0 0 0 2 Shutdown 0 12.5 0 Water +chems 0 0 0 0 3 PAD 35.4 10.3 3.7 YF128FIexD 1487 16/30 Sand 0 0 0 4 0.5 PPA 100.1 20 5.2 YF128FIexD 4122 16/20 CarboLite 0.6 0.5 1869 5 XL Disp 20 21.8 0.9 YF128FIexD 837 0.5 0.1 0 6 LG Disp 235.2 24.6 9.6 WF128 9879 0 0 0 7 Shutdown 6.5 2.5 6.6 WF128 275 0 0 0 8 Pad 150 26.8 6.3 YF128FIexD 6300 0 0 0 9 0.5 PPA 100.1 30.9 3.2 YF128FlexD 4123 16/20 CarboLite 0.5 0.5 1856 10 Pad 150 31.7 4.7 YF128FlexD 6295 16/20 CarboLite 0.5 0 130 11 1.0 PPA 50 31.5 1.6 YF128FlexD 2025 16/20 CarboLite 1 0.8 1657 12 1.0 PPA 44.9 31.4 1.4 YF128FIexD 1806 16/20 CarboLite 1 1 1770 13 2.0 PPA 44.6 31.4 1.4 YF128FIexD 1733 16/20 CarboLite 2 1.8 3122 14 3.0 PPA 45.2 31.8 1.4 YF128FlexD 1690 16/20 CarboLite 3 2.8 4704 15 4.0 PPA 45.1 32.2 1.4 YF128FIexD 1621 16/20 CarboLite 4.1 3.9 6131 16 5.0 PPA 45.1 32.2 1.4 YF128FIexD 1560 16/20 CarboLite 5.1 4.9 7466 17 6.0 PPA 45.4 31.9 1.4 YF128FIexD 1519 16/20 CarboLite 6.2 5.9 8728 18 7.0 PPA 45.7 31.9 1.4 YF128FlexD 1478 16/20 CarboLite 7.1 6.8 9899 19 8.0 PPA 45.9 31.6 1.5 YF128FIexD 1439 16/20 CarboLite 8.1 7.8 10911 20 8.0 PPA 50.3 31.2 1.6 YF128FIexD 1552 16/20 CBL 8.1 8 13342 21 9.0 PPA 50.6 29.8 1.7 YF128FIexD 1515 16/20 CBL 9.3 8.9 14442 22 10.0 PPA 50.8 27.9 1.8 YF128FlexD 1478 16/20 CBL 10.1 9.8 15482 23 11.0 PPA 50.8 27.7 1.8 YF128FlexD 1432 16/20 CBL 11.1 10.9 16656 24 12.0 PPA 69.3 27.6 2.5 YF128FIexD 2023 16/20 CBL 13.3 9.9 21210 25 XL Flush 40 27 1.5 YF128FIexD 1677 16/20 CBL 0.1 0 67 26 Flush 177 26.1 6.9 WF128 7434 0 0 0 0 Schlumberger 0 Client: BP Exploration Alaska Well: S -200A Formation: Kuparuk C District: Prudhoe Bay Country: United States Average Treating Pressure: 3998 psi Stage Pressures • Rates 627 psi Average Injection Rate: Step # Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Minimum Treating Pressure Pressure (psi) (psi) 1 Spot Acid 12.5 19.4 4104 4415 666 2 Shutdown 12.5 0.0 4104 1485 640 3 PAD 10.3 10.2 3035 3155 627 4 0.5 PPA 20.0 22.1 4039 4307 3129 5 XL Disp 21.8 22.0 3968 4043 3899 6 LG Disp 24.6 25.4 4009 4345 1688 7 Shutdown 2.5 1.0 1718 1985 964 8 Pad 26.8 30.2 3753 4057 1137 9 0.5 PPA 30.9 31.6 4198 4291 4054 10 Pad 31.7 31.7 4295 4337 4171 11 1.0 PPA 31.5 31.7 4049 4168 3956 12 1.0 PPA 31.4 31.5 3901 3956 3866 13 2.0 PPA 31.4 31.7 3838 3869 3801 14 3.0 PPA 31.8 32.5 3841 3880 3777 15 4.0 PPA 32.2 32.4 3828 3849 3811 16 5.0 PPA 32.2 32.6 3844 3862 3826 17 6.0 PPA 31.9 32.2 3912 3970 3867 18 7.0 PPA 31.9 32.0 4060 4128 3972 19 8.0 PPA 31.6 31.9 4214 4283 4100 20 8.0 PPA 31.2 31.9 4296 4307 4278 21 9.0 PPA 29.8 30.5 4230 4316 4004 22 10.0 PPA 27.9 28.2 4010 4036 3990 23 11.0 PPA 27.7 28.0 4034 4043 4024 24 12.0 PPA 27.6 27.7 4045 4067 4017 25 XL Flush 27.0 27.9 4074 4261 3909 26 Flush 26.1 26.8 3847 4344 2520 Average Treating Pressure: 3998 psi Maximum Treating Pressure: 4415 psi Minimum Treating Pressure: 627 psi Average Injection Rate: 25.6 bbl/min Maximum Injection Rate: 32.6 bbl/min Average Horsepower: 2523.1 hhp Maximum Horsepower: 3369.0 hhp Maximum Prop Concentration: 13.3 PPA i Schlumberger Section 2: Job Messages • Client: BE Exploration Alaska Well: S 200A Formation: Kuparuk C District: Prudhoe Bay Country United States Message Log # Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 Reset Executed Steps 0 1 0 0.0 0.0 0.0 2 Reset Executed Steps 0 0 0.0 0.0 0.0 3 13:45:38 Remark 0 0 0.0 0.0 0.0 4 13:45:47 CREW ARRIVE 06:45 243 30 0.0 6.9 0.0 5 13:46:01 CID TRANSPORT LEAVE SHOP 10:00 AM ARRIVE LOCATION 11:14 AM 244 30 0.0 6.9 0.0 6 13:46:34 FIRE PUMPS 12:49 PM 203 30 0.0 5.8 0.0 7 14:12:20 PRIMING PUMPS AS PER FPC 196 31 0.0 5.9 0.0 8 14:52:06 GLOBAL TRIP WORKING 2662 629 0.0 0.0 0.0 9 15:10:18 LOW PT PASS AS PER CLIENT 437 629 0.0 0.0 0.0 10 15:37:27 HIGH PT PASS 6833 PSI TO 6653 PSI 180 PSI LOSS 5 MIN 6603 627 0.0 0.0 0.0 11 15:40:48 CLIENT ACCEPTS HIGH PT 868 627 0.0 0.0 0.0 12 16:12:29 COIL PUMPING ACID 1BPM 96 884 0.0 0.0 0.0 13 16:20:50 2 BPM 4200 PSI 94 2064 0.0 0.0 0.0 14 16:23:33 2.7 BPM 3500 PSI 94 2020 0.0 0.0 0.0 15 16:24:57 3.1 BPM 4000 PSI 94 2050 0.0 0.0 0.0 16 16:29:25 3.5 BPM 3500 PSI 93 2033 0.0 0.0 0.0 17 16:51:37 Start Spot Acid Automatically 98 1933 0.0 0.0 0.0 18 16:51:37 Start Propped Frac Automatically 98 1933 0.0 0.0 0.0 19 16:51:37 Start Stage 2 Frac Automatically 98 1933 0.0 0.0 0.0 20 16:51:46 Started Pumping 114 1931 0.0 0.0 0.0 21 16:51:56 Start Shutdown Manually 111 1929 0.0 0.0 0.0 22 16:52:14 Start Spot Acid Automatically 189 1924 0.0 0.3 0.0 23 16:52:42 Start Spot Acid Manually 2071 1919 0.1 0.0 0.0 24 16:54:40 WELLHEAD OPEN 1095 1907 0.1 0.0 0.0 25 16:55:35 233/8TURNS 1059 1893 0.1 0.0 0.0 26 16:56:13 Reset Executed Steps 1024 1920 0.1 0.0 0.0 27 16:56:13 Reset All Totals 1024 1920 0.1 0.0 0.0 28 16:56:13 Start Spot Acid Automatically 1024 1920 0.1 0.0 0.0 29 16:56:13 Started Pumping 1024 1920 0.1 0.0 0.0 30 16:59:19 START PUMPING 4327 2090 23.9 13.0 0.0 31 17:13:28 PUMPS DOWN 25 BLS IN FORMATION 2869 1993 185.5 0.9 0.0 32 17:27:41 START PUMPING AGAIN 735 1761 185.5 0.0 0.0 33 17:30:58 ACID PUMPED AWAY INC RATE 3662 1989 213.7 10.2 0.0 34 17:32:16 Stage at Perfs: Spot Acid 4090 2013 232.6 16.0 0.0 35 17:32:33 Remark 4147 2013 237.1 16.0 0.0 36 17:35:18 PUMPS DOWN ACID INJECTED 1729 1848 281.9 0.0 0.0 37 17:37:41 Start Shutdown Manually 1475 1844 281.9 0.0 0.0 38 17:54:43 MIXING GEL FOR SCOUR STAGE 690 1744 281.9 0.0 0.0 39 17:59:22 Start PAD Manually 638 1730 281.9 0.0 0.0 40 18:04:00 GOOD XL 3124 1931 311.7 10.1 0.0 41 18:04:31 Started Pumping Prop 3132 1934 317.0 10.2 0.0 42 18:04:33 Start 0.5 PPA Manually 3129 1936 317.3 10.2 0.1 43 18:08:33 10.1 PH 4157 2055 391.3 22.1 0.5 44 18:09:46 IStart XL Disp Automatically 4037 2062 417.7 21.8 0.5 45 18:09:54 IStDpped Pumping Prop 4013 2062 420.6 1 21.8 0.4 0 Schlumberger 0 Client BP Exploration Alaska Well: S -200A Formation: Kuparuk C District Prudhoe Bay Country: United States # Time Message Message Log Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. IPPA) 46 18:10:41 Start LG Disp Automatically 3881 2065 437.8 22.0 0.0 47 18:10:50 START LG AT SURFACE 3879 2065 441.1 22.0 0.0 48 18:13:58 Stage at Perfs: 0.5 PPA 4299 2116 514.6 25.0 0.0 49 18:15:23 Stage at Perfs: XL Disp 4244 2111 550.2 25.3 0.0 50 18:19:22 Stage at Perfs: LG Disp 3769 2128 650.8 25.2 0.0 51 18:20:09 Stage at Perfs: LG Disp 3720 2092 670.6 25.3 0.0 52 18:21:07 Start Shutdown Manually 1682 1971 672.7 0.0 0.0 53 18:43:22 WARMING PUMP DOWN WELL 982 1810 672.7 1.0 0.0 54 18:54:56 Start Pad Manually 1178 1806 679.2 1.0 0.0 55 18:56:13 INC FRAC RATE 2896 1 1923 690.3 15.1 0.0 56 18:57:09 GOOD XL 10.2 PH 3503 1964 709.0 25.0 0.0 57 19:01:16 Start 0.5 PPA Automatically 4045 2072 829.3 30.0 0.0 58 19:01:19 Started Pumping Prop 4052 2073 830.8 30.0 0.0 59 19:03:45 Stage at Perfs: Pad 4267 2126 905.7 31.4 0.5 60 19:03:57 Stage at Perfs: 0.5 PPA 4276 2132 912.0 31.5 0.5 61 19:04:31 Start Pad Automatically 4281 1 2138 929.8 31.5 0.5 62 19:04:48 Stopped Pumping Prop 4304 2143 938.8 31.5 0.1 63 19:08:42 Stage at Perfs: Pad 4255 2166 1062.3 31.7 0.0 64 19:09:15 Start 1.0 PPA Automatically 4157 2161 1079.7 31.7 0.0 65 19:09:17 Started Pumping Prop 4156 2160 1080.8 31.8 0.0 66 19:10:50 Start 1.0 PPA Automatically 3944 2151 1129.6 31.4 1.0 67 19:11:54 Stage at Perfs: 1.0 PPA 3866 2145 1163.1 31.6 1.0 68 19:12:16 Start 2.0 PPA Automatically 3863 2144 1174.7 31.4 1.0 69 19:13:41 Start 3.0 PPA Automatically 3774 2136 1219.1 31.2 2.0 70 19:15:06 Start 4.0 PPA Automatically 3854 2130 1264.3 32.3 3.0 71 19:16:30 Start 5.0 PPA Automatically 3826 2115 1309.4 32.3 4.0 72 19:16:37 Stage at Perfs: 1.0 PPA 3839 2115 1313.2 32.5 4.0 73 19:17:54 Start 6.0 PPA Automatically 3869 2100 1354.5 32.0 5.0 74 19:18:10 Stage at Perfs: 2.0 PPA 3884 2103 1363.1 32.2 5.7 75 19:19:20 Start 7.0 PPA Automatically 3954 2083 1400.2 31.9 6.0 76 19:19:34 Stage at Perfs: 3.0 PPA 3993 2087 1407.6 31.6 6.6 77 19:20:46 Start 8.0 PPA Automatically 4079 2071 1445.9 31.7 7.0 78 19:20:58 Stage at Perfs: 4.0 PPA 4130 2076 1452.2 31.4 7.2 79 19:21:21 START CARBOBOND 4260 2079 1464.3 32.0 8.1 80 19:22:13 Start 8.0 PPA Automatically 4300 2067 1491.7 31.7 7.8 81 19:22:24 Stage at Perfs: 5.0 PPA 4287 2064 1497.6 31.8 8.1 82 19:23:50 Start 9.0 PPA Automatically 4307 2041 1542.0 30.5 8.0 83 19:23:51 Stage at Perfs: 6.0 PPA 4298 2038 1542.5 30.5 8.0 84 19:24:07 DEC RATE FOR PSI 4213 2034 1550.7 30.0 8.9 85 19:25:22 Stage at Perfs: 7.0 PPA 4004 2004 1587.7 28.2 9.4 86 19:25:32 Start 10.0 PPA Automatically 4011 2004 1592.4 28.0 9.1 87 19:27:00 Stage at Perfs: 8.0 PPA 4017 1979 1633.4 27.6 9.9 88 19:27:21 Start 11.0 PPA Automatically 4034 1974 1643.1 28.1 9.9 89 19:28:39 Stage at Perfs: 8.0 PPA 4023 1955 1679.1 27.6 11.0 90 19:29:12 Start 12.0 PPA Automatically 4049 1945 1694.3 27.6 10.9 91 19:29:18 Activated Extend Stage 4056 1944 1697.1 27.7 11.0 92 19:30:18 Stage at Perfs: 9.0 PPA 4036 1924 1724.7 27.7 12.1 93 19:31:42 Start XL Flush Manually 4083 1906 1763.2 27.7 0.1 94 19:32:08 Stage at Perfs: 10.0 PPA 3960 1888 1775.1 26.8 0.1 C� schlumberIgep Client: BP Fxploration Alaska Well: S -200A Formation: Kuparuk C District: Prudhoe Bay Country: United States Message11 # Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. IPPA) 95 19:32:29 Stopped Pumping Prop 4087 1882 1784.5 26.8 0.0 96 19:33:11 Start Flush Automatically 4272 1883 1803.3 26.7 0.0 97 19:34:01 Stage at Perfs: 11.0 PPA 4334 1898 1825.4 26.5 0.0 98 19:34:29 STOP MIX GEL 4301 1965 1837.8 26.7 0.0 99 19:35:56 Stage at Perfs: 12.0 PPA 4025 1984 1876.4 26.6 0.0 100 19:37:51 Stage at Perfs: XL Flush 3653 1977 1927.5 26.7 0.0 101 19:40:04 PUMPS DOWN 1064 1848 1980.2 0.4 0.0 102 20:08:08 30 MIN 1597 1816 1980.2 0.0 0.0 103 20:08:10 WELLHEAD CLOSED 1597 1816 1980.2 0.0 0.0 104 20:08:34 BLEEDING LINES TO ZERO 1590 1816 1980.2 0.0 0.0 105 20:11:06 FLUSHING SURFACE EQUIP WITH FREEZE PROTECT 126 1812 1980.2 0.0 0.0 106 20:24:17 FANNING PUMPS -3750 1794 1980.2 22.4 0.0 TREE = CIW 4-1/16' DBL MSTR DRY HDLE WELLHEAD = 11" 5M FMC ACTUATOR = Note: Refer to Production DB for historical pert data OIB = 66.58' Opn/Sgz SHOT SOZ 82.32' BF. —8 -EV - 36.48` KOP = 2734' Max Angle = 104" @ 15120' Datum MD = 9049 Datum TVD = 5000' SS 9-5/8" VN-IPSTOCK (10/28/1 2734' 9-5/8" CSG, 479, L-80 BTC, ID = 8.681' -2734' Minimum ID = 3.725" a@ 13955' 4-1/2" HES XN NIPPLE TOP OF CEMENT (11/17117) 7911' V ERIFIED w /IBC CEMENT LOG 4 TOP OF 4-112" LNIR ( 13966' 4-112" TBG, 12.6#, 13CR-85 VAM TOP,13973' 0152 bpf, D = 3.958" 7" CSG, 26#, L-80 VAM TOP, I-L_1414W 0383 bpf, D = 6276" PERFORATION SLRJMRY REF LOG: BA KER N WC GR 11 /22/17 A NGLE AT TOP PERF: 52" @ 1453V Note: Refer to Production DB for historical pert data SQE SPF INTERVAL Opn/Sgz SHOT SOZ 2-7/8" 6 14530-14562 O 04/01/18 2-7/8" 6 15015 -15025 O 02/19/18 2-7/8" 6 15270 -15323 C 02/18/18 2-718" 4.5 15323 - 15334 C 02/18/18 2-718" 6 15334 - 15366 C 02/17/18 2-718" 6 15535 -15567 C 12/26/17 2-7/8" 6 15554 -15587 C 12/25/17 PBTD 15599' 4-1/2" LNR, 13.5#, 13CR-85 HYD 521, 15691- .0150 bpf, D = 3.920" s 2 0 o a SAFETY NOTES: WELL ANGLE > 700 @ 13492'. MAX DLS: 16.1 " @ 14900'. CHROME TBG & LNR 2029' ML LOUT WINDOW (5 200A) 2734' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3512 3362 45 KGB -2 DMY BK 0 03/25/18 5 4127 3726 57 KGB -2 DOME BK 16 04/14/18 4 6886 4510 75 KGB -2 DW BK 0 03/25/18 3 9649 5244 74 KGB -2 DOME BK 16 04/14118 2 12366 5970 75 KGB -2 DW BK -2 0 11/26/17 1 13767 63871 63 1 KGB -2 SO BK -2 24 04/14/18 13821' 1— 4-112" HES X NP, D= 3.813- 13849' -j 7"X4-1 /2" FES TNT PKK D = 3.856" 13883' 4-1/2" HES X NP, D = 3.813" 13965' 1—(4-112" HES XN NP, ID = 3.725" 13966' 17*X5"VWDLTP&HGRw/TEBACKSLV, 1) = 4.310" 13973' 4 1/2" WLE-G, D = 3.958" 13987' I -i 5" X 4-112" XO, D = 3.910" 16091' 1-14-1/2" WFD C13P (03129118) J 15391' f - i PL)P JT w /RA TAG 15484' 4-1/2" WFTCBP{02117/18) DATE REV BY COA&E NTS DATE REV BY OOMM9NTS 01123/98 ORIGINAL COMPLETION 03/28/18 GJBIJ&U GLV C/O (03125/18) 11127117 P-272 SIDETRACK (S -200A) 04/11118 JNL/JMD EDITS TO COORDNATES 12114/17 BG/JMD FINAL ODEAPPR'OVAL 04/11/18 JCJJMD SETCBP& ADPERFS 12/28/17 JMG/JNQ PERFS (12/25-26/17) 04/17/18 JMG/JMD GLV GO (04/13/18) 01/09/18 JNJJMD ADDED R1+, OKB, & BF E LEV 102/27/181 JWJMD ISETCBP&ADPERFS AURORA LW WELL S -200A PERMTT No: 217-125 AR No- 50-029-22846-01 SEC 35, T12N, T12E, 4301' FSL & 4500' FEL BP Exploration (Alaska) STATE OF ALASKA RECEIVED �11LASKA OIL AND GAS CONSERVATION COMMION REPORT OF SUNDRY WELL OPEROTInNS _ n 1. Operations Performed MAR H 2018 Abandon ❑ Plug Perforations Q Fracture Stimulate ❑ Pul Tubing ❑ Operatiost�y)y(yt�q [0]Suspend ❑ Perforate Q Other Stimulate ❑ / Alter Casing 11ChangeAp ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development Q Exploratory ❑ 5. Permit to Drill Number: 217-125 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-22845-01-00 7. Property Designation (Lease Number): ADL 028257, 028258 8, 028256 8. Well Name and Number: PBU S -200A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: SCMT PRUDHOE BAY, AURORA OIL 11. Present Well Condition Summary: Total Depth: measured 15739 feet Plugs measured 15484 feet true vertical 6825 feet Junk measured None feet Effective Depth: measured 15484 feet Packer measured 13849 feet true vertical 6857 feet Packer true vertical 6425 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 76 20" 48-124 48-124 1490 470 Surface 2686 9-5/8" 48-2734 48-2712 6870 4760 Intermediate 14102 7 46-14148 46-6582 7240 5410 Production Liner 1725 4-1/2" 13966 - 15691 6483-6832 9020 8540 Perforation Depth: Measured depth: 15015 - 15587 feet True vertical depth: 6915-6846 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr85 44-13973 44-6486 Packers and SSSV (type, measured and 4-1/2" HES TNT Penn Packer 13849 6425 true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 3 125 1532 946 236 Subsequent to operation: 21 2753 3587 1158 255 14. Attachments: (required Per 20 nnc 25.070.25.071, &25.283) 15. Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Youngmun, Alex Contact Name: Youngmun, Alex Authorized Title: Kuparuk & Schrader Bluff PE Contact Email: younakCcDBP.com Authorized Signature: At—v- �—� Date: 3r I t Contact Phone: +1 907 564 4864 Form 10-404 Revised 04/2017 r�8DMS, L MAR 2 ?ui8��riginal Only • 0 Daily Report of Well Operations S -200A ArrTnirrvnATG RI IMMARY CTU #9 1.75" Coil Job Objective: SCMT, Set CIBP, AddPerf MIRU. Make up Drift BHAwith 3.70" DJN drift nozzle. 2/14/2018 ...Continued on WSR 2-15-18... TWO = SSV/1500/0. Temp = SI. Assist CTU, Rigged up CNG hose, manifold and check 2/14/2018 valve from (24-583) to SV of S-121. CTU #9 - 1.75" Coil. **"Cont. from WSR 2-15-17*** Job Objective: SCMT, Set CIBP, AddPerf Load well with 230 bbls 1 % KCI w/ SafeLube though with limited injectivity and only able to maintain 2 bpm. RIH with 3.70" Drift nozzle and tag TD at 15492' CTMD (15574' MD). Unable to jet any deeper and PUH and paint orange/yellow logging TD flag at 15450' CTMD. POOH. Notice gas migration from poor sweep while POOH. Make up SCMT logging BHA and tag suspected hydrates at 1470' CTMD. POOH and only minimal damage to tool. Make up 2.25" DJN BHA for jetting hydrates and RIH. Tag @ 1470' again and begin jetting w/ 60/40 methanol, work obstruction down to 3600' then cleared up. Continued RIH to bottom and began circulating in Slick 1 % KCL w/ SafeLube to sweep any remaining gas. 2/15/2018 ...Job in Progress... CTU #9 - 1.75" Coil. ***Cont. from WSR 2-15-17*** Job Objective: SCMT, Set CIBP, AddPerf Finished circulating a bottoms up', 190 bbls of Slick 1% KCL w/ Safelube, displaced reel to 60/40 methanol and POOH pumping 35 bbls of 60/40 Methanol w/ Safelube down backside for freeze protect. Make up SCMT logging BHA and RIH. Pump 1 % KCI down backside to keep well fluid packed while making 2 passes from TD flag at 15550' CTMD up to 13710. Paint red/white tie in flag at 15375'. POOH. Recovered good data from SCMT. Stack down PCE for BOP test 2/16/2018 ...Job in Progress... CTU #9 - 1.75" Coil. ***Cont. from WSR 2-16-18*** Job Objective: SCMT, Set CIBP, AddPerf Complete seven day BOP test, trimmed 99.3' of pipe, changed pack offs, and performed chain inspection. Make up WFT 4.5" CIBP BHA and RIH. Set CIBP @ 15485' ME (15484' CIBP top), correlated to Baker MWD GR 11-22-17. Test plug to 1500 psi. POOH. Make up 32'x 2 7/8" MaxForce pert gun, 6 spf and RIH. Correct depth off of CIBP & perforate interval #1; 15334'-15366'. POOH 2/17/2018 ...Job in Progress... CTU #9 - 1.75" Coil. ***Cont. from WSR 2-17-18*** Job Objective: SCMT, Set CIBP, AddPerf Finish POOH w/ gun run #1 Make up 32'x 2 7/8" MaxForce pert gun, 6 spf and RIH. Correct depth off of CIBP & perforate interval #2; 15302-15334'. POOH. Discover that multiple shots had low order detonation so 15323-15334 is only 4.5 spf. Change pack offs and trim pipe. Make up Perf Gun BHA #3 with 32'x 2 7/8" MaxForce pert gun, 6 spf and RIH. Perforate interval #3; 15270'-15302'. POOH 2/18/2018 ...Job in Progress... 0 Daily Report of Well Operations S -200A CTU #9 - 1.75" Coil. *"`Cont. from WSR 2-18-18*** Job Objective: SCMT, Set CIBP, AddPerf Finish POOH w/ gun run #3 RIH w/ Perf Gun BHA #4; 11' x 2 7/8" MaxForce pert gun, 6 spf and RIH. Tie into CIBP and Perforate 15015-15025'. POP well with 2.5 MMscf/d while POOH. RDMO CTU and leave well flowing on departure. 2/19/2018 ***Job Complete*** TJWJ+ (NV 4-1/l(i-Ut3LMbIKUKY "UJ -- - ------------- Vv�LifAD = 11" 5M ACTUATOR=----.- SPF OKB = 66.59 REF E.EV= 82.32' BF. ELEV _ . 36.48' 15015 - 15025 2734' Max Angle = 104° @ 1512(Y tum MD = 9049 OatumlVd= �� 500(Y SS 9-518" WHIPSTOCK (I Gt28/17) 2734' 9-5/8" C.SG, 47#, L-80 BTC, ID = 8.681" _2734 - Minimum ID = 3.725" a@ 13966' 4-1/2" HES XN NIPPLE TOP OF CEMENT (11/17/17) 7911' V ERIFIED w /IBC CEMENT LOG I TOP OF 4-112" LNR 13966' 4-112" TBG, 12.6#, 13CR-85 VAM TOP, 13973' .0152 bpf, C) = 1958' 7" C.SG, 26#, L-80 VAM TOP, 14148' 0383 bpf, D = 6-276" PERFORATION SUMNF1RY REF LOG_ BAKER MNVD GR 11/22/17 ANGLE AT TOP PERF: 104" @ 15015' Nate: Wfer to Production DB for historical perf data SIZE SPF MERVAL Opn/Sgz SHOT SQZ 2-7/8" 6 15015 - 15025 O 02/19/18 BK 2-718" 6 15270- 15323 O 02/18/18 57 2-7/8' 4-5 15323- 15334 O 02/18/18 4 2-718" 6 15334 - 15366 O 02/17/18 BK 2-7/8" 6 15535-15567 C 12/26/17 74 2-718" 6 15554-15587 C 12/25/17 2 PBTD 16699' 4-1/2' LNR, 13.5#, 13C R-85 HYD 521, 15691' .0150 bpf, IE) = 3.920" S -200A SNEW NOTES: WELL ANGLE a 70° @ 13492'. MAX DLS:16.1 " @ 14900'. CHROME TBG & LNR 2029' MILLOUT VMNDOW (S -200A) 2734' - 2748' GAS LIFT MANDRELS ST MD TVD DEV TYPE I VLV LATCH PORT DATE 6 3512 3362 45 KGB -2 DOME BK 16 12/21/17 5 4127 3726 57 KGB -2 DMY BK 0 12/21/17 4 6886 4510 75 KGB -2 SO BK 20 12/21/17 3 9649 5244 74 KGB -2 DMY BK -2 0 11/26/17 2 12366 5970 75 KGB -2 DMY BK -2 0 11/26/17 1 13767 6387 63 KGB -2 DMY I BK -2 0 11/26/17 13821' 4 1 /2" HESX NP, [} = 3.813' 13849' 17"X 4-1/2" FES TNT PKR, K)=3.856' 13883'4-1/2" FES X NP, ID= 3.813" 13966' j—�4-112" HES XN NP, ID = 3-725" 13966' 17'X5*WFDLTP&HGRw/TEBACKSLV, ID = 4.310" 13973' 4-1/2" WLEG, D= 3.958- 13987' I—I 5" X 4-1 /2" XO, ) = 3.910" 1 16391' I P' JT w /RA TAG 16484` 4-tr2"V17FFCBP(02/17118) DATE REV BY COMMENTS DATE I REO/ BY COMMENTS 01123198 ORIGINAL COMPLETION 01/09/18 JNL/JMD ADDED REF, OKB, & BF ELEV 11127/17 P-272 SIDETRACK (S -200A) 02/27/18 JMJM? SETCIBP&ADPERFS 12/07/17 JM7 ORLG HO CORR13MIONS 12/14/17 BG/JMD FACIAL ODE APPROVAL 12/28/17 JMG/JMD GLV GO (12121117) 12/28/17 JM-/JMD PERFS (12/25-26/17) AURORA UNIT WELL: S -200A PERMT No: 217-125 API Na: 50-029-22846-01 SBC 35, T12N, T12E; 439 NSL & 4500' WEL BP Bcpioration (Alaska) nom\ THE STATE V 0 W 1, 44FOR MAE GOVERNOR BILL WALKER David Wages Well Integrity Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Aurora Oil Pool, PBU S -200A Permit to Drill Number: 217-125 Sundry Number: 317-491 Dear Mr. Wages: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.cogcc.alaska.gov Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Eug---� Hollis S. French L Chair J DATED this day of March, 2018. 15,' STATE OF ALASKA WSKA OIL AND GAS CONSERVATION COMMIS APPLICATION FOR SUNDRY APPROVAP 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0' 5. Permit to Drill Number: 217-125 ' 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-22846-07-00 ` 7. If perforating: G'D YC; -7A 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this po I? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU S -200A ` 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028257, 028258 & 028256 PRUDHOE BAY, AURORA OIL 1. PRESENT WELL CONDITION SUMMARY Depth MD (ft): T o?l Depth TVD(ft): Effective gepth MD: EffG iv��Depth D: "6 N826' MPSP (psi): Plugs (MD): Junk (MD): c�Total s� / G / X5780 None None Casing G' Length ^: `L •!rc Size, SMD TVD Burst Collapse Structural L. Conductor 76 20" 125 ' -49 - -125 1490 470 Surface -2686 9-5/8" -2734 6870 4760 Intermediate <74482" 7" :%N - ; ' 7240 5410 Production Liner -1360 4-1/2" -14379 - -155 X6243 - -$B21 8430 7500 Perforation Deoth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): I y�eft i5 " /56j�—/ 13Cr85 Gls �1, 4-1/2" 12.6# -45--14384 / Packers and SSSV Type: 4-1/2" Packer Packers and SSSV MD (ft) and TVD (ft): -14380 / -6645 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary H Wellbore Schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: November 15, 2017 15. Well Status after proposed work: Oil 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Wages, David be deviated from without prior written approval. Contact Email: David.Wages(Mbp.com Authorized Name: Wages, David Contact Phone: 907.564.5669 Authorized Title: Well Interntionj Engineer Authorized Signature: Date: 1(04ZL2 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �) 1-i q ( Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BYTHE lie) Approved by:Loo;�� COMMISSIONER COMMISSION Date:-) /(. Form 10-403 Revised 04/2017 U`T'6 3/6/te ORIGINAL Approved application is valid for 12 months from the date of approval. CIO / ir,18 L ,l—L :�' z-lid, C Submit Form and 3�J' Attachments in Duplicate j ,LS�2oI • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AFFIDAVIT OF NOTICE OF OPERATIONS Before me, the undersigned authority, on this day personally appeared QV 1J oem r- , who being duly sworn states: 1. My name is David Wages. I am 18 years of age or older and I have personal knowledge of the facts stated in this affidavit. 2. I am employed as an Engineer by BP Exploration (Alaska) Inc. (`BPXA") and I am familiar with the Application for Sundry Approvals to stimulate the S -200a Well (the "Well") by hydraulic fracturing as defined in 20 AAC 25.283(m). 3. Pursuant to 20 AAC 25.283(1), BPXA prepared a Notice of Operations regarding the Well, a true copy of which is attached to this Affidavit as Attachment 1 ("Notice of Operations"). 4. On October 11, 2017, the Notice of Operations was sent to all owners, landowners, surface owners and operators within a one-half mile radius of the current or proposed wellbore trajectory of the Well. The Notice of Operations included: a. A statement that upon request a complete copy of the Application for Sundry Approvals is available from BPXA; b. BPXA's contact information. Signed this 12th day of October, 2017. (Signature) STATE OF ALASKA THIRD JUDICIAL DISTRICT Subscribed and sworn to or affirmed before me at (.y''K f P . I`t� on the day of CJ ( v j4 , 20/'?. ignature of Officer 8 fLill#* {titt of Atatka W t L. Jordhalm Title of Officer rl Davies, Stephen F (DOA) 0 From: Wages, David <David.Wages@bp.com> Sent: Friday, February 23, 2018 7:03 PM To: Davies, Stephen F (DOA) Subject: S -200a updated info Attachments: S -200a AOGCC notification 2-23-2018.docx; S -200a Pre and Post Frac 2-23-18.docx Steve, Please see attached the updated sundry information as discussed. EIVED David Wages BP I AK I Completion Engineer FEB 2 6 2018 900 E. Benson Blvd 1744c I Anchorage, AK 99515 Direct: +1.907.564.5669 1 Mobile: +1.713.380.9836 1'1OGCC Wellwork Procedure Request To: Well Services Operations Team Lead Date: 2/12/18 F Wireline Operations Team Lead 2. VER2 Install Buffalo head 3. AFE: Hydraulic Fracture Treatment (2x) From: David Wages - Well Intervention Engineer Assist with frac, set plug, perforate, cleanout, set plug, perforate 4. S Todd Sidoti - Well Intervention Engineer IOR: C Mill out plugs to TD 6. Est. Cost: Post frac flowback Subject: S -200a - Pre and Post Frac Procedure Please perform the following steps 1. S Pull LGLVs, Circ in inhibited brine with freeze protect, Install Dummy valves 1. F Assist SL w/ loading IA 2. V Install Buffalo head 3. Frac Hydraulic Fracture Treatment (2x) 3. C Assist with frac, set plug, perforate, cleanout, set plug, perforate 4. S D&T, Install GI -Vs 5 C Mill out plugs to TD 6. T Post frac flowback Current Status: Minimum ID: Max Deviation: Top Perf Deviation Last TD Tag: Last Downhole Op SBHP/SBHT: Latest H2S: Program Contacts New RST 3.813" at 4-1/2" X -Nipples 104 deg at 15,150' MD 50 deg at 14,500' MD 12/25/2018 @ 15,525' with coil Perforate to test the rates and cuts of the toe of the well. New Well, 3250 est. est @ 10 ppm FEB 2 6 2013 Page 11 of 9 Contact Phone - Work Phone - Mobile / Home Interventions Engineer David Wages 907-564-5669 713-380-9836 Interventions Engineer Todd Sidoti 907-564-5113 907-632-4113 FEB 2 6 2013 Page 11 of 9 0 0 1. Critical Issues A. Tree Configuration a. To perforate and pump our frac job, a Buffalo head needs to be rigged up. Available from Stinger, this is a cap on the tree that has a connection on top for coil and 2-4 side outlets for hooking up frac pumping equipment. 2. Procedure A. Slickline- Pull LGLVs, Circ in inhibited brine with freeze protect, Install Dummy valves a. Freeze protect with diesel or crude to 2500' B. Fullbore- Assist with IA circ a. T+IA Vol: 476 bbls Tbg Vol: 220 bbls IA Vol: 256 bbls T+IA Freeze protect vol: 119 bbls C. D. Coil/Special Projects- Pump stimulation a. Install Buffalo head b. MIRU coil c. RIH and set bridge plug @ -15100' d. Perforate ToeFRAC1 fr. 15015'-15025' per pert reference attached i. 2-7/8" MaxForce ii. 175 MaxForce HMX Charge iii. 6 spf e. RU SLB Frac and pressure test FRACTURE STIMULATION Maximum Allowable Treating Pressure: Stagger Pump Kickouts between: Global Kickout Treating Line Test Pressure IA Hold Pressure 5000 psi 4750 psi and 4500 psi (95% to 90% of MATP) 4750 psi (95% of MATP) 6000 osi 2200 psi OA Monitor and maintain open to atmosphere Minimum Water Requirement 3000 bbls (pump schedule: 2600 bbls) f. Frac stage 1 per pump schedule g. MU Frac plug (for easy drill of multiple plugs) Page 12 of 9 i. Baker or Halliburton both have composite plugs developed specifically for stackable plug and pert fracing. They have a half moon or muleshoe on the bottom to prevent spinning. h. Set plug @ -14700' i. Perforate HeelFrac2 fr. 14530'-14562' per pert reference attached 1. 2-7/8" MaxForce 2. 175 MaxForce HMX Charge 3. 6 spf j. POH k. Frac Stage 2 I. If a screenout occurs, have coil CO to the tubing tail so live valves can be put in place E. Slickline- D&T. Install GLVs a. Drift to deviation. b. Install Deep GL design if possible F. Mill out plugs to TD a. Coil to mill out bridge plugs to TD while testers flow back. G. Testers- See Appendix for Post Frac Flowback Page 13 of 9 9 9 Appendix A - CT FCO Procedure if screenout occurs Notes: This is a generic FCO procedure for a post frac FCO. Specific info such as amount of proppant left in tubing and estimated sand top will not be known until after the job is pumped. The objective of this procedure is to get the well cleaned to facilitate post frac well test or to continue frac operations. Recommend reviewing PE Manual section for Coiled Tubing Fill Cleanouts for specifics on reversing rates, speeds and CT loading. Planned Procedure 1. MIRU CT 2. MU BHA. 3. RIH down to estimated sand top and begin cleaning out with slick 1 % KCL. 4. Continue down to tubing tail. We only want to ensure the GLM are clear of sand to facilitate the mill out of plugs when testers are flowing the well. a. Jet across GLMs to ensure they are clear of sand 5. FP to 2500'. 6. Pump a gel pill at surface out to the tanks to ensure CT is clean if necessary. 7. RDMO. Page 14 of 9 0 Appendix C - Test Separator Additional Flowback Procedure 0 The goal is to keep what sand we placed during the frac in place. Changes to BHP and flowrate need to be gradual for the remainder of this well's life. Some sand/proppant flowing back is ok, however, no more than a few hundred pounds should be flown back. It is difficult to differentiate between what settled out in the liner vs what is coming from a frac, but conventionally, no more than 2000# of proppant should return to surface, the lower the better. 1. MIRU ASRC. RU equipment to in a manner that allows CT to RU if an additional FCO is necessary. 2. POP the well to ASRC at minimum choke. Flow the initial returns to the flowline as long as the shake -outs meet the returned fluid/solids management guidelines. 3. Limit flow to 500 bpd 4. If solids are < 1 %, increase the production rate to 1000 BLPD. 5. Flow bottoms up and sample for solids production. If solids are still below 1 %, allow well to flow to 1500 BLPD. Flow bottoms up and sample for solids production. If solids are still below 1 % continue to increase the flow rate in 500 BPD increments. The objective is to achieve maximum drawdown. Watch returns and do not continue to open choke if solids > 1 %; allow well clean up before choke is opened further. 6. Once at FOC, stabilize the well for 4 hrs. Obtain a 3 hr purge, 8 hr welltest. Page 15 of 9 2 Injection test W128 20 20.0 100 110 GROSS 4,200 4,620 _.._..._._....._.....__._..._.._-..................................................................................__.._.._.............-.._.._............_.._....____-______ 3 Shut down to isolate CPS 0.0 ATTACHMENT 1: PU(.1P SCHEDULE ._ ............................................., 0 Pressure Test 8000 hlaxtdHTF•ressare 7000 Slurry Rate 30 .,._....._......................................................... 200 310 .......... ....... _ .......................... 8,400 _.... 13,020 _..__._....._._._..._.....__...._..._............................................................................._............_.._......................................................._...... 5 Flush WF128 30 ................ ...... .... .... ....... ..........................._.. ..._.. 30 0 _........._.._.............................................................................._...._..................__..._........._.........__ _...... __.._..__.._.._....__..........._._....................................................... 223 533 (p AFE 22,399 HARD SHUTOOVN, MONITOR PRESSURE TILL CLOSURE. Pump Trips 6500 Ann Pressure 3000 Fluid Type YF128FIezD - STEP STAGE AVERAGE COMMENTS FLUID PUMP CF DIRTY VOLUME DIRTY VOLUME PROPPANT PAD a 4 PPA TYPE RATE RATE STAGE CUM STAGE CUM STAGE CUM SIZE O 7 BPM BPM) IBBLI 1081.11GAL GAL BS LBS 29 ............ t......Prime up, pressure test FreeieProt 5 5.0 10 10 =20 420 1 2 Injection test W128 20 20.0 100 110 GROSS 4,200 4,620 _.._..._._....._.....__._..._.._-..................................................................................__.._.._.............-.._.._............_.._....____-______ 3 Shut down to isolate CPS 0.0 _ 7111.__--_ _ 110 ._ ............................................., 0 4,620 .... ........................................._..... .................... 4 Calibration Test YF128FlexD 30 ........... _... _..... 30 0 .,._....._......................................................... 200 310 .......... ....... _ .......................... 8,400 _.... 13,020 _..__._....._._._..._.....__...._..._............................................................................._............_.._......................................................._...... 5 Flush WF128 30 ................ ...... .... .... ....... ..........................._.. ..._.. 30 0 _........._.._.............................................................................._...._..................__..._........._.........__ _...... __.._..__.._.._....__..........._._....................................................... 223 533 f 9,379 22,399 HARD SHUTOOVN, MONITOR PRESSURE TILL CLOSURE. ...................... _ 2,011 lBPMj Iffirpm)BBL .---_•.--•--1 ......__............... 48 BBL BBL T Proppant Density C Proppantused 3 CLEAN VOLUME GROSS CUM (n BOL) (BBLI n .......1.... . .....................��.......... (D 100 110 CL 0 ...................................... CD 200 310 STAGE CUM SIZE GROSS FLUID PUMP CF DIRTY VOLUME DIRTY VOLUME STEP STAGE AVERAGE COMMENTS TYPE RATE RATE STAGE CUM TOT JOB STAGE CUM f i PPA ..... .... ........ . ...................... _ 2,011 lBPMj Iffirpm)BBL .---_•.--•--1 ......__............... 48 BBL BBL GAL GAL 6 1 916 PAD YF12$FlexD 30 0 0 125 658 5,250 27,649 7 1 0.5 FLAT YF128FlexD 30 29 50 708 2,100 9,749 8 1 .............................................._.._............... 31,252 ....................._._..... PAD __..............................._......_.................._.._............................................... YF128fkx0 10 30 0 125 _................._._.................................................................._.-. 833 5,250 34,999 9 t 1 FLAT YF128FIexO 30 22.7 50 883 2,100 .....2...9...,.7 .. 37,099 to 1 . 1 ...... RAMP ............... Yf128FlexD _.................... 30 . ......... ................. 28.7 ... _....... ......... ...__. 38 . ..._.................. ...._. 921 .............. ... ............. 1,596 ...............__ 38,695 11 1 2 RAMP YF128Fkx0 .............. 30 27 E 38 959 1,596 40,291 ...-.._ ... ........................................ t2 t -.._..._.._...._.._.._......_....... 3 .......... .......................................... RAMP YF128FIexO ........................ 30 ........... _._........... 26 5 ........... _......___._ 38 ........................... ______... ....... 997 ............... .._....... 1,596 _.......................... _.. 41,887 _ ...- Yt - ...............__...... 1 _............................................................................................................................._.... 4 RAMP YF128fkxD 30 .......... 25 .............. ... _..... 38 ............. .............. _.._._.._....._____ 1,035 ................. ._... _._._......._.... 1,5% ....... ...... 43,483 __.._......_........_.._ 14 ...... 1 ---....------------_...._•__-- _....................................................................................................................... 5 RAMP YF128FIexO _........................ 30 246 _ 38 _._......_._........- - 1,073 1,596 45,079 -....._.__... B 1 6 ........................................................................................_._.................. RAMP YF128FIexD 30 __....`.........................................._.._.. 23 7 38 1 111 � ... ____..................... 1,596 ............ _........ 46.675 _._....._................__......................._...__.._............................................................................................................................ 16 1 7 RAMP YF128FIexO 30 171 _ _ ... 22.9 _.........................._.... 38 ...._........._..................................._.._...........................I.............. 1,149 1,596 48,271 _ .._......----_ 1T 1 8 RAMP YF128FkxD 30 22 2 38 1,187 _..__.._........._....__............................. 1,596 49,867 18 ......................................................_.._......_......................................................._................................................__.......................__.._..___........ t $ FLAT YF128Fkx0 30 222 50 1237 2,100 51,967 M_.._.._....__ 19 ..........................................................._..._._.. 1 9 FLAT YF128FIexO 30 215 100 .................................._.._....__-.........._..........................._......___.............. 1,337 4,200 56,167 20 ....................... 1 ....................... 10 ....... ..... _................................ FLAT ...................................................... ............................... -------------- YF128FIex0 ............... ... 30 .--------••---- 20.8 ----- ............................................................._............1 100 1,437 ... .7...__...........11. 4,200 - .. _.. 60,367 21 1 DISPLACE ... YF128FIexD __.... _............. 30 ................. _....... _'0.0 ............ ...... ............... 'W ......... .................... .._..__......_..._......_......................._....._................. 1,477 1,680 62,047 _.._.........._......_...._ 22 ............................. 1 ..........................................._. DISPLACE Fl 28 30 -,__.._........._.........................................................._............._ 30 0 180 1,658 1117._ 7117._ 7,573 1117._ 69,621 Shut down, plug an, 30.0 125 1,783 5,250 74,871 23 2 PAO YF123FIexD 30 24 _........_...._._..... 2 0.5 FLAT YF128FIexD ................... ...... 30 ..... ........... ti..._ 29 ° ._. __..._.............._........_..........-..-......__., 2,100 76,971 - .... .....__ . ........................1111..... --_..........PAD................ YF123FIexD............30.................zi ......... cc 1 1, 5250 .._.�_.._.. 26 _........_ 2 ...................._...... 1 FLAT ................. YF128FIexO 11 ............ 11_._..71..1.1.._...... 30 22 ' _ ._.. .. 2,008 _..._........._.._........_..__......_.. 100 27 7111.........-_-. 2 _ ___...............................................................2....:........... 1 RAMP YF128FIexD 30 28 7 _........... _.....�....._.. 2 a.............. 91 ..............._.._....____............................__-_................._............................_.._....__..._...................................................................._.._..._... 28 2 2 RAMP YF128fkx0 30 »..W__.. _ 1111 ........___.... 87,513... 29 2 . 3 RAMP .................................. YF128Fkx0 30 .......-�%........................ 26 5 ..71...............71 2,122 89,109 30 2 4 RAMP YF128Fkx0 30 25 5 ............ _. _.............. .......... _ . 2160 r 7 3i 2 ... ................ 5 ......................................... 30 _w..,.................. 24 6 _.._.............................. 2,198..._.......... 32 ___...................._....__._..__....___....... 2 6 _RAMP........_.............-YF128fkxD RAMP .............................................._......._._... YF128FIexD 30 2_3 7 ___..._. 38 2,236 1,596 _----- 93,897 33 ...- -.. 2 ............................................................................................I................_....... 7 RAMP YF128FIex0 30......... 22.9 _............._ 38 _._.__.. _ _ 2,274 1,596 _ 34 2 ......................................... 8 RAMP YF128FkxD 30 ..._..._..... 22.2 __................_._.................................._......-__-................................_ 38 2,312 1,596 97,089 35 2 8 FLAT YF128fkx0 30 222 5o 2,362 2,100 99,189 ...............................-- 36 i! ..................._._....._..._.. __..__............................................................................._.........._......_.. FLAT YF728fkXD 30 21.5 ___..__..._....._.,.................................................__...._......_..........................1......... 100 2,462 4,200 ... __111 103,389 _37 2 _ ...t0....... " • FLAT YF128FkxD 30 208 100 2,562 4,200 107,589 38 2 _....__ ............ ..................... ................... FLUSH .....-............. ................................... YF128FkxD .... 30 ........ .... ._._... .. N 0 _............................................................................... 40 202 ...................... ....................... 1,680 _..... _...., 109,269 39 2 FLUSH WF128 30 20.0 2,737 114:945 40 2 __........_..................................................................._...................._................................... FLUSH FreezeProt 12 ----.... , 2 0 .135 40 2,777 _5.676 1,674 116,619 TOTALS....................................................................................................__.._....._..........-^___........_........___...... ................._ .........2�_.._...................I_-... .... ._._........_._ ......._........................... ................. . SO and obtain ISIP ti 15 min SIP. T Proppant Density C Proppantused 3 CLEAN VOLUME GROSS CUM (n BOL) (BBLI n .......1.... . .....................��.......... (D 100 110 CL 0 ...................................... CD 200 310 STAGE CUM SIZE GROSS CUM (LBS) (LBS) (BBLI JBBL �.........._.........._.Q............_.._.. ...... 1,027 1,027 16130 Sand .._125 ..................._658.. 49 707 0 - 1,027 ------1711 .............. .... ........ 125832 ..... .... ........ . ...................... _ 2,011 .... .... ........ .... ...... 3,038 __......................_.._.._... 16 -^.. C -Lite .---_•.--•--1 ......__............... 48 880 .__.........._.I...._...77.........7....7_ 1,528 4,567 ........... .................. . 16 C -Lite ----...._........._.--7711._. 36 916 ..._......___ ...........................-.I......._.......-.- 2,933 7,499 __..._••..___..._ 16 C -Lite ......__._...... __ 36 ............- 951 4,227 11,726 16 z0 C -Lite 34 986 ............................................................................... 5,424 17,150 [.._......... 16120 C -Lite ......... 33 1,019 6,534 23,685 16120 C -Lite 32 1,050 .__.__................. 7,567 .............................................._.._............... 31,252 16120 C-Lite31 ............_...........__._......._....... 1,081 . ...._.............................................___......_..._._.__.._. 8,530 39,782 16120 C -Lite __.__.._............. 30 1,110 9,430 49,212 16/20 C -Lite 29 1,139 12,408 61,620 16120CB137 _......_..__...._............ 1111.. ..__... .... ......... 1,176 .._.._._... 27,035 88,655 16120 CBL 73 1,248 29,117 ................._......._.............._.._................................._...................._...._...._.._................_ 117,772 16M COL 70 1,319 0 117,772 40 1,359 ....................................................._................_......................................................_...... 0 117,772 180 1,539 0 117,772125 1,664 ............... 1,027 _............_ 118,799 ..._.................... 0 ...._........_ 49 _ __......_....._._... 1,713 0 118,799 125 1,838 ... 120,810 e 48 1,886 1 528 ._____._.....__..11_ 122 338 1111 a _______._...__.___.._........... 36 1,922 _.......x .......................... 125,271 ............ jmi. 0 a .............__...._...._�.......... 36 1,957_.... a ........7.........7......7..7...._ 34 1,991 ........._.._ 134,922 __..__. 0 a .._...........5,424 33 2,024 141456 _ 0 e ......................................._....... 32 2 056 7,567 149,023 IW20 C -Lite 31 2,087 __._............__.._...._ 8,530 157,554 ............. .......... ...... ...._....... 16120 C -Lite ......_.. ..._........__.-.._...... 30 2,116 9,430 166,984 16/20 C -Lite 29 ... .......... ...... 2,145 ... __..........................._...._..............................__.._................ 12,408 179,39216il0 CBL ......................._...._..- 37 - 2,182 27,035 206,426 17...7.1...._.. 16120 CBL 7 771._ ............................... 73 2,254 29117 _......................................... 235,544 16!20 CBL 7111. _._ ....__.._.._............. 1111 70 ............ 2,325 0 235,544 .. 40 ..._._............._.................. 2,365 0 ..................... 235,544 135 _........._.__._... 2,500 0 235,544 40 2.540 si 0 TFam= CNV4-1116r ML MSTRCW IDLE WELLHEAD- 11l5mrw ACIMTOR - 0KB -- 66-58, REF EILFV - 82.32' BF ELFV - 3648' K(Fa 21N. Mm Arigic15127 ii6W-M5".- DettntTVD - 5000' SS "Wvu- i; i —i i i'4 F [Miiini—munm ID = 3.725- @ 13966 , 14-112- HES XN NIPPLE -T-T-T --- 1 topoHckmml (i lei im —F I" i VERFED wffl3C; CEMENT LOG I " 7811. OF 4-Irr LNR 1-1 13968' .0152 bof. E) = 3.958r -0353 bpf. D=6.276' PE FORAIION SLtt"RY D-6-276- PERFORATIONSLA"RY FEF LCIG- BAKFR MIWGR 1102M7 ANGLE AT TOP FEW: 96"a IWW Note: Refer lo RAucbon OB for hobw-* pelf data sff SFE INTMAL Orv'sw SHOT Sw 2 TV 6 16654 16567 0 12?25117 57 4-lf2- LNK 13.59, 13CR-85 HY U $21. 0150 bpf. ID = 3.920' S -200A 9 SAFETY NOTES: WELL ANGLE S. 70'@ 13492% MAX DLZ: 16.11 @ 149001. CHROME TBG a ILNR 2M' 4 -Ur HES X NIP. K) !23:813'I j Iw t Ow Wm)t')W (S -MOIL) 7734- ?748' - , - , , "'" , , , nAn k rT L&%tinnri n ST UD TVD DEV TYPE VILV I LATCH FORT DATE J12 -i-28!17 PM&A—qmws (12125-26w) I 5 4127 3726 57 KG&2 OMY BK 0 12121117 4 6886 4510 75 KGB -2 SO SK 20 1221117 3 9649 5244 74 KGU-2 IDW BK -2 0 11/26117 2 12366 5970 75 KGE)-2 UMY BK -2 0 I1!26!17 1 13767 6387 63 K(Z-2 DMH' BK -2 0 IUM171 1362v -A4-ipFmmxNP.ID-35l3- 1384W -JT-x4-lr2-HES TNT mKID- 3Aw 13893' 13966' J-j4-lM-HES XNMF. D=3.72V' X 5' VFD LTP & HIGR w rrIEBACK SLV, :: 4 1398r H3-x4-In-x0.lD=3-910^ PUP JT w IRA TAG Page 17 of 9 POLARIS UNFr Wn.t 0,4MA PUMI W 211-125 APO No 50.029 22W>-01 SEr, 35, T121 -k T12F, 430- W>L & 45W M DA11E FEV BY CCIMMsm ()Alt M BY COMNINTS 0111CINAL 00MI'LUION IM,00110 &AJAMI, An0MrTr,0KrI.&8FELEV IV2?n7 P-272 SIDETRACKS -2011A) 12007117 JW DRLG NO ODF443MIDW 12114/17 FKVJMI) FINAI 00FAFIRMAI, 12128117 ACYJMDGLV CJ0fl2/2l/l?) OPS"orationiAlaskal J12 -i-28!17 PM&A—qmws (12125-26w) I Page 17 of 9 -v CD OD 0 (0 --I C W CD m 0 CD fll 0 0 (Ml*aWO4.)(ISd)ajnsSaJdletluojojli(]jefnuuV j0peA AtaleS leinul aInjosqV OOOZL OOOOL 0008 0009 0009 000z 0 OOOz- 0004- 0009, 0009, 00OU- 000rt- )00'9 909,9 z6z v IME US E 6zz E SL8 z tzs z 19&e ELS "t 8st t tot t OGL a OOOSIE- 00081 -------- ............................................... . . ............................................... 000c. ...... ..................------1-----------I-.....I.----- ------- 0009L ------ ....................................... ------- ....................... ................. I .............................. ......................................................... ...... w.. -000,t .......... I .................... .................. . .............. ... .............. ......................... ..................... ... --------- — - .... .. ................ ........... . 0000st- ......... . ............................................................ ...... ................... ............. . OOOZL ............................••---._...;...--•-•-----•---...-.........--...- •--•----....-............__.... ---------- OOGSL- ......... .... ........ ......... ---------- ------------------- ................. ----- ------------- - 00001 m - I ........ .......... .......... ------------------- ................... ..................... --------- ------- ----------- ....... . ...... .......... I ..... --------- --------- . ....... ......... ......... I ---------- .......... ..... ..................... ........ --------- . ...... OCGSL ........ ................ --------- ......... ......... --------- ...... ............... ------ ....... . ... ..... ...... ......... I ......... ... ......... --------- ----- .... ......... ---+---•----- 0008 0009 • --------------------------- ---------------- ..... ........... ------------- ..... ----------- --------- Wl A 00005& 07 . VI -I --- --------- 0004 . ........ --------- .........I .-------------------'---------'---•----- -- I --------- I --------- mdOS OIDOW ; ......... ......... --------- -------- - ------- aeij L ------- 0 oz Os too suGQ0uO3 leq,.] suowp. 00 Impul OOOOK (OVIUsn 00 O;BEL PIOoEd) t018'Ped- OUI.QnlUMnPOJd.M V ado"3 uQeJbdOJOVed I le. -I (JOD 03,OA jev F JOUII UOrPAPOJd 21L V Usn 00 EqtSt 00009E 00000c OOOOGZ 00000z 0000st OOOOOL 00009 0 00001, OOOOOL- 000OW 00000z- OOOOGZ- NOW - I I I I L I MOM -101 ucrimpoM _L Usn 00 LpZVL 101 UsnOOL"VL ajewlo�ue sie sl�.,l:"DN LNAXed Usn000ggEt ........A ...... --i---------` ---------- -------- .......... I......._{..._...__1._......_000 -L asd C1100 ----- -------- - 0008- ........ ........ ......... ........ .'.-------i... .. ........ ......... .................. ....... ........ 0009, ........ .............. .. ........ ... .......... .................................. ..................... ..... o0op- . ............................................ 000z..................... 0 . ........... ..... .. .................................. A. ..... -------- ----- ........ I ......... ....................................... -------- -------- - 000z ........ ........ ......... -------- =t ....... i ......... i ........ {.._......+..... .......... ......... ........ . 0009 .... ..................... ........ ................ ................ — -------- --- ----- ........ . 0009 6UISeO MPAS.91S 6 U- 00 VE? ............ ..... OOE-t UCRSWI: ----- ** ............... 1' o9z & ........................ r.. oot t . 0008 !Sine OS n�A . : t0000t SUOIIIPUOZ) leillul (Ory are stadap Irv) Usn 00 0 9M+ 08--1 spe)o -Idd 009 ZL joisM - ui 009't OO- L —paS - 6ui0nj umnPoidza v - --I C W CD m 0 CD fll 0 0 0 Cerberus: 40 Perf Tie in: Well S -200A Date 26 -Jan -18 Reference Log BHI MPR -GR Log Dated 22 -Nov -2017 Surface Weight during Tripping 14563.0 -1.0 0 HeeIFRAC2 14530 14562 32 6735.4 6754.1 ToeFRAC1 )DD D -1 0 D 10033 20&0 3011M 4DdOO 5)C 15270 15366 -------------- --------------4----------- - t -------------- t -------------- i -------------- t ------------ - ------------- -------- --- ------------ --+----------------------------i------------------------- ---- ---------- ---6G)G ----- ----------------------------- i -------------- t ------------ -- C i C i ------------- A, 4 ------------ — —M )G-'---: --- ----------t-------------- ------- - ----- - --------- o ---------------- C L L L ------------- --------------t ----------- —Imeo ---- ------- ----- ------------ - ---------------- ----------- C ------------- -------------- – ----------- — +212 )OD --- -------- ---- -------------- - --------------- – – ---------- -- --------------- v --------------- t ------ - td y-------------- I --------------- L ------------ -- ------------- -------------- - -------------- ------------ -3D000 Surface Weight (Ibf) 5MM Perf Tie in: Well S -200A Date 26 -Jan -18 Reference Log BHI MPR -GR Log Dated 22 -Nov -2017 Tie In Log HAL Coil Flag Dated 24 -Dec -2017 Heel FR.AC2 14531.0 14563.0 -1.0 Toe FRACI HeeIFRAC2 14530 14562 32 6735.4 6754.1 ToeFRAC1 15015 15025 10 6832.5 6830.1 PERF Only 15270 15366 96 6776.6 6775.7 Tie In Log HAL Coil Flag Dated 24 -Dec -2017 Heel FR.AC2 14531.0 14563.0 -1.0 Toe FRACI 15015.0 15025.0 0.0 PERF Only 15268.0 15364.0 2.0 Page 19 of 9 Legend -- - at Depth 15693 ft Surface Weight RIH 4771 Ibf Surface Weight POOH 254751bf Skq at Yield (80%) 494621bf %A] at Lockup Limit am Ibf 9N at Catastrophic Buckling Itf Yield Limit Lockup Limit 0 Date: January 15, 2018 Subject: S -200a Frac and Pack Stimulation From: David Wages Engineer, BP Alaska o: 907.564.5669 c: 713.380.9836 To: AOGC Commission Attached is BP's proposal and supporting documents to fracture stimulate the Kuparuk interval of well S -200a. S -200a targets a poorly swept polygon on the NW side of S -pad. Due to a long sail angle and excessive losses, the lower completion had to be cemented in place rather than the original plan of an openhole completion. As ✓ such, several fracs are planned in the lower completion. We are requesting a variance to sections 20 AAC 25.283, a, 3-4 which requires identification of fresh water aquifers and a plan for basewater sampling. Please direct questions or comments to David Wages FEB 2 8 2018 0 Summary of Work S -200a will receive a two stage frac via plug and pert Affidavit of Notification (20 AAC 25.283, a, 1) Partners notified 10/10/2017: ConocoPhillips ExxonMobil Chevron Department of Natural Resources i 0 0 Plat Identifying Wells (20 AAC 25.283, a, 2, A -B) ADI_028256 'r ID 028258 W c \��' Ai�L428257 ►j' FIA ;mit PRO r � Per the plat above, there are no water wells within % mile of the subject well. 0 • Producers within %. mile of well trajectory (20 AAC 25.283, a, 2, Q Wells Within X Mile of S -200A SW NAME WELL CLASS DESC WELL STATUS DESC NKUPST Development Abandoned 5-01 iDevelopment JAbancloned S -01A iDevelopment JAbandoned 5-016 Development Abandoned S -01C iDevelopment Oil Producer Shut -In 5-02 Development lAbancloned { S -02A Development Joil Producer Gas Lift S-02AL1 Development Oil Well S-02ALlPB1 Development IPlugged Back For Redrill S-02AP61 Service 113lugged Back For Redrill 5-03 IDevelopment 10il Producer Gas Lift 5-04 Service Miscible Injector Shut -In S-05 iDevelopment bandoned S -05A Service lWater Injector Injecting S-05APB1 Service Plugged Back For Redrill 5-06 iService lWater Injector Shut -In S-07 iDevelopment bandoned S -07A IDevelopment 10il Producer Shut -In S-08 � Development bandoned IS -OSA 'Development (Abandoned 5-106PB1 iDevelopment Plugged Back For Redrill 0 Wells Within % Mile of 5-200A • SW NAME IWELL CLASS DESC WELL STATUS DESC 5-107 Service Water Injector Shut -In FS 1085-109 Development Suspended Development Development Oil Producer Shut -In 5-109P61 Development Plugged Back For Redrill S -10A Development Suspended S 10AP61 Development Plugged Back For Redrill S-10APB2 Development Plugged Back For Redrill E S-11 Service Abandoned 5-110 ServiceSuspended lusscu ua�m 1 ul 11cul iii lugged Back For Redrill 5-113A Development bandoned lugged Back For Redrill 5-117 Development Oil Producer Shut -In 5-118 Development Oil Producer Shut -In S-119 IlDevelopment Oil Producer Gas Lift Wells Within % Mile of 5-200A SW NAME WELL CLASS DESC WELL STATUS DESC 5-122PB3 iDevelopment Plugged Back For Redrill 5-123 Service Water Injector Shut -In 5-124 ServiceMiscible Injector Shut -In 5-125 Development Oil Producer Gas Lift S-125PB1 Development Plugged Back For Redrill j 1S-126 lService Water Injector Shut -In 5-128 Service Water Injector Injecting 5-128PB1 Service Plugged Back For Redrill 5-128P62 Service Plugged Back For Redrill 5-129 Development Oil Producer Gas Lift 5-1291361 Development Plugged Back For Redrill 5-1291362 Development Plugged Back For Redrill IS -12A Development bandoned 5-126 Development Oil Producer Gas Lift 5-13 Development bandoned 5-134 Service Miscible Injector Shut -In S-135 Development Oil Producer Gas Lift S -135P61 Development Plugged Back For Redrill S -135P62 Development Plugged Back For Redrill IS -13A Development Oil Producer Shut -In S-13APB1 Development Plugged Back For Redrill S-14 Service bandoned 1S -14A Service Suspended 5-15 Service Water Injector Shut -In 5-151361 Service Plugged Back For Redrill 5-16 Development Oil Producer Shut -In S-16PB1 Development Plugged Back For Redrill 5-17 Development bandoned IS -17A Development bandoned S-17AL1 Development Abandoned IS-17ALlPB1 lDevelopment Plugged Back For Redrill S 17AP61 Development Plugged Back For Redrill IS -17B Development Abandoned IS -17C Development Oil Producer Shut -In S-17CPB1 Development Plugged Back For Redrill S-17CPB2 Development Plugged Back For Redrill 5-18 Development Abandoned S -18A Development bandoned IS -18B Development Oil Producer Shut -In 5-19 Development Oil Producer Shut -In 5-20 Service Abandoned Wells Within % Mile of 5-200A SW NAME WELL_CLASS_DESC WELL_STATUS_DESC IS -200 Development IS -200A Development Oil Producer Shut -In _. Oil Producer Shut -In S-200PB1 Development Plugged Back For Redrill 5-201 Development Oil Producer Shut -In 5-201PB1 Development Plugged Back For Redrill I S -20A Service Water Injector Injecting 5-21 Development Oil Producer Gas Lift 5-213 Development bandoned 5-213A Development Oil Producer Gas Lift 5-213AL1 Development Oil Producer Flowing 5-213AL1-01 Development Oil Producer Flowing 5-213AL2 Development Oil Well 5-213AL3 Development Oil Well 5-215 Service ater Injector Injecting 5-216 Service lWater Injector Shut -In 5-217 Service lWater Injector Shut -In S-218 Service Miscible Injector Shut -In 5-22 Development bandoned IS -22A Development bandoned S-226 Service lWater Injector Injecting 5-23 Development Oil Producer Shut -In j 5-24 Development bandoned IS -24A Service bandoned S-24APB1 Service Plugged Back For Redrill 5-246 Service lWater Injector Shut -In 5-25 Development bandoned IS -25A Service ater Injector Injecting S 25AP61 Service Plugged Back For Redrill 5-26Development Oil Producer Shut -In j 5-27 Development bandoned S-27ADevelopment bandoned S-27APB1 Development Plugged Back For Redrill 5-276 Development Oil Producer Shut -In 5-28 Development bandoned IS -28A (Development Abandoned :7 Wells Within % Mile of S -200A 0 SW NAME WELL CLASS DESC WELL STATUS DESC I5-31 Development iAbandoned FS 31A ServiceWater Injector Injecting 5 -32 IS -32A 5-33 S-34 Development Development "Oil Development Service Abandoned Producer Shut -In Oil Producer Gas Lift Water Injector Injecting 5-35 Development 'Oil Producer Shut -In 5-36 Development Oil Producer Shut -In 5-37 Development Abandoned IS -37A Development Oil Producer Gas Lift S-37APB1 Development Plugged Back For Redrill S-38 Development Oil Producer Shut -In 5-40 Development Abandoned 5-400 Service lAbancloned 5-400A Service Water Injector Shut-in S-401 Service Water Injector Shut-in 5-401PB1 Service Plugged Back For Redrill S-40ADevelopment Oil Producer Shut -In S-41 Development Abandoned IS -41A Service Water Injector Injecting S-41AL1 Development Oil Producer Gas Lift 5-41 L1 Development lAbancloned S -41P61 Service Plugged Back For Redrill 5-42 Development lAbancloned IS -42A Development Oil Producer Gas Lift S-42PB1 Service Plugged Back For Redrill 5-43 Development Oil Producer Shut -In S -43L1 Development Oil Producer Gas Lift S-44 Development Abandoned IS -44A Development Oil Producer Gas Lift 5-441_1 Development Abandoned S-44L1PB1 Development Plugged Back For Redrill 5-504 Service Water Injector Shut -In IV -200 (Exploratory (Abandoned Exemption for Freshwater Aquifers (20 AAC 25.283, a, 3-4) Well 5-205a is in the West Operating Area of Prudhoe Bay. Per Aquifer Exemption Order No. 1 dated July 11, 1986 where Standard Alaska Production Company requested the Alaska Oil and Gas Conservation Commission to issue an order exempting those portions of all aquifers lying directly below the Western Operating Area and K Pad Area of the Prudhoe Bay Unit for Class 11 Injection activities. Findings 1-4 state: 0 • 1. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit do not currently serve as a source of drinking water. 2. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit are situated at a depth and location the makes recovery of water for drinking water purposes economically impracticable. 3. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit are reported to have total dissolved solids content of 7000 mg/I or more. 4. By letter of July 1, 1986, EPA -Region 10 advises that the aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit qualify for exemption. It is considered to be a minor exemption and a non -substantial program revision not requiring notice in the Federal Registrar. Per the above findings, "Those portions of freshwater aquifers lying directly below the Western Operating and K Pad Areas of the Prudhoe Bay Unit qualify as exempt freshwater aquifers under 20 AC 25.440." thus allowing BP exemption from 20 AAC 25.283, a, 3-4 which requires identification of freshwater aquifers and establishing a plan for basewater sampling. Detailed Casing and Cement Information (20 AAC 25.283, a, 5-6) 5-200 de -complete: 10/26/2017: NU and test BOPS, pull and lay down existing 3-1/2" tubing. Cut and pulled casing, set a bridge plug at 2953', pressure tested casing to 2000 psi, whipstock set at 2925'. Cut pulled 7" casing at 2788'. Set EZSV @ 2740' and pressure tested the 9-5/8" casing. Well 5-200a window milled on 10/31/2017. TD reached on 11/13-14/2017 Pressure Test Information (20 AAC 25.283, a, 7) Ran and cemented 7" L80 casing to 14,150'. Cemented with 445 bbls of Arctic set and Class G cement. Pressure testing casing to 3500 psi for a good test. Ran and cemented 4-1/2" 13Cr85 liner to 15,659'. Cemented with 65 bbls of 15.8 ppg GasBlok cement. Pressure testing casing to 3500 psi for a good test. After running the 4-1/2" completion, the IA and tubing was pressure tested to 3500 psi for a passing pressure test. Please see completion schematic Accurate Pressure Ratings of Tubulars and Schematic (20 AAC 25.283, a, 8) TRS= CWV4-1116' ML MSTRDRY HDLE VVEIL.HLAD = 11' 5M TMC ACTUATOR - _ OKB= --- 6&59 RR~ ELL# = 6232' Br B. P/ - 36.49' KOPz 2734' Mix Angb = 104" 15127 omw A0 = 9449' DeiMM PVD= 5000' SS 8.51x• CSG, 47*. L-60 STC. D8.916' STC, - a.d81" -2734' Minimum ID = 3.725" @ 13956' 4-112" HES XM NIPPLE top OFGEMEMT(Iin7n7) HIV V ERFED w 1BC CEWENT LOG .0152 W. D = 3.958' SAFETY NOTES: WELL ANOLEa TO' @ 13492'. S_2 0 0 A MAX DLS:16.1"$14900'. CHROME TBG& LMR -24-' j 4-1/2' AM X NP, D - 3.613' I .,.f4U I OLH W KDO'N (9.200A) 2734' -2746' ..._ � I ClAr, I M AMUT91G ST NO ND OEVST TYFE VLV LATCH FORT FORT DATE DATE 6 3512 3362 45 KG -2 DDM: BK 16 1212V17 5 4127 3726 57 KG&2 OWA' BK 0 IWV17 4 6886 4510 75 KG&2 SO 8[ 20 122#17 3 9648 5244 14 KGB -2 DW SK -2 0 112&17 2 12366 5970 75 KGB -2 DWf1 BK -2 6 1112&17 1 13767 6387 p63 KG&7 .DMI„ ,. BK -2 0 112)117 13821' H4 -v7' HES X NP, D - 3.913• 13818 _ l 139W T X 5' WFD LTP a o-4a1w VAMTOR 13973' 13978' 4-1rTWt.6Gv-i D=6276' FERFDRAIIDN SUL MRY W (.OG. BAKER MM OR 11122!17 ANGLE AT TOP PERF: 06"@ 16635' tote: Mer 10 Rodwbon DB for P" cal pmt data S17E SW NFERVAi. DArVW SMT SQ7 --- 2-718' 6 M_. ,.. 15535 -15&67 6 12J2Gf 77` _.,.. 2 718 6 15554,15%7 O 12/25117 3.958" 4-112' LNR, 13.5*, 13CR-06 HY O 521, �....,...1569T .82 -0150 bpf, D = 3.0" .._...._ 13987" H5"X4-1/2'X(.xD=3.417 JTwIRA WAG DATE REV BY COW ANTS DATE REV 13Y COW AMM FOL.AT9S UNIT wn L 6e^OOA PLMAT Na,211-125 AR W 5D429-22846.01 SFC 36, TI 2K TVF 430' t, -A A 4504' WET, 64MM96 oa a0 L. OOe1PLmoN 0410914 *&. AAM ArxxtarwF FKa a w F v, 11127117 P-272 SKURACK (5-200A) 12A7117 JM) MG HOODRFMTIDNS 12)14117 BDIJYD FTIAI.: OTFAPFROJAI. 12/29117 JdG1JuD GLV CJO (1212117) BPEiWlwalkm(At=kai 12128/17 AIGJ/DPOWS(12r2SS-2&'17) Name/Size Weight Grade ID Burst, psi Collapse, psi 9-5/8" Surface Casing 47# L-80 8.681" 6870 4760 7" Production Casing 26# L-80 6.276" 7240 5410 4-1/2" Production Lnr/tbg 12.6# 13Cr-85 3.958" 8960 7810 e Wellhead: FMC manufactured wellhead, rated to 5000 psi. Tree: 4-1/16" 5,000psi Tubing head adaptor: 11" 5,000psi x 4-1/16" 6,500psi Tubing Spool: 11" 5,000psi w/ 2-1/16" side outlets Casing Spool: 11" 5,000psi w/ 2-1/16" side outlets 0 Treating Head: A "Buffalo Head" will be rigged up to the top of the tree. This is an adaptor flange with 4-1/16" 10K bottom flange and 4" 1002 top connection. It also has four 4" 1002 side outlets with 4" 1502 crossovers. The buffalo head is used when fracturing with coil or E -line is planned. Coil/E-line rigs up to the top 4" 1002 connection while fracturing pumping iron rigs up to the side outlets. Geological Frac Information (20 AAC 25.283, a, 9) ? v fq, v' l Litholo is Description Geological Name MD Top, ft TVD Top. ft MD Thickness, ft TVD Thickness, ft Est. Frac Pressure THRZ Shale 14240 6636 285 179 0 7 TKUP-TKUD Sandstone 14525 6815 2 1 06 TKC4 Sandstone 14527 6816 18 11 061 TKC3D Sandstone 14545 6827 10 5 063 TKC3C Sandstone 14555 6832 36 20 064 TKC38 Sandstone 14591 6852 61 29 064 TKC3A. Sandstone 14652 6881 64 26 065 TKC2E Sandstone 14716 6907 36 12 065 TKC2D Sandstone 14754 6919 53 10 066 TKC2C Sandstone 14807 6929 NIA N..A 066 When we frac the kuparuk formation, decline analysis is what determines the closure pressure for the C4 sands. This can be obtained from an injectivity test. A quick look at a conventional GR curve for a typical Kuparuk producer looks something like this: Note the sharp contrast between the relatively clean sandstone of the Kuparuk (@^'6715') vs the shale of the kalubik above it. Shales have a much higher poisons ratio relative to sandstones and thus, have a much higher closure pressure. The sandstones and shales below lack the contrast in GR and are likely to have a closure pressure similar to that of the C4 itsself. BP has data to confirm the closure pressure of the confining shales is 0.83 psi/ft • G'�" ki 0 Location, Orientation and a Report on Mechanical Condition of Each Well that may Transect Confining Zone (20 AAC 25.283, a, 10) jCD Data Sources: Fe -eq A- --*V 3a 0- Survey . All wells have cement isolating the Kuparuk production interval %r Well Name Casing Type Casing Size Casing Depth Hak Size Volcmt TOC est. via TOC TQC Top of payintetval Zonal Isolation? Comments Inches Feet kwhes Cu Ft MDFeat TVDssFeet TVDssFeet -119 PC Production Casing 7 16514 9.875 538.2 Volumetric 14948 6247 6775 Yes MIT-IA:400D psi, 4/2005 S-102 pc Production Casing 711719 9.875 721.05 Volumetric 9621 5529 6702 Yes MIT-IA:4000 psi, 9/2012 S-102 pi Production Liner L.5 1310D 6.125 6555 Volumetric 11731 6701 6745 Yes MIT-IA40DD psi, 9/2012 S-100 pc Production Casing - 10250 9.875 650 Log 7908 5223 6619 Yes MIT-TxIA: 35M psi, 5/2010 5-100 pl Production Liner _ 5 12150 6.5 287 Volumetric 10308 6751 6619 Yes MIT-TxIA: 3500 psi, 5/2010 5-114 N/A N/A N/A N/A N/A N/A 12600 5321 6608 Yes MIT -IA: 3000 psi, 2/2015 S -114a pc Production Casing 14555 9.875 511.75 Volumetric 13066 5621 6656 Yes MIT lk 30DO psi, 2/2015 S-106 pc Production Casing 15817 8.75 391 Volumetric 13814 5451 6747 Yes MIT-TxIA: 2250 psi, 8/2017 5-106 pl Production Liner =.5 17575 6.125 244.95 Volumetric A N.,'- 6747 N/A hIIT-TxIA: 225D psi, 8/2017 5 107 pc Production Casing 12421 9.875 1198 Volumetric 8935 5D74 6658 Yrs F1IT-IA: 2154 psi, 4/2017 5-107 pi Production Liner =.5 15980 6.125 227 Volumetric 13163 6930 6658 No I.i!T-IA: 2154 psi, 4/2017 0 0 Location of, Orientation of, and Geological data for each known or suspected fault. (20 AAC 25.283, a, 11) BP's technical analysis based on seismic, well and other subsurface information available indicates that there are 8 mapped faults that transect the Kuparuk interval within the % radius of the wellbore trajectory for S - 200A. Fracture gradients within the confining zone (Kalubik and HRZ) will not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. The HRZ and Kalubik in this area are predominately shale with some silts with an estimated fracture pressure of—16ppg. Thickness and fracture pressure for the confining layer is discussed in Section 9. -- v,'5 51Cgr%/6 The S -200A crossed one mapped fault in the Kuparuk interval. Fault #2 terminates in the Colville. Fault #2 did take losses when drilled (800 bbls). S -200A Fault MD SSTVD THROW Fault #2 15170' • 6795' 30' (DTW) The S-107 crossed two mapped faults in the Kuparuk interval. Both Fault #1 and fault #2 terminate in the Colville. There were no report losses with Fault #1 and Fault #2. The Fault #1 crossing in S-107 is greater than 600' from the S -200A and the Fault #2 crossing in S-107 is greater than 1100' from the S -200A. S-107 Faults MD SSTVD THROW Fault #1 13280' 6930' 114' (DTW) Fault #2 14480' 6971' 32' (DTW) The S -114A crossed one mapped fault in the Kuparuk interval. Fault #5 terminates in the Colville. The is fault did take losses when drilling S -114A. The Fault #1 crossing in S -114A is greater than 1800' from the S -200A. S -114A Fault MD SSTVD THROW Fault #5 14607' 6846' 76' (DTSE) Fault #3, Fault #4, Fault #6, Fault #7 and Fault #8 all terminate in the Colville. Their displacements and sense of throw are given below. Faults THROW 0 Fault #3 110' (DTNE) Fault #4 100' (DTN) Fault #6 130' (DTE) Fault #7 35' (DTN) Fault #8 30' (DTS) C Frac locations 1 and 2 are closest to known Faults #1 and #2. The wellbore generally drilled perpendicular to the maximum stress orientation in this area which runs N/S (10° W of N) based on a regional stress map. With ✓ this wellbore orientation, a transverse fracture will be created leaving an 800' standoff from Fault #1 and 600' JL5 L standoff from Fault #2 assuming' half-length for Frac location #1. A transverse fracture will also leave 150' standoff from Fault #2 assuming half-length for Frac location #2 / '5�-G' tG� 3 °%` 1 Expecting –300' fracture half -lengths; minimum stand-off from the closest faults can be seen in Table 1— Standoff Values. TABLE 1 -STANDOFF VALUES. Frac #1 14530-14562' MD Fault 1 800' Fault 2 600' Frac #2 15015-15025' MD Fault 2 150' Summary Hydraulic Fracture Program (20 AAC 25.283, a, 12) (Detailed Program and Pump Schedule included) Fault: 15170ttMO Above is a cross-section of the wellbore. Due to the relatively wet nature of the toe section of the wellbore, BP intends to only frac the heel section. Approximate frac locations are labelled with orange lines. The maximum horizontal stress has been determined to be nearly perpendicular to the wellbore, this is based on historical information as well as borehole breakout data. The maximum horizontal stress means that the induced hydraulic fractures will be perpendicular to the wellbore. Maximum Anticipated Treating Pressure: 3500 psi Maximum Allowable Treating Pressure: 5000 psi Stage 1-2: Anticipated half length: 150' Anticipated height growth: 90' Due to the horizontal nature of the well and the transverse nature of the fracs, we are unable to specify a MD for the frac height. Each frac will initiate at their corresponding perforations. The perforations are located at: Frac Stage MD, feet TVD, feet Approx. TVD Height of frac 1 15015'-15025' 6915'-6912' 6795'-6885' 2 14530'-14562' 6818'-6836' 6815'-6905' The above frac dimensions were calculated using modeling software. Surface pressure is calculated based on a closure pressure of —0.61 psi/ft or 4200 psi, this combined with the anticipated net pressure to be built, hydrostatics and the friction gives a surface pressure of 3500 psi at the time of flush. The frac height is primarily based on closure pressure differences between the confining shale layers and the unconfined sandstone reservoir. Average confining layer stress is anticipated to be —0.7 psi/ft. Half length is based on confining layer stress as well as leak -off and formation modulus. Given the values, the above half lengths are calculated. Pressure Test Information (20 AAC 25.283, a, 7) Per the drilling program, the both the tubing and the IA will be pressure tested. The IA will be tested to 3500 psi and the tubing will be tested to 4000 psi. PRV setting procedures and annulus monitoring: Maximum Allowable Treating Pressure: 5000 psi Stagger Pump Kickouts between: 4750 psi and 4500 psi (95% to 90% of MATP) Global Kickout Treating Line Test Pressure IA Hold Pressure OA Minimum Water Reauirement OA 4750 psi (95% of MATP) 6000 psi 2200 psi Monitor and maintain open to atmosphere 3000 bbls (pump schedule: 2600 bbls) Monitor and maintain open to atmosphere There are three overpressure devices that protect the surface equipment and the wellbore from overpressure. Each individual frac pump has an electronic kickout that will kick the pumps into neutral as soon as the set pressure is reached. Since there are multiple pumps, these set pressures are set between 90% and 95% of the maximum allowable treating pressure. There is the primary pressure transducer in the treating line that will trigger a global kickout which will kick all the pumps into neutral. Finally, there is a manual kickout that is controlled from the frac van. All three of these shutdown systems will be individually tested prior to high pressure pumping operations. Additionally, the treating pressure, IA pressure and OA pressure will be monitored in the frac van. 5-200a Rig Up ---------------- rac Cat Caauol S'aa as3 Laa r s Chemical Disclosure (20 AAC 25.283, a, 12) 0 Disclosure Type: Pre -Joh Well Completed. 2/9/2018 Date Prepared. 1/13/20181:24 PM Report ID: RPT -52881 rh. eem�ra�en.�:.rw»en.e.ei.:aeew nn�.rnv u.w...nw.t..rr.rsys. w.w.mersww�� - Water (InckadYq Mix Water Supplied by Client)' -72% 66402.681 Ceramic materials and wares, chemicals -27% 14806-W7 Quartz, Crystatline silica < 1 % 90OD-30-0 -- Guargum <1% 67-48-1--- _----- _ — 2-trydroxy-N, N," iettMw4"n rauM d*xide <I% 102-71-6 7727-51-0_ 56813 ....-- -....---------- r 2,2',2"-nkrdctrie"-MA Diammonium peroxidisW ,,__,_. Pronevpl <0% _. . c 0.1 % c 0.1 % 1309-961 Sodium tetroborate deo <0.1 % 67-63-0 Propan-2-ol <0.1 % 111-76-2 2-butoxyethanol <01 % 3439801-1 EthoxylatedCSS Alcohd <01 % 107-21-1 Ethylene gWa <01 % 63.42-3 lactose <01 % 129898.01-7 2-OropenoicKid, With Sock- <01 % 68131-39-5 Ethax~Akahol <0.1 % 68131-40.8 Akohds d1 -15 -sec ed <0.01 % 7647-14-5 Sodiumchkwide <0.01 % 10043-52-4 312-42-5 CalOum Chloride Undecanol < 0.01 % <OAl % 93053-39-3 Diatomaceous earth calcined 7631-86-9--------- —^-------� Non-uyAalline silica (impuiily) <0.001 % 10377-60.3 MagnesmimnrMe <O.001% 9050.36.6 Mattodexbin <O.001 % 111-46.6 2,2"-oxydw&wmllitrpuirity) <O.001 % 26172-55.4 5Khloro-2-ffwM*2h-isothiazoloF3one <0.001 % 77W30-3 Magnesium ch"e < 0.001 % 1310-73-2 Sodium hydromcle "purity) <0=1 % 127-08-2 Acetic acid, potassium sah <O.0001 % 7047-00.7 PM . 1 chloride funpunitt <O.0001 % 2682-20-4 14464.46.1 900453.9 2 2h saattiazd 3 one Crutobakte `... Dextrin <O.0001 % <MOM % <O.0001 % 64-19-7 Aatic <0.0001 % 901234-8 Hen"m*dne el <OA001 % Wellwork Procedure Request To: Well Services Operations Team Lead Date: 10/9/17 S Wireline Operations Team Lead 3. VER1 Install Tree -saver, set Saltel Packers, In II Buffalo head, Hydraulic Fracture Treatment 4. AFE: D&T, Install GLVs From: David Wages - Well Intervention Engineer Post frac flowback Todd Sidoti - Well Intervention Engineer IOR: Est. Cost: f Subject: S -200a - Pre and Post Frac Procedure - l Please perform the following steps j' 1. W Install Production Tree, Test tree and compone ts, Pull TWC 2. S Pull DCRV, Install DGLV, pull B&R, Pull RHC 3. SP,C Install Tree -saver, set Saltel Packers, In II Buffalo head, Hydraulic Fracture Treatment 4. S D&T, Install GLVs 5. T Post frac flowback Current Status: Minimum ID: Max Deviation: Top Perf Deviation: Last TD Tag: Last Downhole Op: SBHP/SBHT: Latest H2S: Program Contacts New RST 3.813" at 4-1/2" X -Ni 107 deg at 15,200' 1 50 deg at 14,500' D N/A New Well N/A New Well New Well, 320 est. est @ 10 ppm ✓ VV/ (V Z' - v Z'� I Page 11 of 9 Contact Phone - Work Phone - Mobile / Home Interventions Engineer David Wages 907-564-5669 713-380-9836 Interventions Engineer Todd Sidoti r 907-564-5113 907-632-4113 VV/ (V Z' - v Z'� I Page 11 of 9 rl 1. Critical Issues E A. Tree Configuration a. To shift the NCS style sleeves and pump our frac job, a Buffalo head needs to be rigged up. Available from Stinger, this is a cap on the tree that has a connection on top for coil and 4 side outlets for hooking up frac pumping equipment. 2. Procedure A. Wellhead- Install production tree, pull hanger plug Verify the tubing has been tested to 3500 psi Verify the IA has been tested to 3500 psi a. Install production tree. Test to 5000 psi. b. Pull TWC/BPV B. Slickline- Pull BSER, Pull Circ valve, Dummy GLM, Pull RHC a. Drift to RHC b. Pull ball and rod c. Pull circ valve d. Install dummy gas lift valves e. Pull RHC C. Coil/Special Projects- Pump stimulation • 2" coil used for stimulation. • Overpulls are to be managed on the fly, plan on pumping pills of safelube laden KCI between stimulation stages. a. Install tree -saver b. Pressure up on the backside to 3000 psi and hold c. Pressure up on the tubing per Saltel setting procedure: Page 12 of 9 0 0 Bekr* is the deladed setter sequenca. The proc es s i r c I odes Packer expansw venficallm (volmie meas t) PF. E S - E.1. 1 E - PAP RAT E 1, Increase casing internal pressure 2 Establish volume marker on the mud tank (optional: 3, Increase Casing trtemal pressure No expansion of the packer Plastic deformah-or of the sleeve starts at pressures higher than 2C,C0 [psi] 4- Pressure is further increased to 4400 [ptsi] o Parker diameter increases but is not yet in contact �oiith the borehole 5- Pressure is increased gradually to 5800 [w] o Increase pressure over 10 min- minimum Cr Target ar-get stair -step pressure increase of 100 psi during 1 minute each 6- Bleed off to same level as 2 and determine Expansion volume ;optional`; o Theoretical volume to set packer is 1 "K [;al] d. Bleed pressure off tubing, then backside, RD tree -saver FRACTURE STIMULATION Pressure Criteria -CT Annulus (Frac Side) ONLY Maximum Allowable Treating Pressure: 5000 psi Stagger Pump Kickouts between: 4750 psi and 4500 psi (95% to 90% of MATP)_ Page 13 of 9 0 Global Kickout Treating Line Test Pressure Minimum Water Requirement IA Hold Pressure OA Pressure Criteria -CT ONLY Maximum Allowable Treating Pressure: Stagger Pump Kickouts between: Global Kickout Treating Line Test Pressure Minimum Water Requirement a. Install Buffalo head 4750 psi (95% of MATP) 6000 psi TBD bbls (pump schedule: TBD bbls) 2200 psi Monitor and maintain open to atmosphere 7000 6000 psi and 6600 psi (95% to 90% of MATP) 6500 psi (95% of MATP) 8000 psi TBD bbis (pump schedule: TBD bbls) a. Uses BX155 gasket, ID: 4-1/16" b. MIRU CT Unit and SLB frac and pressure test BOPs. c. RIH w/ NCS BHA (Max OD: 3.785"), typical setup: a. 2" CTC b. Memory Gauge c. Disconnect Shear Sub d. 4-1/2" 2 Dot Centralizer e. Disconnect Ball Seat Carrier, Ball and seat size TBD on job f. 4-1/2" 2 Dot Centralizer g. Blast Joint h. Port Sub i. EQ Valve w/ Ball Check j. 4-1/2" Shift/Frac/Close Packer k. 4-1/2" 2 Dot Vulcan MS Locator I. Decompression Sub m. Gauge n. Pin x Pin X -Over o. 4-1/2" 2 Dot Magnetic Bullnose w/ Magnetic carrier d. Locate sleeve #1 and shift open per NCS procedure. e. Stimulate stage #1/Port #1 per pump schedule i. If overpulls are seen while dragging through blank pipe, sand may be caught up in the drag blocks. Follow NCS procedure to clean up packer/wellbore. f. Continue to shift and frac remaining sleeves per pump schedule and NCS shifting procedure g. POH D. Slickline- D&T. Install GLVs a. Drift to deviation. b. Install Deep GL design if possible Page 14 of 9 • 0 E. Testers- See Appendix for Post Frac Flowback Page 15 of 9 0 0 Appendix A - CT FCO Procedure Notes: • To be performed if unable to get a clean well with the NCS BHA deployed. • This is a generic FCO procedure for a post frac FCO. Specific info such as amount of proppant left in tubing and estimated sand top will not be known until after the job is pumped. • The objective of this procedure is to get the well cleaned to facilitate post frac well test or to continue frac operations. • Recommend reviewing PE Manual section for Coiled Tubing Fill Cleanouts for specifics on reversing rates, speeds and CT loading. Planned Procedure 1. MIRU CT 2. MU BHA. 3. RI down to estimated sand top and begin cleaning out with slick 1 % KCL. 4. Continue down to 14,300' CTMD (depth to be determined post RST). At this point we are close uppermost sliding sleeve. Ensure CT is clean as it is expected that returns will begin to fall off as the nozzle nears the sleeve. If returns begin to fall off, reducing BHP by lowering rate may keep returns at a manageable level. 5. Slowly continue to clean out until returns fall off to —80%. If returns are still good even after the nozzle is past the sleeve (not likely but possible), continue to clean out to TD a. If returns are too low, it may be necessary to mill the bridge plug without taking returns. 6. FP to 2500'. 7. Pump a gel pill at surface out to the tanks to ensure CT is clean if necessary. 8. RDMO. Page 16 of 9 0 • Appendix C - Test Separator Additional Flowback Procedure 1. MIRU ASRC. RU equipment to in a manner that allows CT to RU if an additional FCO is necessary. 2. POP the well to ASRC at minimum choke. Flow the initial returns to the flowline as long as the shake -outs meet the returned fluid/solids management guidelines. 3. Limit flow to 500 bpd 4. If solids are < 1 %, increase the production rate to 1000 BLPD. 5. Flow bottoms up and sample for solids production. If solids are still below 1 %, allow well to flow to 1500 BLPD. Flow bottoms up and sample for solids production. If solids are still below 1 % continue to increase the flow rate in 500 BPD increments. The objective is to achieve maximum drawdown. Watch returns and do not continue to open choke if solids > 1 %; allow well clean up before choke is opened further. 6. Once at FOC, stabilize the well for 4 hrs. Obtain a 3 hr purge, 8 hr welltest. Page 17 of 9 VW HEAD = ................................................. 11' SNI FIC .............. ,ecnd+,aR.=_ ..............................3r ........ ............. �_aFv- ............................................................... N3P=.. ............................................................. DI' oFrNo= F>Ir.�vo = sw ss 0 PROPOSED ls'WW -j--J 293V "M CSG.47*. x -M er-o = 8 87' -263r IWWCFCUKWF I I 1 — IU P(F+1IrLNR I- 4-W—MlGL% M17CR-i6VAUWV — A'152 bpb, in = 3DW 3WA-WVAUKW. I -L SO4T at o= ezra 441!" IES 3rWATF31 SWELL FRCMM NO O F9H D 4 3 2 1 3 -IR -AM MRMWI3_ In=2-21x, 4-W— LFR 13-W 17pF49 HVO 52f. A15obpr.o=3.. M +1r2' I14Z 13�E 1�Ie-ss Hro �1- -C JwImbmc [7 =3- 0 %/ SAFHVNUYENE S:CHRU-MCA LMR i� V-200 ,%, --14-iju-HMxNp-o=3Bla- SF I UD I -MU 113EV I WFE I VLv I LA7CH I R3;UF MME -�--FV-7"m xw n=3 3- rx4 Y2'IP panuLo=3Ew •Q +urHFsxn�o=3313' +1lrHMXW.D=3SF3' T-x!r Bm HFO-F1XPl7Rr/>®0.GICSLV: sur VN$- o= rx5'B1QZH5LiFiB�OCKr Hat -1]=429' NCS HYD 321 FRAC SL.EWS L"s! MLZ.J�Om IMEME 4-1p MM SNF HMG 1001_ VF34UA7M SUL 17= 3" 4-V--W&MOMM iVALVE --� +1rrx3-urxa_o=2_sae- Page 18 of 9 VYaL- F1FMW N¢ ARN¢ 51F023 -223460V SFC 3FLTia . T1Z F 43r NSL 6 4WW WFi Bralps rafiom JALE k2l 0) ("Ise woo,) (19d) aJnsSOJd le!WeJap(] Jelnuuy (Q O90Zt 000% 0008 0009 0009 OOOZ 0 OOoZ- o009- 0009- 0008• OOOOL• OOOLL• (D 000SLE- Cc)-------- .................. ......................... ;. 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I ; 00( 0 t : ; ooc :t WI9NlUW0'J 1 ........ {......... ..... ... }........ {.........t:.......{......... i........ {......... {------ ;.........j........}........ OOC ' .... ..... .... ..... ..... .... ..... .... OOC M -LW a ; 1 -UW.: (>s OeJd . ....._. OSZ llelxeui ,. �... -----OOE-L uolsusl;.......--:- ................ : .. 00 t)sine ----- ........ OOC suowOuoO le0.u) . 000 Jope3 NaleS leveul ainlosgb 000'S 909 an* 8C6E £8SE Re SLBZ LZSZ L9LZ "OL 8591 90t1 OSLO 0008 ......... .......... 009 . ....... ........... ...... ..'............................. ........................._..... 009 ..... ..... ................... ............... .............. ....................... ..... OOOZ ......... .......... ......... :......... :......... :......... .... .... ......................... ..... 000 ..... ........ ..... ..... ..... ....... ...... ... .?............... ----- 0008 pyLl = Joped IseO le0u!OL • : , bl•LIW • ," -•i•• - 0009 LLIW t• w OS OeJ1 ,c ; suogp000 lewul. --•tt t •� �k; G ulgnl uoilonpold .Zit 9-Joped AajeS lelx Ja Uij U0113r)DOJd .Z1L 9 Usn 00 E89St 6ulSeD UOiI'inpnJd L USO 00 L9L91 ® l01 USn OOL909t esn nt �jt oulsep aoepnS .ws 6 Usn 009E8Z aJe C Cr CD ic O L CD C N 4 0 0 Date: October 12, 2017 Subject: S -200a Fracture Stimulation From: David Wages Engineer, BP Alaska o: 907.564.5669 c: 713.380.9836 To: AOGC Commission Attached is BP'sro osal and supporting p p documents to fracture stimulate the Kuparuk interval of well S -200a. S -200a is a planned rotary sidetrack. It is a "U" shaped well with offtake points at the heel and toe. The target is an un -swept portion of a fault block outside of the producer -injector pattern. We are requesting a variance to sections 20 AAC 25.283, a, 3-4 which requires identification of fresh - - water aquifers and a plan for basewater sampling. We are also requesting that the requirements in section 20 AAC 25.283, a, 10 be met by pressure tests of the tubulars on the well to be stimulated and by investigation into the mechanical condition of the wells within 1/z mile of the wellplan within the producing interval. Please direct questions or comments to David Wages Affidavit of Notification (20 AAC 25.283, a, 1) Partners notified 9/11/2017: `r ConocoPhillips ExxonMobil Chevron Department of Natural Resources 0 Plat Identifying Wells (20 AAC 25.283, a, 2, A -C) and Faults (20 AAC 25.283, a, 11) Green lines indicate approximate length and location of the frac. - Producers within 1/2 mile of S -200a: S-107 I S-114 S -114a Per the plat above, there are no water wells within '/2 mile of the subject well. The above map shows 2 primary faults of concern: Fault #1 which is approximately —300' away from S-200a's wellpath and —150' away from the max expected frac length. Fault #2 is approximately —600' away from the frac initiation point and —500' from the max anticipated frac length. Both faults are roughly parallel to the anticipated frac direction. If a sudden change in pressure is seen during the fracturing treatment indicating connection to the fault, pumping operations will cease. Exemption for Freshwater Aquifers (20 AAC 25.283, a, 3-4) Well S -200a is in the West Operating Area of Prudhoe Bay. Per Aquifer Exemption Order No. 1 dated July 11, 1986 where Standard Alaska Production Company requested the Alaska Oil and Gas Conservation Commission to issue an order exempting those portions of all aquifers lying directly below the Western Operating Area and K Pad Area of the Prudhoe Bay Unit for Class II Injection activities. Findings 1-4 state: 1. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit do not currently serve as a source of drinking water. 2. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit are situated at a depth and location the makes recovery of water for drinking water purposes economically impracticable. • 3. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit are reported to have total dissolved solids content of 7000 mg/I or more. 4. By letter of July 1, 1986, EPA -Region 10 advises that the aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit qualify for exemption. It is considered to be a minor exemption and a non -substantial program revision not requiring notice in the Federal Registrar. Per the above findings, "Those portions of freshwater aquifers lying directly below the Western Operating and K Pad Areas of the Prudhoe Bay Unit qualify as exempt freshwater aquifers under 20 AC 25.440." thus allowing BP exemption from 20 AAC 25.283, a, 3-4 which require identification of freshwater aquifers and establishing a plan for basewater sampling. Detailed Casing and Cement Information (20 AAC 25.283, a, 5-6) Well S -200a is to be spudded in mid-October 2017. Please see Proposed Completion schematic 61, • Accurate Pressure Ratings of Tubulars and Schematic (20 AAC 25.283, a, 8) Tom= RNV 8Y CtMMt ",- _ _ _ En- wwrw `OR= PROPOSED S -200A 1123A9I _f_I,_ TEI.CHROME TBG &I.NR ,WteV = 62.18' SWETRACK(S-20CIA) L-80 _- !BF. R -EV = 3T JM7 BUI T F'FZCX(x;F�i _ KOP= 2934' .Max AIV*_...__ 4112'k�XNP, •3.113' Daban MD 6.276 BP Exploration (Alaska) 'LAbm tVO= 5000' SS —_ --- — 9-518• WMMTOCK (_7-1�� 21W 3.958 GAS Li•T MRCS 7500 ISTJ MD I TVD UW TYPE i VLV LATM7 FORr DATE 9.518• CSG, 47N• L-80 STC,2-7—W--1 I 4 3 T—" Minimum 0 a 1 TOP OF CB0Ejw C -1_7__j J:� 4-112' FES X NP, D = 3.817 T X 4112" HB"s 7NT FKR D = 3 H58' bpi, Ip - 8278' NCS HYD 521 FRAC Si_EVES ND nEPIH MN D OAC DATE 41 Q- H83 39 WATER SWRL PACK MB / 3 '. ................ NO DFPRI p / 2 4 C9 0 1 — _t CK x 3117' ANCHOR PKRA�',10-2."2- 4- 1rr .997' 41rr LNR 12.60.13CPAO HY 0150 bpf. D - 3.958 L� l-HY LNR 12.8At, 13CR-� VCS S2� I6'% __ EPUM ms: J 0150 bpi. D - 3 M. [)4TE.... RNV 8Y CtMMt ",- --w1CTFw8y POLARS ONT WELL. S -200A FE ROW APIW: 50421122846-01 SEC 35, T12N, T12F, 430' WL S 4500' WR. 1123A9I _f_I,_ I ORGMML COMPLETION 9-5/8" Surface Casing SWETRACK(S-20CIA) L-80 0012i96 JM7 BUI T F'FZCX(x;F�i _ 7" Production Casing 26# L-80 6.276 BP Exploration (Alaska) 5410 —_ --- — Name/Size Weight Grade ID Burst, psi Collapse, psi 9-5/8" Surface Casing 47# L-80 8.681 7930 4760 7" Production Casing 26# L-80 6.276 7240 5410 4-1/2" Production Liner/tbg 12.6# 13Cr-80 3.958 8430 7500 0 Wellhead: FMC manufactured wellhead, rated to 5000 psi. Tree: 44/18^5iOOOpoi Tubing head adaptor: 11^5'OOOpoix44/1G^5iOOUpoi Tubing Spool: 11^x13-5/O^5iOOOpoim/2'1/l8^side outlets Casing Spool: 13-5/8" 5,000psi w/ 2-1/16" side outlets Geological Frac Information (20AAC 25.283'o'9) 0 Formation Estimated Formation Top Estimated Formation Top TVD Thickness (ft) Frac Gradient (PSOU Lithological Description THRZ -6467 271 0.70 Shale TKUD -.6738 14529 21 0.60 Sandstone TKC3D -6759 14561 20 0.61 Sandstone TKC3C -679 14595 35 0.61 Sandstone TKC3B -6,814 14665 39 0.62 Sandstone TKC3A -6853 1478-4 0. 6-C Sandstone TKC3B-invert -6826 150aO 33 Sandstone TKC3C-tffvert -6792 15199 '33 Sandstone TKC3D-invert -6771 15322 '210 Sandstone TD -674-1 15739 Sandstone 0 • Mechanical Information of nearby wells (20 AAC 25.283, a, 10) Web Nat,te Casing T Site Casing Depth Hole Sue Vol cmt TOL est. via TOC TOC Top of pay Mtervai 7...ai ksaHdw? Comments tithes €eet b cbes Cu Ft MDFeet TVOssFeet TVOssFeet 5-137 pc Pmouctnn Casi 12421 4.875 1148 Volumetric 8335 5074 5.61.3 ves 5-137 p Prcducttion tarter 15380 6.125 227 Volumetric 13163 6430 6653 No 5:ntted '. ner at the tae. an production interval S-11Sa pc Prcdu ,an Lasting 14555 4.875 511.75 Volumetric 13066 5621 665c res FuIi Returns dun job 5-115 WA WA N: ». WA NIA NfA 126110 5321 6fiC3 ' PSAtl Summary Hydraulic Fracture Program (20 AAC 25.283, a, 12) (Detailed program included) Hydraulic fracture treatment schedule stage 1, 2 and 3 (same pump schedule per stage): The induced fractures are expected to propagate at 30 degrees west of north. Maximum Anticipated Treating Pressure: 4500 psi Maximum Allowable Treating Pressure: 5000 psi Surface pressure is calculated based on a closure pressure of —0.64 psi/ft or 5500 psi, this combined with the anticipated net pressure to be built, hydrostatics and the friction gives a maximum surface pressure of 4500 psi at the time of flush. Anticipated half length: 250' , Half length is based on confining layer stress as well as leak -off and formation modulus. Given the values obtained from analog wells, the logs and log interpretations, the above half length is calculated. Anticipated height growth: 80' The above frac dimensions were calculated using modeling software. The frac height is primarily based on closure pressure differences between the confining shale layers and the unconfined sandstone reservoir. Average confining layer stress is anticipated to be —0.7 psi/ft. 0 . Pressure Test Information (20 AAC 25.283, a, 7) Per the drilling/fracturing program, the both the tubing and the IA will be pressure tested. The IA will be tested to 3500 psi and the tubing will be tested to 3500 psi. The wellhead will be tested to 5000 psi, a tree saver will not be required. PRV setting procedures and annulus monitoring: Maximum Allowable Treatinq Pressure: 5000 Stagger Pump Kickouts between: 4500 psi and 4750 psi (90% to 95% of MATP) Global Kickout: 4750 psi (95% of MATP) IA pop-off set pressure: 2600 psi (<75% of MIT -IA) Treating line test pressure: Sand Requirement Minimum Water Reauirement IA Hold Pressure OA 6000 170,000# 16-20 Carbolite, 145,000# 16-20 CarboBOND, 3000# 20-40 or 16-30 sand 1800 bbls (pump schedule: 1400 bbis) 2300 psi (IA pop-off @ 3000 psi) Monitor and maintain open to atmosphere There are three overpressure devices that protect the surface equipment and the wellbore from overpressure. Each individual frac pump has an electronic kickout that will kick the pumps into neutral as soon as the set pressure is reached. Since there are multiple pumps, these set pressures are set between 90% and 95% of the maximum allowable treating pressure. There is the primary pressure transducer in the treating line that will trigger a global kickout which will kick all the pumps into neutral. Finally, there is a manual kickout that is controlled from the frac van. All three of these shutdown systems will be individually tested prior to high pressure pumping operations. Additionally, the treating pressure, IA pressure and OA pressure will be monitored in the frac van. Chemical Disclosure (20 AAC 25.283, a, 12) '°=.- F.11 2 J475 X04 A91 142,716 Gal NKW M27S S012-1630 S123 5522-1620 5526-1620 cklem BP ExpkwaMn Alaska Schlumberger Well 5-200A 145.0 Gal �v� .,eld Prudhoe Bay 1"3DD Lb 20 Q Gal 144.5500 Lb 1450.0 Lb Alaska 64742-47-8 CouMiPansh: North Slope Borough <1% Case Guar M"n -iisoosureType: Pre -Job ,':._i I Conwpleted 11/3/20I7 ate Prepared IO/W2017 3:30 PM ID RPT -51047 '°=.- F.11 2 J475 X04 A91 142,716 Gal NKW M27S S012-1630 S123 5522-1620 5526-1620 T- -'lay Stabifixe+ Crasslanker Slide Addifte Bactenade Water (InCI41d I ',I I -T-' 290.0 Gal 145.0 Gal 8850 Lb .... 66402-6-&-4 - - -- --------------- 145.0 Gal 1160 Lb 6D.0 Lb 1"3DD Lb 20 Q Gal 144.5500 Lb 1450.0 Lb <i% - 64742-47-8 Distvllwte�. K-lln-, "dratre-d Water (InCI41d I ',I I -T-' % .... 66402-6-&-4 - - -- --------------- Ceranvicma7- 21 % 148OB-60-7 <i% - 64742-47-8 Distvllwte�. K-lln-, "dratre-d <1% Guar M"n 1319-33-1 % 107-21-1 EUWI"w G" - ---- ------- < 0. 1 7727-54-0 Dwwnonnjrn perouWbuWate <0-2 129899-01-7----------- -roperow add, pwwwer Wild, so�aen <0-1 % 7647-14-S Sodwn chlonde <0-1 % 7736303 NUVIesm" chlorode <0-1 % 2SO35-72-6 VbWklene d6onde/methViscrytate 11 - <0.1 % 31726-34-9 - ---- . . ......... - -----. - - aWwhv*owegahvdrawV- <0-01 % 1303-96-4 <Q-01 % 1310-73-2 Sock- d hydr-e ice( < 9-91 %66i4_3"- -' ' ' - " - ' �Amw tMaved gnamte copy <001 % 6-63-0 Pr 2-01 < 0.61 % . . ........... . WTIdi-secandary. <0-01 % IW43-52-4 CallammOldoride < OLOI % 110-17-8 but-2-enedicir acid <(101 % 910S3-39-3 DwWroareviseard%cilldned % 68131-39-5 Akabob 01235 bvw "bad < 0.01 % 763!-869 SO= Movide < 0.001 % 61789-77-3 DKOW diMledW qU3WwwwV affunanxim chloride < 0.001 % ----10577-fKI-3 MONMIlffis runne <Q.001 % 14IM-96-6 _16172-55-4 Marwgum allicalle hydrae < UM1 % < GMI % 111-4" 2.2--axythethm-al C -p -q) < G.001 % 9(W-8" < OM % 595585 -IS -2 ORMM < 0M1 % 125005-87-0 DRitan guen <0. I% 26V -20-4 2--e"v#-bH5adwwol-3-one - <0-0001 % 7447-4111-7 Potassam chlonde fampunW <0-0001 % 14464.461 Crotobalte <0-0001 % Davies, Stephen F (DOA) From: Wages, David <David.Wages@bp.com> Sent: Tuesday, February 27, 2018 5:30 PM To: Davies, Stephen F (DOA) Cc: Loepp, Victoria T (DOA) Subject: RE: S -200a updated info a) They both are actually... What the 0.7 psi/ft refers to is the minimum closure pressure required of the shales in order for our frac modelling software to accurately represent the treating pressures we see when we frac. 0.83 psi per foot is from our geologists and an injection test that was performed in the shale in the past. The 0.83 psi/ft represents the breakdown pressure with the 0.7 psi/ft representing the frac closure pressure. In the future, our sundries will refer to the breakdown pressure as this is a more accurate depiction of the stresses confining our fracs. b) 150' is correct. We started getting more geology input and I did not double check it, apologies. David Wages BP I AK I Completion Engineer 900 E. Benson Blvd 1744c I Anchorage, AK 99515 Direct: d 1.907.564.5669 1 Mobile: +1..713.380.9836 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Tuesday, February 27, 2018 4:00 PM To: Wages, David Cc: Loepp, Victoria T (DOA) Subject: RE: S -200a updated info David, The updated information is nicely done. Thank you for the additional work. I have only a couple of questions: In Section 9, the geological frac information table lists the HRZ estimated frac pressure as 0.7. The last sentence on that same page indicates that the closure pressure of the confining shales is 0.83 psi/ft. In Section 11 (Geological data for known or suspected faults), the second to last sentence of the first paragraph indicates the HRZ and Kalubik in this area are predominantly shale with some silts with an estimated fracture pressure of —16 ppg. [Which equals about 0.83 psi/ft.] • Does the phrase "estimated frac pressure" signify the fracture initiation pressure (formation breakdown pressure) or the closure pressure? • Which value is correct? In Section 11 (Geological data for known or suspected faults), the second page indicates 300' half -lengths for Frac locations #1 and #2. Section 12 (Summary Hydraulic Fracture Program) indicates the anticipated half - lengths for Stages 1 and 2 are 150'. 0 Which values are correct? i Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Tuesday, February 27, 2018 4:00 PM To: david.wages@bp.com Cc: Loepp, Victoria T (DOA) Subject: RE: S -200a updated info David, • The updated information is nicely done. Thank you for the additional work. I have only a couple of questions: In Section 9, the geological frac information table lists the HRZ estimated frac pressure as 0.7. The last sentence on that same page indicates that the closure pressure of the confining shales is 0.83 psi/ft. In Section 11 (Geological data for known or suspected faults), the second to last sentence of the first paragraph indicates the HRZ and Kalubik in this area are predominantly shale with some silts with an estimated fracture pressure of —16 ppg. [Which equals about 0.83 psi/ft.] • Does the phrase "estimated frac pressure" signify the fracture initiation pressure (formation breakdown pressure) or the closure pressure? • Which value is correct? In Section 11 (Geological data for known or suspected faults), the second page indicates 300' half -lengths for Frac locations #1 and #2. Section 12 (Summary Hydraulic Fracture Program) indicates the anticipated half - lengths for Stages 1 and 2 are 150'. Which values are correct? Section 11 indicates the maximum stress orientation is 10 degrees west of north; the fault map shows Fault 2 as trending NNE. Is the 150' standoff value given for Fault 2 in Table 1 based on a half-length value of 150' or 300'? Regards, 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.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Monday, February 26, 2018 11:48 AM To:'Wages, David' <David.Wages@bp.com> Subject: RE: S -200a updated info Thank you, David. Regards, 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 0 0 or disclosure of such information may violate state or federal law. If you are an unintended recipient oft his e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware oft he mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@aIaska.gov. From: Wages, David [mailto:David.Wages@bp.com] Sent: Friday, February 23, 2018 7:03 PM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: S -200a updated info Steve, Please see attached the updated sundry information as discussed. David Wages SP I AK I Completion Engineer 900 E. Benson Blvd 1744c I Anchorage, AK 99515 Direct: +1.907.564.5669 1 Mobile: +1.713.380.9836 P) 0 Davies, Stephen F (DOA) From: Wages, David <David.Wages@bp.com> Sent: Thursday, February 15, 2018 11:16 AM To: Davies, Stephen F (DOA); Sidoti, Todd Cc: Loepp, Victoria T (DOA); Wallace, Chris D (DOA) Subject: RE: PBU S -200A (PTD #217-125) Hydraulic Fracturing Application (Sundry #317-491) - Questions and Requests Forwarded to pertinent parties, will be back to you shortly, How is L -205a coming along? David Wages BP I AK I Completion Engineer 900 E. Benson Blvd 1744c I Anchorage, AK 99515 Direct: +1.907.564.5669 1 Mobile: +1.713.380.9836 From: Davies, Stephen F (DOA) [ mai Ito: steve, davies@alaska.gov] Sent: Thursday, February 15, 2018 11:14 AM To: Sidoti, Todd Cc: Wages, David; Loepp, Victoria T (DOA); Wallace, Chris D (DOA) Subject: PBU S -200A (PTD #217-125) Hydraulic Fracturing Application (Sundry #317-491) - Questions and Requests Todd, The application to hydraulically fracture PBU S -200A (Sundry #317-491) was received by the AOGCC on October 16, 2017, before BP spudded the well on October 29, 2017. BP completed PBU S -200A on December 26, 2017, and the Well Completion or Recompletion Report and Log (Well Completion Report; AOGCC Form 10-407) for the well was received by the AOGCC on January 12, 2018. Two perforation intervals are displayed on the wellbore schematic drawing that accompanies the Well Completion Report. They are from 15,535' to 15,567' measured depth (MD) and from 15,554 to 15,587' MD. In addition to the information requested in separate emails, below, to support BP's application to hydraulically fracture PBU S -200A, please: Provide updated footages for all anticipated fracturing intervals within PBU S -200A. 1. How confident is BP in the location of the proposed fracturing perforations? 2. What are the dimensions of the 2D ellipse of uncertainty in the directional survey data at this depth? Provide an updated version of the structure map (plat) that reflects the drilling results for PBU S -200A and identifies all wells and faults within one-half mile of the fracturing interval(s). 3. Regarding this updated structure map: • What is the spacing of the 3D seismic lines (bin size) used to map this area? • How confident is BP in the location of fault #1 with respect to the PBU S -200A wellbore? Please provide an estimate of possible position error for this fault (uncertainty ellipse dimensions). • From seismic mapping, what is the vertical displacement of the fault #1 at the point it appears to cross the PBU S -200A well path? • Which formations are affected by fault #1? (That is, provide the shallowest affected formation and the deepest affected formation.) Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Thursday, February 15, 2018 11:14 AM To: 'Sidoti, Todd' Cc: david.wages@bp.com; Loepp, Victoria T (DOA); Wallace, Chris D (DOA) Subject: PBU S -200A (PTD #217-125) Hydraulic Fracturing Application (Sundry #317-491) - Questions and Requests Todd, The application to hydraulically fracture PBU S -200A (Sundry #317-491) was received by the AOGCC on October 16, 2017, before BP spudded the well on October 29, 2017. BP completed PBU S -200A on December 26, 2017, and the Well Completion or Recompletion Report and Log (Well Completion Report; AOGCC Form 10-407) for the well was received by the AOGCC on January 12, 2018. Two perforation intervals are displayed on the wellbore schematic drawing that accompanies the Well Completion Report. They are from 15,535' to 15,567' measured depth (MD) and from 15,554 to 15,587' MD. In addition to the information requested in separate emails, below, to support BP's application to hydraulically fracture PBU S -200A, please: Provide updated footages for all anticipated fracturing intervals within PBU S -200A. 1. How confident is BP in the location of the proposed fracturing perforations? 2. What are the dimensions of the 2D ellipse of uncertainty in the directional survey data at this depth? Provide an updated version of the structure map (plat) that reflects the drilling results for PBU S -200A and identifies all wells and faults within one-half mile of the fracturing interval(s). 3. Regarding this updated structure map: • What is the spacing of the 3D seismic lines (bin size) used to map this area? • How confident is BP in the location of fault #1 with respect to the PBU S -200A wellbore? Please provide an estimate of possible position error for this fault (uncertainty ellipse dimensions). • From seismic mapping, what is the vertical displacement of the fault #1 at the point it appears to cross the PBU S -200A well path? • Which formations are affected by fault #1? (That is, provide the shallowest affected formation and the deepest affected formation.) • The structure contours that lie between S-107 and fault #1 suggest a localized depression and rapidly changing vertical displacement along fault #1 near the point where fault #1 appears to cross PBU S - 200A. How confident is BP in the accuracy of the contours in this area? 4. Did the PBU S -200A wellbore intersect fault #1? If so: • At what measured depth? • What is the vertical displacement of the fault based on well log correlations? • Did the wellbore loose or gain fluid as the fault plane was drilled? If so, how much? • Did cement for the 7" casing string cover the fault? If so: o What is the quality/coverage of the cement across fault #1 as determined by a cement evaluation log? , o From the cement evaluation log, what is the measured depth of the top of "good" quality cement for the 7" casing string? • Were the results of the FIT conducted just below the 7" casing shoe similar to the results from FITS conducted at similar true vertical depths in the S -Pad area? Does BP expect fault #1 to present a risk to fluid migration during fracturing operations? If so, what mitigation measures will be implemented? Did the drilling results for PBU S -200A change any aspect of BP's fracture stimulation computer model or BP's planned fracture stimulation operations program as described in Sundry #317-491? If so, please update that sundry application accordingly. What is the estimated date for commencing fracturing operations in PBU S -200A? Note that for clarity of the public record, each sundry application to must be complete. In other words, information submitted in support of one sundry application cannot be presumed to "carry over" to subsequent sundry applications. Thank you for your help, 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.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Tuesday, February 13, 2018 10:04 AM To:'Sidoti, Todd' <Todd.Sidoti@bp.com> Subject: RE: PBU S-129 (PTD #210-132) Hydraulic Fracturing Application (Sundry #318-044) - Questions Todd, Perfect timing. I literally just reviewed PBU S -200a and S-129 on my Task List to see what information was still lacking. Thank you for the information for S-129. Per the email from David Wages on 2/12, BP's priorities are: 1. P1-20 2. L -205a 3. S -200a (I will resubmit this one today using the new template) 4. S-129 S -200a is next on my list. According to my Task List, for S -200a I still need information requested in my email to David Wages dated 11/28/2017 (below) and Area -of -Review maps similar to those in recent L -205a application. Please let me know if my priorities are not correct. Thank you, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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.davies@alaska.gov. • • ------------- From: Davies, Stephen F (DOA) Sent: Tuesday, November 28, 2017 11:46 AM To:'Wages, David' <David.Wages@bp.com> Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) David, That's great to hear. In addition to my requests, below, could BP also please provide an updated wellbore schematic drawing that includes perfs, packer(s), frac sleeves, and BP's determination for the top of cement? Also, this morning while again reading through BP's Sundry Application for fracturing operations in PBU S -200A, I realized that I had overlooked the fact that the Area of Review for PBU S -200A encompasses all of PBU S-200A—from TD to ground surface—and not just the portion of the well that is open to the Kuparuk formation as shown on BP's plat that accompanies the application. (See my email to you regarding BP's Sundry Application to fracture the PBU S-113BL1 lateral wellbore, dated Tue 10/18/2016 9:12 AM.) So, please accept my apologies for this oversight and please submit the following information that is required under 20 AAC 25.283 but was not provided in BP's Sundry Application for fracturing operations within PBU S-20OA: Regulation Deficient Information 20 AAC 25.283(a)(2)(C) Since PBU S -200A is open to the ground surface, the one-half mile radius Area of Review 20 AAC 25.283(a)(10) (AOR) encompasses PBU S -200A from TD to ground surface. For that AOR: 20 AAC 25.283(a)(11) 20 AAC 25.283(a)(2)(C) — identify each well penetration within one-half mile of any portion of PBU S -200A from TD to the ground surface; 20 AAC 25.283(a)(10) -provide the location, the orientation, and a report on the mechanical condition of each well within that AOR that transects the confining zones, and information sufficient to support a determination that the well will not interfere with containment of the hydraulic fracturing fluid; and 20 AAC 25.283(a)(11) — provide the location of, orientation of, and geological data for each known or suspected fault or fracture that may transect the confining zones within that AOR, and information sufficient to support a determination that the known or suspected fault or fracture will not interfere with containment of the hydraulic fracturing fluid. Regards, Steve Davies Alaska Oil and Gas Conservation Commission (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.davies@alaska.gov. i ;2 t7- l2-5- Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Tuesday, February 13, 2018 10:04 AM To: 'Sidoti, Todd' Subject: RE: PBU S-129 (PTD #210-132) Hydraulic Fracturing Application (Sundry #318-044) - Questions Todd, Perfect timing. I literally just reviewed PBU S -200a and S-129 on my Task List to see what information was still lacking. Thank you for the information for S-129. Per the email from David Wages on 2/12, BP's priorities are: 1. P1-20 2. L -205a 3. S -200a (I will resubmit this one today using the new template) 4. S-129 S -200a is next on my list. According to my Task List, for S -200a I still need information requested in my email to David Wages dated 11/28/2017 (below) and Area -of -Review maps similar to those in recent L -205a application. Please let me know if my priorities are not correct. Thank you, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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.davies@alaska.sov. From: Davies, Stephen F (DOA) Sent: Tuesday, November 28, 2017 11:46 AM To:'Wages, David' <David.Wages@bp. com> Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) David, That's great to hear. In addition to my requests, below, could BP also please provide an updated wellbore schematic drawing that includes perfs, packer(s), frac sleeves, and BP's determination for the top of cement? Also, this morning while again reading through BP's Sundry Application for fracturing operations in PBU S -200A, I realized that I had overlooked the fact that the Area of Review for PBU S -200A encompasses all of PBU S-200A—from TD to ground surface—and not just the portion of the well that is open to the Kuparuk formation as shown on BP's plat that accompanies the application. (See my email to you regarding BP's Sundry Application to fracture the PBU S-11361_1 lateral wellbore, dated Tue 10/18/20169:12 AM.) So, please accept my apologies for this oversight and please submit Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Thursday, February 8, 2018 5:18 PM To: 'Sidoti, Todd' Subject: BP's Hydraulic Fracturing Applications for PBU 5-129, P1-20, L -205A, 5-200A, and 5-109 - Information Needed Thank you Todd. For BP's five Hydraulic Fracturing Applications under review, I need: 1. 5-129 (PTD #210-132; Sundry # 318-044): Answers to questions and requests emailed to you on 2/7/2018. P1-20 (PTD #192-094; Sundry # 317-548): Fault information requested in my email to David Wages dated 12/19/2017; Area -of -Review maps similar to those in recent PBU L -205A application. When I spoke with Carl on the phone on 1/29, he said that BP would provide the info in the next day or two. 3. L -205A (PTD #217-118; Sundry # 318-020):1 have all of the information that I need for L -205A. 4. 5-200A (PTD #217-125; Sundry #317-491): Information requested in my email to David Wages dated 11/28/2017; Area -of -Review maps similar to those in recent PBU L -205A application. 5. S-109 (PTD #202-245; Sundry #316-444): A revised application per my most recent email exchange with David Wages regarding S-109 (dated 1/14/17) that is attached below. Thanks for your help, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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.davies@alaska.go . From: Wages, David (mailto:David.Wages@bp.com] Sent: Wednesday, June 14, 2017 11:30 AM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Cc: Carlisle, Samantha J (DOA) <samantha.carlisle@alaska.gov> Subject: RE: PBU S-109 (PTD #202-245, Sundry #316-444) - Application to Fracture Stimulate - Request for Additional Information Nope, we are looking to get that one back up and runner here in a bit. We've had quite a few issues with our deployment system as you may be aware and feel we've finally gotten things ironed out. I will go over it and submit an application per our most recent approved frac sundry (L -200a). From: Davies, Stephen F (DOA)[mailto:steve.daviesCcbalaska.gov] Sent: Wednesday, June 14, 2017 10:59 AM To: Wages, David Cc: Carlisle, Samantha J (DOA) Subject: RE: PBU S-109 (PTD #202-245, Sundry #316-444) - Application to Fracture Stimulate - Request for Additional Information 0 Davies, Stephen F (DOA) From: Wages, David <David.Wages@bp.com> Sent: Monday, January 8, 2018 10:57 AM To: Davies, Stephen F (DOA) Subject: FW: PBU S -200A (PTD 217-125; Sundry 317-491) Attachments: QC Passed for BP Well: S -200A with Log Type: On_LithoTrak and Log Date: 11/22/2017; FW: QC Passed for BP Well: S -200A with Log Type: USIT-MSIP-GPIT and Log Date: 11/17/2017 Steve, our guys say they have passed on the logs for this well, please advise if this is not the case. David Wages BP I AK I Completion Engineer 900 E. Benson Blvd 1744c I Anchorage, AK 99515 Direct: +1.907.564.5669 1 Mobile: +1.713.380.9836 From: Itter, David Sent: Monday, January 08, 2018 8:26 AM To: Lastufka, Joseph N; Cedillo, Gerardo; Kendall, Merion (Wipro); Douglas, David (Wipro Technologies) Cc: Gorham, Bradley M; Wages, David Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) HI Joe / David, The open hole logs were passed for distribution by the vendor to the DNR/AOGCC on 20 -Dec -2017. The cement evaluation of the 7in cement job was passed for distribution on 28 -Dec -2017 following revisions. Mer / David, Have we received transmittals from Baker / SLB for the attached jobs? Thanks, Dave From: Lastufka, Joseph N Sent: Thursday, December 28, 2017 2:57 PM To: Itter, David <David.ltter@bp.com>; Cedillo, Gerardo <coubec@BP.com> Cc: Gorham, Bradley M <Bradley.Gorham@bp.com> Subject: FW: PBU S -200A (PTD 217-125; Sundry 317-491) Hello, Do either of you know if the log data has been sent to the state? If not, do you happen to have an ETA of when it will be ready? If you aren't the correct contact, please let me know who to forward the request to. Thank you, • Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 BP Exploration Alaska1900 E. Benson Blvd.lRoom: 788DIAnchorage, AK ----------------------------------------------------------------------------------------------- From: Gorham, Bradley M Sent: Thursday, December 28, 2017 2:49 PM To: Lastufka, Joseph N <Joseph.Lastufka @bp.com> Subject: FW: PBU 5-200A (PTD 217-125; Sundry 317-491) Wages, Joe is normally who sends the logs to the state. I spoke with him and he hadn't yet received the logs. Joe, FYI. Let me know if you need me to help you track these down. Thanks, Brad From: Wages, David Sent: Thursday, December 28, 2017 2:35 PM To: Gorham, Bradley M <Bradley.Gorham@bp.com> Subject: FW: PBU S -200A (PTD 217-125;'Sundry 317-491) Hey Brad, do you know who sends the state the logs for the well? David Wages BP I AK I Completion Engineer 900 E. Benson Blvd 1744c I Anchorage, AK 99515 Direct: +1.907.564.5669 1 Mobile: +1.713.380.9836 From: Davies, Stephen F (DOA)[mailto:steve.davies(aaalaska.gov] Sent: Thursday, December 28, 2017 2:33 PM To: Wages, David Cc: Loepp, Victoria T (DOA); Wallace, Chris D (DOA) Subject: FW: PBU S -200A (PTD 217-125; Sundry 317-491) David, A reminder about the digital open -hole well log and directional data for PBU 5-200A that I haven't received yet. If BP has sent it, please let me know. 2 Thanks, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Monday, December 18, 2017 2:40 PM To: david.wages@bp.com Subject: FW: PBU S -200A (PTD 217-125; Sundry 317-491) David, No, I haven't received any digital open -hole well log and directional survey data for the PBU S -200A well. I checked with our Natural Resources Tech, and she hasn't received anything either. Thanks, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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.davies@alaska.gov. From: Wages, David [mailto:David.Wages@bp.com] Sent: Thursday, December 14, 2017 10:44 AM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) Did you get the log data for S -200a? the drillers should have sent it. If you haven't, I can track it down for you. David Wages BP I AK I Completion Engineer 900 E. Benson Blvd 1744c I Anchorage, AK 99515 Direct: +1.907.564.5669 1 Mobile: +1.713.380.9836 From:. Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Tuesday, November 28, 2017 12:56 PM To: Wages, David Cc: Loepp, Victoria T (DOA) Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) David, • Could BP please also provide digital open -hole well log and directional survey data for the PBU S -200A well? (Field -run well log data in LAS or ASCII format are fine. The most recent directional survey data in spreadsheet or ASCII format are appreciated.) Regards, Steve Davies Alaska Oil and Gas Conservation Commission (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.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Tuesday, November 28, 2017 11:46 AM To:'Wages, David' <David.Wages@bp.com> Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) David, That's great to hear. In addition to my requests, below, could BP also please provide an updated wellbore schematic drawing that includes perfs, packer(s), frac sleeves, and BP's determination for the top of cement? Also, this morning while again reading through BP's Sundry Application for fracturing operations in PBU S -200A, I realized that I had overlooked the fact that the Area of Review for PBU S -200A encompasses all of PBU S-200A—from TD to ground surface—and not just the portion of the well that is open to the Kuparuk formation as shown on BP's plat that accompanies the application. (See my email to you regarding BP's Sundry Application to fracture the PBU S-11361-1 lateral wellbore, dated Tue 10/18/2016 9:12 AM.) So, please accept my apologies for this oversight and please submit the following information that is required under 20 AAC 25.283 but was not provided in BP's Sundry Application for fracturing operations within PBU S-20OA: Regulation Deficient Information 20 AAC 25.283(a)(2)(C) Since PBU S -200A is open to the ground surface, the one-half mile radius Area of Review 20 AAC 25.283(a)(10) (AOR) encompasses PBU S -200A from TD to ground surface. For that AOR: 20 AAC 25.283(a)(11) 20 AAC 25.283(a)(2)(C) — identify each well penetration within one-half mile of any portion of PBU S -200A from TD to the ground surface; 20 AAC 25.283(a)(10) — provide the location, the orientation, and a report on the mechanical condition of each well within that AOR that transects the confining zones, and information sufficient to support a determination that the well will not interfere with containment of the hydraulic fracturing fluid; and 20 AAC 25.283(a)(11) — provide the location of, orientation of, and geological data for each known or suspected fault or fracture that may transect the confining zones within that AOR, and information sufficient to support a determination that the known or suspected fault or fracture will not interfere with containment of the hydraulic fracturing fluid. Regards, Steve Davies Alaska Oil and Gas Conservation Commission (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 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Tuesday, November 28, 2017 11:46 AM To: 'Wages, David' Cc: Loepp, Victoria T (DOA) Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) David, That's great to hear. In addition to my requests, below, could BP also please provide an updated wellbore schematic drawing that includes perfs, packer(s), frac sleeves, and BP's determination for the top of cement? Also, this morning while again reading through BP's Sundry Application for fracturing operations in PBU S -200A, I realized that I had overlooked the fact that the Area of Review for PBU S -200A encompasses all of PBU S-200A—from TD to ground surface—and not just the portion of the well that is open to the Kuparuk formation as shown on BP's plat that accompanies the application. (See my email to you regarding BP's Sundry Application to fracture the PBU S-113BL1 lateral wellbore, dated Tue 10/18/20169:12 AM.) So, please accept my apologies for this oversight and please submit the following information that is required under 20 AAC 25.283 but was not provided in BP's Sundry Application for fracturing operations within PBU S-20OA: Regulation Deficient Information 20 AAC 25.283(a)(2)(C) Since PBU S -200A is open to the ground surface, the one-half mile radius Area of Review 20 AAC 25.283(a)(10) (AOR) encompasses PBU S -200A from TD to ground surface. For that AOR: 20 AAC 25.283(a)(11) 20 AAC 25.283(a)(2)(C) — identify each well penetration within one-half mile of any portion of PBU S -200A from TD to the ground surface; 20 AAC 25.283(a)(10) — provide the location, the orientation, and a report on the mechanical condition of each well within that AOR that transects the confining zones, and information sufficient to support a determination that the well will not interfere with containment of the hydraulic fracturing fluid; and 20 AAC 25.283(a)(11) — provide the location of, orientation of, and geological data for each known or suspected fault or fracture that may transect the confining zones within that AOR, and information sufficient to support a determination that the known or suspected fault or fracture will not interfere with containment of the hydraulic fracturing fluid. Regards, Steve Davies Alaska Oil and Gas Conservation Commission (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.davies@alaska.gov. From: Wages, David [mailto:David.Wages@bp.com] Sent: Tuesday, November 28, 2017 11:19 AM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) Davies, Stephen F (DOA) From: Wages, David <David.Wages@bp.com> Sent: Tuesday, November 28, 2017 11:19 AM To: Davies, Stephen F (DOA) Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) Steve, Got our logs back, our original plans will be modified, will submit supplemental information as soon as final decisions are made. We have made a couple changes but for the most part, things are going as planned. David Wages BP I AK I Completion Engineer 900 E. Benson Blvd 1744c I Anchorage, AK 99515 Direct: +1.907.564.5669 1 Mobile: +1.713.380.9836 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Tuesday, November 28, 2017 10:30 AM To: Wages, David Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) David, I'm finishing my review of the Sundry Application for fracturing operations in PBU S -200A. I don't believe that I received answers from BP regarding my requests and questions that are highlighted with yellow in the emails below. Thanks, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 CONFIDENTIALITYNOTICE: 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.davies@alaska.sov. From: Davies, Stephen F (DOA) Sent: Friday, October 27, 2017 9:05 AM To:'Wages, David' <David.Wages@bp. com> Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) David, Thanks for your help. For clarity of the public record and to ensure that a standardized review process is followed for every application, each application must stand alone, which is the reason behind any repetitive questions. If that information isn't provided in each application, I'll keep requesting it. Thanks again, Steve Davies 0 i Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Tuesday, November 28, 2017 10:30 AM To: 'Wages, David' Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) David, I'm finishing my review of the Sundry Application for fracturing operations in PBU S -200A. I don't believe that I received answers from BP regarding my requests and questions that are highlighted with yellow in the emails below. Thanks, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Friday, October 27, 2017 9:05 AM To:'Wages, David' <David.Wages@bp.com> Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) David, Thanks for your help. For clarity of the public record and to ensure that a standardized review process is followed for every application, each application must stand alone, which is the reason behind any repetitive questions. If that information isn't provided in each application, I'll keep requesting it. Thanks again, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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.davies@alaska.gov. From: Wages, David [mailto:David.Wages@bp.com] Sent: Wednesday, October 25, 2017 11:48 AM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Cc: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov>; Wallace, Chris D (DOA) <chris.wallace@alaska.gov>; Sidoti, Todd <Todd.Sidoti@bp.com> Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) Steve, To answer your initial question: with top of Kuparuk at -6738' TVDss, our geologist estimates, based on offsets, that the top of the Miluveach is 430' below this at 7168'. Having said that, our frac modelling software does not predict height growth to get to even half that distance. I can immediately address some of the questions below and will forward to appropriate channels for further clarification: 5-200a is an openhole completion, thus the location of the fracture initiation point is very much an estimate. We do know that the top sandstone layers of Kuparuk, based on neighboring sonic data by which closure stress can be obtained, typically have the lowest closure stress. In conjunction with this, there is a certain degree of jetting action that takes place when pumping through a frac sleeve at frac rates. This, I believe, help to initiate the frac near the frac sleeve. Therefore, when we place a sleeve on the cross-section/WBD, it is placed at a point that 1) optimizes reserve recovery and 2) at a place where we think the frac will initiate. The exact position is to be modified upon drilling of the well and the logs are obtained. Our driller are looking into the ellipse for us. To my knowledge, we have not done active measuring of the induced fracture length. I myself have done plenty of post job pressure matching to the extent that I can say that 250' if very likely the max half length of the induced frac if it were a planer frac. The more I work in the Kuparuk, the more I am coming to the conclusion that the induced fracture are more complex than what a planer fracture model would estimate. A more complex induced structure also (probably) means and even shorter induced frac half-length. Question forwarded on to our seismic people 4. 1 believe I've addressed this question before but I will happily address it again. When drilling, we occasionally get at an X -Y caliper which can highlight borehole breakout. Depending on the azimuth of the wellbore upon drilling, there is a predominate trend for when borehole breakout occurs. For us, in the Kuparuk, this happens when we drill —30 deg south of west, which is indicative of the maximum stress direction. The min stress direction would then be 90 degrees (perpendicular) to the max. HAVING SAID THAT: in order to create complex fractures or non -planer fractures, you must physically change the local minimum stress direction. When you are fracing you are indeed moving rocks, compacting them which can indeed alter the local stress field. This can be compounded by the fact that, I believe, the max and minimum stress magnitudes are close together so it is relatively easy to alter the local field. Take Eaton's equation which predicts closure pressure: Pc=K(Pob- Pres)+Pres +tectonics where: a. Pc is closure pressure b. K, an effective stress ration, usually close to 1/3 c. Pob is overburden pressure, usually 1 psi/ft d. Pres is reservoir pressure e. And tectonics thrown in there at the last The tectonics of the region are what determines the direction of the max/min stress in that equation. When I look at the slope from a USGS earthquake history perspective, it really isn't all that geologically active. It's not near a large subduction or divergent plate boundary to my knowledge, while the sub -structure looks like shattered glass, those faulting events happened during a period of high regional plate stress/movements. in the end, 30 deg west of north is the ultimate answer... Will try and get a prompt answer back to you for your remaining inquiries. Thanks, David Wages BP I AK I Completion Engineer 900 E. Benson Blvd 1744c I Anchorage, AK 99515 Direct: +1.907.564.5669 1 Mobile: +1.713.380.9836 • 0 From: Davies, Stephen F (DOA)[mailto:steve.daviesalaska.aov] Sent: Wednesday, October 25, 2017 10:14 AM To: Wages, David Cc: Schwartz, Guy L (DOA); Wallace, Chris D (DOA) Subject: FW: PBU S -200A (PTD 217-125; Sundry 317-491) David, I have a couple of additional questions due to the very close proximity of the eastern -most proposed fracturing perforations in PBU S -200A to fault #1. These perforations are expected to be only about 150' away from the maximum fracture length predicted by computer modeling. 1. How confident is BP in the location of the proposed fracturing perforations? What are the dimensions of the 2D ellipse of uncertainty in the directional survey data at this depth? 2. How confident is BP that the maximum length of the induced fracture will be 250'? Has BP ever conducted a post -audit or monitoring survey to see if modeled fracture lengths are close to the actual length of induced fractures? If so, how closely do modeled fracture lengths agree with actual fracture lengths? 3. How confident is BP in the location of fault #1? Was it mapped using 3D seismic data? What is the spacing of the lines (bin size) in this area? Can you provide an estimate of possible position error for this fault (uncertainty ellipse dimensions)? 4. 1 see two predominant trends in the faults on BP's map for PBU S -200A, north and northwest. What is the basis for BP's belief that the induced fractures will trend about 30 degrees west of north in this area? Thanks, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Tuesday, October 24, 2017 5:44 PM To: david.wages@bp.com Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) David, The Miluveach Shale will serve as lower confinement for the Kuparuk Formation. Could BP please provide the estimated frac gradient value for the Miluveach Shale that was used for computer simulation of the proposed fracturing operations? Thanks, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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.davies@alaska.gov. 0 From: Davies, Stephen F (DOA) Sent: Tuesday, October 24, 2017 3:28 PM To:'Wages, David' <David.Wages@bp.com> Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) David, 0 No, we need the well log and final directional survey data to confirm locations, depths, hydrocarbon -bearing intervals, confining intervals, and the absence of faults. But with most of the other review done up front, we can get this application before the Commissioners shortly after receiving the well log data. I'll let you know if I have any questions or need any other additional information. Thanks, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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.davies@alaska.gov. From: Wages, David [mailto:David.Wages@bp.com] Sent: Tuesday, October 24, 2017 1:40 PM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) Steve, Thanks for the note, we are presently getting ready to move over to S -200a. In regards to this, we would like to get on the well as soon as the rig leaves, I know you've been in this position before, is there any chance we can get approval before you guys get the logs? David wages BP I AK I Completion Engineer 900 E. Benson Blvd 1744c I Anchorage, AK 99515 Direct: +1.907.564.5669 1 Mobile: +1.713.380.9836 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.clov] Sent: Tuesday, October 24, 2017 11:22 AM To: Wages, David Subject: PBU S -200A (PTD 217-125; Sundry 317-491) David, I'm reviewing the Sundry Application to fracture stimulate PBU S -200A. Could you please tell me the current status of the well? Has it been drilled? If so, could you please provide digital well log data for the field logging runs (gamma ray, resistivity, porosity) for this well? If not, when do you anticipate digital well log data will be available for the well? 0 0 Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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.davies@alaska.gov. i Davies, Stephen F (DOA) • From: Gorham, Bradley M <Bradley.Gorham@bp.com> Sent: Tuesday, November 14, 2017 12:30 PM To: Loepp, Victoria T (DOA); Wages, David Cc: Davies, Stephen F (DOA); Schwartz, Guy L (DOA) Subject: RE: S-200A(PTD 217-125) Completion Victoria, The base plan will be to cement the 4-1/2" production liner. David was working with the subsurface team to assess the possibility of running a cementless completion. Since then the subsurface team has determined that the cemented liner would be their optimal completion. Sorry for any confusion this may have caused. Our base plan has not changed. We will attempt to drill the entire production interval with the rotary rig. If we encounter any issues in the preliminary stages of drilling we are going to opt to top set the Kuparuk formation with our 4-1/2" production liner and allow our Coil Tubing Drilling Group to come in and finish the well. They will obviously need to submit the proper paperwork if we do in fact go that route and they are aware of that. At this point in time, the proposed schematic has not changed from what I previously sent you other than the casing set depth is now 14,148' MD. Feel free to give me a call if you have any further questions. Thanks, Brad Brad Gorham BP Exploration (Alaska), Inc. Drilling Engineer W: (907)564-4649 C: (907)223-9529 Bradley.Gorham@bp.com From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, November 14, 2017 8:40 AM To: Wages, David <David.Wages@bp.com>; Gorham, Bradley M <Bradley.Gorham@bp.com> Cc: Davies, Stephen F (DOA) <steve.davies@alaska.gov>; Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Subject: FW: S-200A(PTD 217-125) Completion David & Brad, Please get in touch with Brad Gorham. The completion planned for now is a cemented production liner, correct Brad? Please send updated planned schematic. Thanx, Victoria From: Davies, Stephen F (DOA) Sent: Monday, November 13, 2017 3:48 PM 0 0 To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: FW: S -200a question Hi Victoria, Since you were out on flex day, Guy and I called David about this. Details are still sketchy, but BP had to set the 7" casing shallower than expected. David will send a schematic drawing of the current well configuration with depths, the frac gradient of the formation(s) above the HRZ, and more detail as to what they are proposing. A 403 seems appropriate to me. Thanks, Steve D 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.davies@alaska.gov. From: Wages, David [mailto:David.Wages@bp.com] Sent: Monday, November 13, 2017 3:10 PM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: S -200a question Steve, Do we need cement across the confining shale of our production interval in order to frac S -200a? In talking to the drillers, it doesn't sound like we need cement at the shale. That the requirement says we need cement between two distinct permeable zones, where we put it is up to us. If your guy's understanding is different when we intend to frac, please advise, as we are on the well now. David Wages BP I AK I Completion Engineer 900 E. Benson Blvd 1744c I Anchorage, AK 99515 Direct: i 1..907.564,5669 1 Mobile: 1.713.380.9836 Davies, Stephen F (DOA) From: Wages, David <David.Wages@bp.com> Sent: Wednesday, October 25, 2017 11:48 AM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L (DOA); Wallace, Chris D (DOA); Sidoti, Todd Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) Steve, To answer your initial question: with top of Kuparuk at -6738' TVDss, our geologist estimates, based on offsets, that the top of the Miluveach is 430' below this at 7168'. Having said that, our frac modelling software does not predict height growth to get to even half that distance. I can immediately address some of the questions below and will forward to appropriate channels for further clarification: 1. S -200a is an openhole completion, thus the location of the fracture initiation point is very much an estimate. We do know that the top sandstone layers of Kuparuk, based on neighboring sonic data by which closure stress can be obtained, typically have the lowest closure stress. In conjunction with this, there is a certain degree of jetting action that takes place when pumping through a frac sleeve at frac rates. This, I believe, help to initiate the frac near the frac sleeve. Therefore, when we place a sleeve on the cross-section/WBD, it is placed at a point that 1) optimizes reserve recovery and 2) at a place where we think the frac will initiate. The exact position is to be modified upon drilling of the well and the logs are obtained. Our driller are looking into the ellipse for us. 2. To my knowledge, we have not done active measuring of the induced fracture length. I myself have done plenty of post job pressure matching to the extent that I can say that 250' if very likely the max half length of the induced frac if it were a planer frac. The more I work in the Kuparuk, the more I am coming to the conclusion that the induced fracture are more complex than what a planer fracture model would estimate. A more complex induced structure also (probably) means and even shorter induced frac half-length. 3. Question forwarded on to our seismic people 4. 1 believe I've addressed this question before but I will happily address it again. When drilling, we occasionally get at an X -Y caliper which can highlight borehole breakout. Depending on the azimuth of the wellbore upon drilling, there is a predominate trend for when borehole breakout occurs. For us, in the Kuparuk, this happens when we drill —30 deg south of west, which is indicative of the maximum stress direction. The min stress direction would then be 90 degrees (perpendicular) to the max. HAVING SAID THAT: in order to create complex fractures or non -planer fractures, you must physically change the local minimum stress direction. When you are fracing you are indeed moving rocks, compacting them which can indeed alter the local stress field. This can be compounded by the fact that, I believe, the max and minimum stress magnitudes are close together so it is relatively easy to alter the local field. Take Eaton's equation which predicts closure pressure: Pc=K(Pob- Pres)+Pres +tectonics where: a. Pc is closure pressure b. K, an effective stress ration, usually close to 1/3 c. Pob is overburden pressure, usually 1 psi/ft d. Pres is reservoir pressure e. And tectonics thrown in there at the last The tectonics of the region are what determines the direction of the max/min stress in that equation. When I look at the slope from a USGS earthquake history perspective, it really isn't all that geologically active. It's not near a large subduction or divergent plate boundary to my knowledge, while the sub -structure looks like shattered glass, those faulting events happened during a period of high regional plate stress/movements. in the end, 30 deg west of north is the ultimate answer... 0 • Will try and get a prompt answer back to you for your remaining inquiries. Thanks, David wages BP I AK I Cornpletion Engine.er 900 E. Benson Blvd 1744c. I Anchorage, AK 9951.5 Direct: +1.907.564.5669 1 Mobile: +1.713.3801.9836 From: Davies, Stephen F (DOA)[mailto:steve.davies@alaska.gov] Sent: Wednesday, October 25, 2017 10:14 AM To: Wages, David Cc: Schwartz, Guy L (DOA); Wallace, Chris D (DOA) Subject: FW: PBU S -200A (PTD 217-125; Sundry 317-491) David, I have a couple of additional questions due to the very close proximity of the eastern -most proposed fracturing perforations in PBU S -200A to fault #1. These perforations are expected to be only about 150' away from the maximum fracture length predicted by computer modeling. 1. How confident is BP in the location of the proposed fracturing perforations? What are the dimensions of the 2D ellipse of uncertainty in the directional survey data at this depth? 2. How confident is BP that the maximum length of the induced fracture will be 250'? Has BP ever conducted a post -audit or monitoring survey to see if modeled fracture lengths are close to the actual length of induced fractures? If so, how closely do modeled fracture lengths agree with actual fracture lengths? 3. How confident is BP in the location of fault #1? Was it mapped using 3D seismic data? What is the spacing of the lines (bin size) in this area? Can you provide an estimate of possible position error for this fault (uncertainty ellipse dimensions)? 4. 1 see two predominant trends in the faults on BP's map for PBU S -200A, north and northwest. What is the basis for BP's belief that the induced fractures will trend about 30 degrees west of north in this area? Thanks, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Tuesday, October 24, 2017 5:44 PM To: david.wages@bp.com Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) David, The Miluveach Shale will serve as lower confinement for the Kuparuk Formation. Could BP please provide the estimated frac gradient value for the Miluveach Shale that was used for computer simulation of the proposed fracturing operations? Thanks, Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Wednesday, October 25, 2017 10:14 AM To: david.wages@bp.com Cc: Schwartz, Guy L (DOA); Wallace, Chris D (DOA) Subject: FW: PBU S -200A (PTD 217-125; Sundry 317-491) David, I have a couple of additional questions due to the very close proximity of the eastern -most proposed fracturing perforations in PBU S -200A to fault #1. These perforations are expected to be only about 150' away from the maximum fracture length predicted by computer modeling. 1. How confident is BP in the location of the proposed fracturing perforations? What are the dimensions of the 2D ellipse of uncertainty in the directional survey data at this depth? 2. How confident is BP that the maximum length of the induced fracture will be 250'? Has BP ever conducted a post -audit or monitoring survey to see if modeled fracture lengths are close to the actual length of induced fractures? If so, how closely do modeled fracture lengths agree with actual fracture lengths? 3. How confident is BP in the location of fault #1? Was it mapped using 3D seismic data? What is the spacing of the lines (bin size) in this area? Can you provide an estimate of possible position error for this fault (uncertainty ellipse dimensions)? 4. 1 see two predominant trends in the faults on BP's map for PBU S -200A, north and northwest. What is the basis for BP's belief that the induced fractures will trend about 30 degrees west of north in this area? Thanks, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Tuesday, October 24, 2017 5:44 PM To: david.wages@bp.com Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) David, The Miluveach Shale will serve as lower confinement for the Kuparuk Formation. Could BP please provide the estimated frac gradient value for the Miluveach Shale that was used for computer simulation of the proposed fracturing operations? Thanks, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Tuesday, October 24, 2017 3:28 PM To:'Wages, David' <David.Wages@bp.com> Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) David, No, we need the well log and final directional survey data to confirm locations, depths, hydrocarbon -bearing intervals, confining intervals, and the absence of faults. But with most of the other review done up front, we can get this application before the Commissioners shortly after receiving the well log data. I'll let you know if I have any questions or need any other additional information. Thanks, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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.davies@alaska.gov. From: Wages, David [mailto:David.Wages@bp.com] Sent: Tuesday, October 24, 2017 1:40 PM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) Steve, Thanks for the note, we are presently getting ready to move over to S -200a. In regards to this, we would like to get on the well as soon as the rig leaves, I know you've been in this position before, is there any chance we can get approval before you guys get the logs? David Wages BP I AK I Completion Engineer 900 E. Benson Blvd 1744c I Anchorage, AK 99515 Direct: +1.907.564.5669 1 Mobile: +1.713.380.9836 From: Davies, Stephen F (DOA)[ma iIto: steve.davies@alaska.gov) Sent: Tuesday, October 24, 2017 11:22 AM To: Wages, David Subject: PBU S -200A (PTD 217-125; Sundry 317-491) David, 0 0 I'm reviewing the Sundry Application to fracture stimulate PBU S -200A. Could you please tell me the current status of the well? Has it been drilled? If so, could you please provide digital well log data for the field logging runs (gamma ray, resistivity, porosity) for this well? If not, when do you anticipate digital well log data will be available for the well? Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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.davies@alaska.sov. 0 Loepp, Victoria T (DOA) 0 From: Gorham, Bradley M <Bradley.Gorham@bp.com> Sent: Monday, November 27, 2017 10:47 AM To: Loepp, Victoria T (DOA) Cc: Lastufka, Joseph N; Oshiro, Joleen Subject: S -200A Update - (PTD# 217-125) Attachments: S -200A ST PROPOSAL REV 12017-XX-XX.PDF Follow Up Flag: Follow up Flag Status: Flagged Victoria, Please see the attached document for the updated wellbore schematic. Also, the FIT conducted after drilling out the 7" shoe was a 12.7 ppg EMW. This value provided adequate kick tolerance as well as exceeded our planned drilling ECD's for the production hole section. The production liner was cemented, cement was circulated off the top of the liner and the liner and liner top packer achieved a passing pressure test. The rig ran the planned completion and is expecting to release later today. Please let me know if you need any other information or have any questions. Thanks, Brad Brad Gorham BP Exploration (Alaska), Inc. Drilling Engineer W: (907)564-4649 C: (907)223-9529 Bradley.Gorham@bp.com Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Saturday, November 11, 2017 1:55 PM To: Gorham, Bradley M Subject: Re: S -200A Update - PTD# 217-125 No issue with plan forward. As your plans for completion solidify, please update me. Victoria Sent from my iPhone On Nov 11, 2017, at 1:42 PM, Gorham, Bradley M <Bradley.Gorham@bp.com> wrote: Victoria, As we previously discussed on the phone, as a precautionary measure we are going to alter our planned casing point. We have currently drilled ahead to 14,150' MD in preparation for setting our 7" intermediate casing in the top of the HRZ formation. As of now our operations will consist of running and cementing our 7" casing at this depth and then conducting our TQC verification logs as originally planned. As far as completing the well there are two potential paths that we are evaluating: Plan A: To drill and complete the well with P272 rotary rig by drilling the production interval with a higher mud weight to the planned TD of 15,739' MD. Only change from the original plan would be that we will be changing the completion to cement and pert as opposed to the packer and sliding sleeve completion. I mentioned this in our previous discussions and in my previous email. Plan B: To drill the 6-1/8" hole to the top of the Kuparuk formation at 14,532' MD and run a 4-1/2" production liner. Then the coil tubing drilling team would move over the well later in the year and drill the production interval. We are still gathering information to determine the path forward but I wanted to give you an update. Please let me know immediately if you have any questions or concerns with either of our proposed paths forward or require any other additional information. Thanks, Brad Brad Gorham BP Exploration (Alaska), Inc. Drilling Engineer W: (907)564-4649 C: (907)223-9529 Bradley.Gorham@bp.com 0 10 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Tuesday, January 16, 2018 4:41 PM To: 'Wages, David' Cc: Loepp, Victoria T (DOA) Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) David, The AOGCC received the digital open -hole well log and directional data for PBU S -200A that I requested. I believe that we're still waiting on the information requested in emails sent to you by Victoria and me on December 19" and 20tH Thanks, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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.davies@alaska.gov. From: Wages, David [mailto:David.Wages@bp.com] Sent: Monday, January 8, 2018 10:57 AM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: FW: PBU S -200A (PTD 217-125; Sundry 317-491) Steve, our guys say they have passed on the logs for this well, please advise if this is not the case. David Wages BP I AK I Completion Engineer 900 E. Benson Blvd 1744c I Anchorage, AK 99515 Direct: +1.907.564.5669 1 Mobile: +1.713.380.9836 From: Itter, David Sent: Monday, January 08, 2018 8:26 AM To: Lastufka, Joseph N; Cedillo, Gerardo; Kendall, Merion (Wipro); Douglas, David (Wipro Technologies) Cc: Gorham, Bradley M; Wages, David Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) HI Joe / David, The open hole logs were passed for distribution by the vendor to the DNR/AOGCC on 20 -Dec -2017. The cement evaluation of the lin cement job was passed for distribution on 28 -Dec -2017 following revisions. Mer / David, Have we received transmittals from Baker / SLB for the attached jobs? Thanks, RECEIVE Originated: Schlumberger JAN 12 2018 PTS - PRINTCENTE!R 6411 A Street /� OGCC Anchorage, AK 99518 �•� (907)273-1700 main (907)271-4760fax Delivered to: MakanaK Bender • Natural Resources Technician 11 Alaska Oil & Gas Conservation Commission 333 W 7ti, Ave, Suite 100 Anchorage, AK 99501 28 943 TRANSMITTAL DATE TRANSMITTAL #12Jan18, 01 DATA LOGGED 1z412oi'y M K. BENDER B-06 50-029-20279-00 DXPU-00005 PRUDHOE BAY WL PPROF FINAL FIELD 7 -Nov -17 • • 1 1 Y -09A _ 50-029-20579-01 DQMD-00021 PRUDHOE BAY Memory PPROF-FSI Rev1 FINAL FIELD 10 -Nov -17 1 1 E -35B 50-029-22557-02 DQMD-00023 PRUDHOE BAY Memory SCMT Rev2 FINAL FIELD 14 -Nov -17 1 1 S -200A 50-029-22846-01 DODJ-00092 AURORA _ WL Cement Eval-USIT Revi FINAL FIELD 17 -Nov -17 1 1 Transmittal Receipt A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the X package have been verified to match the media noted above. The Print Name Signature Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this Please return via courier or sign/scan and email a copy to both Schlumberger and BP point. Alaska PTSPrintCenterPslb.com AKGDMINTERNALPLr).corr SLB Auditor STATE OF ALASKA �� ANLLASKA OIL AND GAS CONSERVATION COMMIS WELL PLETION OR RECOMPLETION REPOWND LOG EIVEn 1a. Well Status: Oil a • Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ 11WAG ❑ WDSPL ❑ No. of Completions: One Developk"R, JE 1102 ❑ �� Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., orAband.: 14. Per It Drill Number/Sundry BP Exploration (Alaska), Inc 12/26/2017 217-12A� 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 196612 Anchorage, AK 99519-6612 10/29/2017 50-029-22846-01-00 ` 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 11/22/2017 PBU S -200A Surface: 4301' FSL, 4500' FEL, Sec. 35, T12N, R12E, UM 9 Ref Elevations KB 82,32 17. Field/Pool(s): Top of Productive Interval: 551' FSL, 2388' FEL, Sec. 21, T12N, R12E, UM GL 35.17 BF 36.48 PRUDHOE BAY, AURORA OIL 10. Plug Back Depth(MD/TVD): 18. Property Designation: Total Depth: 607' FSL, 3498' FEL, Sec. 21, T12N, R12E, UM . 15599'/6845' ADL 028257. 028258 & 028256 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth (MD/TVD): 19. DNR Approval Number: Surface: x- 618930 ` y- 5980505* Zone - ASP 4 15693'/ 6832' • 83-47 TPI: x- 610368 y- 5987184 Zone - ASP 4 12. SSSV Depth (MD/TVD): 20 Thickness of Permafrost MD/TVD- Total Depth: x- 609257 y- 5987224 Zone - ASP 4 None 1900' (Approx.) 5. Directional or Inclination Survey: Yes p (attached) No ❑ 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top VYindow Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) MD/TVD: • 2734' / 2712' - 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 MWD / GR / RES, Cement Evaluation, MWD / GR / RES / DEN / NEU 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" 91.5# H-40 48' 124' 48' 124' 30" 260 sx Arctic Set (Approx.) 9-5/8" 47# L-80 48' 2734'' 48' 2712' 12-1/4" 2508 sx Cold Set, 234 sx Class'G' 7" 26# L-80 46' 14148' ' 46' 6582' 8-1/2"x9-7/8" 1544 sx Arctic Set, 160 sx Class'G' 4-1/2" 13.5# 13Cr85 13966' 15691' ' 6483' 6832' 6-1/8" 312 sx Class'G' 24. Open to production or injection? Yes a . No ❑ 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number): GRADE DEPTH SET (MD) PACKER SET (MD/TV 4-1/2" 12.6# 13Cr85 13973' 13849'/ 6425' 2-7/8" Gun Diameter, 6 spf 15535'-15567' 6852'- 6849' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 15554'-15587' 6850'- 6846' Was hydraulic fracturing used during completion? Yes ❑ No D ' Per 20 AAC 25.283 (i)(2) attach electronic and printed , information j.. I I�/ Z(e / l DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED -500' Freeze Protect w/ 17 Bbls Diesel U� 27. PRODUCTION TEST Date First Production: December 27, 2017 Method of Operation (Flowing, gas lift, etc.): Gas Lift Date of Test: 12/27/17 Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: 8 Test Period r■1111. 80 152 2005 176 2533 Flow Tubing 220 Press Casino Press: 350 Calculated 24 Hour Rate Oil -Bbl: 20 Gas -MCF: 51 Water -Bbl: 4 668 Oil Gravity - API (torr): WA Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only f" (,4 ri OLR1rr•+a �7- -I tF-� I �-( 28. CORE DATA is Conventional Core(s) Yes ❑ No R1 in Sidewall Cores Yes ❑ No m If Yes to either question, list formations and interva cored (MD+TVD of top and bottom of each), and summarize i ology 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 Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 14525' 6815' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Ugnu 3864' 3582' Schrader Bluff NA 8803' 5017' Schrader Bluff NB 8658' 5032' Schrader Bluff NC 8945' 5055' Schrader Bluff NE 8974' 5063' Schrader Bluff OA 9186' 5120' Schrader Bluff OBa 9309' 5153' Schrader Bluff OBb 9434' 5186' Schrader Bluff OBc 9579' 5225' Schrader Bluff OBd 9741' 5268' Schrader Bluff OBe 9910' 5313' Schrader Bluff OBf 10037' 5347' Colville Mudstone 10174' 5384' HRZ 14234' 6632' Kuparuk C4 14525' 6815' Kuparuk C3 14543' 6826' Kuparuk C2 14716' 6907' Kuparuk C3 (Invert) 15053' 6906' Kuparuk C4 15549' 6851' HRZ 15667' 6835' Formation at total depth: HRZ (From Base) 1 15667' 1 6835' 31. List of Attachments: Summary of Daily Drilling Reports, Summary of Post -Rig Work, LOT/ FIT Summary, 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. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Gorham, Bradley M Authorized Title: Inf ion and Da on ro r Contact Email: Bradley. Gorham@bp.com Authorized Signature: Z Contact Phone: 907-564-4649 INSTRUCTIONS General: This form is designed or submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. 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 1a. 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 4b. 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 permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. 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 10-407 Revised 5/2017 Submit ORIGINAL Only TREE= CW4-1/16"DBL MSTR DRI' HOLE VVELLHEAD= 11" 5M F TVD ACTUATOR TYPE VLV OKB = 66.58' DATE REF 8-13f= 82.32' 3362 BF. ELEV = 36.48' DOME KOP — 2734' 12/21/17 Max Angle = 104" @ 15120 3726 Datum MD = 9049 DMY Datum TVD = 5000' SS 12/21/17 X5/8" IAA IPSTOCK (10128/17) 273d' 9-5/8" CSG, 47#, L-80 BTC, 1D = 8.681" -2734' Minimum ID = 3.725" @ 13955' 4-1/2" HES XN NIPPLE TOP OF CEMENT (11117/17) 7911' V ERIFED w /IBC CEMENT LOG S O S� NOTES: @ 14 ANGLER M �s 13492'. M LS 16.1 14900'. CHROME TSG 8 LNR 2029' --�4-1/2" HES X NP, D= 3.813" MLLOLIT WINDOW (S -200A) 2734' - 2748 GAS LIFT MANDRELS 111111 ST MD TVD I DFV TYPE VLV LATCH PORT DATE 6 3512 3362 45 KGB -2 DOME BK 16 12/21/17 5 4127 3726 57 KGB -2 DMY BK 0 12/21/17 4 6886 4510 75 KGB -2 SO BK 20 12/21/17 3 9649 5244 74 KGB -2 DMY BK -2 0 11/26/17 2 12366 5970 75 KGB -2 DMY BK -2 0 11/26/17 1 113767163871 63 1 KGB -2 I DMI' I BK -2 r 0 11/26/17 13821' (-14-1/2" HES X NP, D= 3.813" 13849' 13883' 4-1/2" HES X NP, D= 3.813" 13966' 1--�4-1/2- HES XN NP, ID = 3.725^ TOP OF 4-1/2- LNR 13966' 13966' 17*X5'WFDLTP&HGRw/TIEBACKSLV, D = 4.310" 4-1/2" TBG, 12.6#,13CR 85 VAM TOP, 13973' 13973' 4-vz^ wLEG, D = 3.958" .0152 bpf, D = 3.958" 13987' 7" CSG, 26#, L-80 VAM TOP, 14148' 0383 bpf, D = 6.276" PERFORAT)ON SUMMARY REF LOG: BAKER MVM GR 11/22/17 ANGLE AT TOP PERF: 96° § 15535' Nate: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 2-7/8" 6 15535 -15567 O 12/26117 2-7/8" 6 15554 - 15587 O 12/25!17 PBTD l --q 16699' 4-1/2' LNR, 13.5#, 13CR-85 HYD 521, I—J_1569V .0150 bpf, D = 3.920' 16391' 1-1 PUP JT w /RA TAG DATE REV BY COMMENTS DATE REV BY 00MM9JTS 01123198 ORIGINAL COMPLETION 01/09/18JNNJJMD ADD@ REF, OKB, & BF ELEV 11127/17 P-272 SIDETRACKS -200A) 12/07/17 JMD DRLG HO ODF4�ELMNS 12/14/17 BG/JMD FINAL ODEAPPROVAL 12/28/17 JMG1,W GLV CIO (12/21117) 12/28/17 I JMG1AU PEWS (12J25-26/17) POLARS UNIT VVELL S -200A PERMIT No: 217-125 AR No: 50-029-22846-01 SEC 35, T12R T12E� 430' NSL & 4500' WEL BP Exploration (Alaska) Page 1 of 1 BP AMERICA LOT / FIT Summary Well Name: S -200A Surface Leak Off Test Test Test Depth Test Depth AMW Pressure Pressure EMW Date Type (TMD -Ft) (TVD -Ft) (pp) (psi) (BHP) (psi) (ppg) 10/29/17 LOT 2,777.27 2,752.43 9.60 683.00 2,055.91 14.38 11/20/17 FIT 14,170.00 6,594.30 10.50 769.00 4,367.33 12.74 Page 1 of 1 C North America - ALASKA - BP Page 1 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations _ (hr) (usft) 10/24/2017 12:00 - 15:00 3.00 RIGID P -0.73 PRE I GENERAL RIG DOWN OPERATIONS SKID RIG FLOOR LAY OVER DERRICK SEPERATE MODULES AND STAGE IN PREPERATION FOR MOVE 15:00 - 00:00 9.00 RIGID P -0.73 PRE MOVE RIG MODULES FROM DS14 TOWARDS S -PAD ALONG THE SPINE ROAD STOP AT BOC TO ALLOW TRAFFIC TO PASS AT 17:30 HRS NEAR EAST CHANNEL OF THE KUPARUK RIVER BRIDGE AT MIDNIGHT -0.73 PRE JMOVE RIG TOWARDS S -PAD ALONG THE 10/25/2017 00:00 - 03:00 3.00 RIGU P SPINE ROAD ACROSS THE WEST CHANNEL OF THE KUPARUK RIVER BRIDGE AT 02:30 HRS -0.73 PRE MOVE RIG DOWN S -PAD ACCESS ROAD TO 103:00 05:00 2.00 RIGU P THE PAD ENTRANCE. TOTAL RIG MOVE 17.5 MILES -0.73 PRE STAGE MODULES AT PAD ENTRANCE -0.73 PRE PICK UP WELLHEAD TOOLS AND EQUIPMENT 05:00 06:00 1.00 RIGU P 06:00 11:00 5.00 RIGU P AND STAGE ON BOP DECK. SPOT DRILL MODULE OVER WELLAND MATE UP THE UTILITY AND MUD MODULES RAISE DERRICK OFF RACK WITH 515 KLBS SKID RIG FLOOR TO DRILLING POSITION AND MOVE HAUNCH INTO POSITION HOOK UP SERVICE LINES BETWEEN MODULES 11:00 14:30 3.50 RIGU P -0.73 - ' PRE RIG UP OVER S-200 CONTINUE WITH GENERAL RIG UP OPERATIONS THROUGHOUT THE RIG BRIDLE DOWN AND SECURE BRIDLE LINES INSTALL TORQUE TUBE PIN UNPIN FORUM CRANE RIG UP RIG FLOOR SURFACE LINES AND RIG FLOOR EQUIPMENT TAKE ON 9.8 PPG BRINE TO PITS -CALIBRATE PVT SYSTEM RIG ACCEPT AT 12:00 HRS 14:30 - 16:00 1.50 BOPSUR P -0.73 PRE CHANGE UPPER PIPE RAMS IN BOP STACK FROM 2-7/8" x 5" VBR TO 4-1/2" x 7" VBRS CONTINUE WITH GENERAL RIG UP OPERATIONS THROUGHOUT RIG PRESSURE TEST BPV FROM BELOW TO 2900 16:00 17:00 1.00 WHSUR P -0.73 PRE PSI HIGH FOR 5 CHARTED MIN PASSING TEST REVIEW PRESSURE CROSSCHECK CHECKLIST PRIOR TO TEST Printed 1/10/2018 5:03:39PM 'All depths reported in Drillers Depths' North America - ALASKA - BP Operation Summary Report Page 2 of 67 Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3 -017W0 -C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 17:00 - 19:00 2.00 WHSUR P -0.73 PRE NIPPLE DOWN TREE AND ADAPTER FLANGE - FUNCTION AND INSPECTALL LOCK DOWN SCREWS AND GLAND NUTS PER FMC REP CLEAN AND INSPECT HANGER THREADS. MAKE UP CROSS-OVER (7 1/4 TURNS) AND BLANKING PLUG (8 1/4" TURNS ON LH ACME) SIMOPS: - GENERAL HOUSEKEEPING THROUGHOUT RIG. 19:00 23:00 4.00 BOPSUR P -0.73 PRE NIPPLE UP BOPE AND HIGH PRESSURE RISER LOWER DSAAND RISER SPOOLS MOVE BOP STACK OVER WELL CENTER TORQUE ALL BOLTS TO SPEC OBTAIN RKB MEASUREMENTS INSTALL TURNBUCKLES AND FLOW RISER SIMOPS: BUILD STANDS OF 4" DRILL PIPE OFF-LINE 23:00 23:30 0.50 BOPSUR P -0.73 PRE MAKE UP BOPE TEST ASSEMBLIES 4" AND 5" VALVE ASSEMBLIES 7" TEST JOINT 23:30 00:00 0.50 BOPSUR P -0.73 PRE HELD H2S / RIG EVACUATION DRILLAND AAR WITH BOTH CREWS 10/26/2017 00:00 00:30 0.50 BOPSUR P -0.73 PRE HELD H2S /RIG EVACUATION DRILLAND AAR WITH BOTH CREWS 00:30 01:00 0.50 BOPSUR- P -0.73 PRE HELD PRE -SPUD MEETING FOR S-200 WITH HUNDLEY'S CREW 01:00 02:00 1.00 BOPSUR P -0.73 PRE CONTINUE TO RIG UP TO TEST BOPE FILL SYSTEM WITH WATER AND PURGE AIR PERFORM A SHELL TEST ON THE BOPE TO 3500 PSI - RE -TORQUE ALL BOP BOLTS 0200 07:00 5.00 BOPSUR P -0.73 PRE TEST BOPE TO 250 PSI LOW, 3500 PSI HIGH FOR 5 CHARTED MINUTES EACH PER BP AND AOGCC REQUIREMENTS TEST WITH 7", 5" AND 3-1/2" TEST JOINTS TEST ALARMS, PVT AND FLOW SHOW TEST RAM LOCKS, HIGH/LOW BYPASS FUNCTION AND POWER BLACK -OUT ALL TESTS PASS, SEE ATTACHED TEST CHARTS - TEST WITNESS WAIVED BYAOGCC REP CHUCK SCHEVE 07:00 08:00 1.00 BOPSUR P -0.73 PRE RIG DOWN BOPE TEST EQUIPMENT AND PICK UP 3-1/2" TEST JOINT TO PULL BLANKING PLUG THROUGH DUTCH RISER. Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths' Printed 1/10/2018 5:03:39PM "All depths reported in Drillers Depths' North America - ALASKA - BP Page 3 of 67 Operation Summary Report Common Well Name: S-200 _ AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 1 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations 08:00 12:00 (h r) 4.00 WHSUR P (usft) -0.73 PRE INSTALL DUTCH RISER AND MAKE UP LUBRICATOR TO PULLAND LAY DOWN BLANKING PLUG / BPV SUCK OUT STACK AND OBSERVE SOME RUBBER FROM ANNULAR ELEMENT IN THE WAY OF THE DUTCH RISER REMOVE SMALL PIECE OF RUBBER FROM ANNULAR INSTALL DUTCH RISER AND RUN IN LOCK DOWN SCREWS - MAKE UP QUICK TEST SUB AND LUBRICATOR TO TOP OF DUTCH RISER - PRESSURE TEST DUTCH RISER/LUBRICATOR ASSEMBLY TO 3500 PSI - GOOD TEST - SET BACK LUBRICATOR AND RUN IN WITH TEST JOINT TO PULL BLANKING PLUG - LAY DOWN BLANKING PLUG, REINSTALL LUBRICATOR AND TEST BREAK - PULL BPV, RIG DOWN LUBRICATOR AND DUTCH RISER. 12:00 13:00 1.00 WHSUR P -0.73 DECOMP HELD PRE -SPUD MEETING FOR S-200 WITH YEAROUT'S CREW, SERVICE PERSONNEL _ AND PARKER MANAGEMENT TEAM 13:00 - 13:30 0.50 WHSUR P -0.73 DECOMP RIG DOWN 3-1/2" TEST JOINTAND BLOW DOWN CHOKE LINE 13:30 15:00 1.50 WHSUR P 3,223.27 DECOMP CIRCULATE OUT THE DIESEL FREEZE PROTECT TO THE TIGER TANK. CLOSE THE BLIND/SHEAR RAMS AND LINE UP TO CIRCULATE OUT TO THE TIGER TANK CIRCULATE BARA-KLEAN SOAP PILL, SURFACE TO SURFACE THROUGH THE CUT AT 3224' 5 BPM, 640 PSI WHSUR P 3,223.27 DECOMP ENGAGE TUBING HANGER WITH LANDING 15:00 16:00 1.00 JOINT, BACK OUT LOCK DOWN SCREWS AND I PULL TO RIG FLOOR HANGER CAME OFF SEAT AT 59 KLBS MONITOR WELL FOR 10 MIN; STATIC DECOMP CIRCULATE A BOTTOMS UP 1600 1700 1.00 WHSUR P 3,223.27 - 6 BPM, 290 PSI -MONITOR WELL FOR 10 MIN; STATIC 17:00 21:00 4.00 CASING P 3,223.27 DECOMP PULLAND LAY DOWN 3-1/2",9.3 LB/FT EUE TUBING FROM CUT AT 3224' MD LAY DOWN HANGER AND LANDING JOINT SWAP TO 3-1/2" ELEVATORS PULLAND LAY DOWN: 99 FULL JTS, 4 PUP JTS, 2 GLM ASSEMBLIES, 1 X -NIPPLE ASSEMBLY AND 1 CUT JT CUT JOINT DAL = 3.4' WITH A 4.5" OD FLARE SEE ATTACHED PICTURE OF CUT JT. 21:00 - 21:30 0.50 CASING P 3,223.27 DECOMP RIG DOWN DOYON CASING TOOLS AND CLEAN AND CLEAR RIG FLOOR INSTALL 10" ID WEAR RING Printed 1/10/2018 5:03:39PM "All depths reported in Drillers Depths' North America - ALASKA - BP Page 4 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USACOOOO172 Active datum: S-200AActual @82.32usft (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 FISH N 3,223.27 DECOMP WAIT FOR SCHLUMBER E-LINE TOARRIVE ON LOCATION SIMOPS: - LOAD, STRAP, TALLY AND BUILD STANDS OF 5" DRILL PIPE OFF -LINE - FMC REPRESENTATIVE BACK-OUTAND CHECK LDS ON 7" CASING; NO SIGNS OF CASING COMPRESSION NOTED SERVICE RIG FLOOR PIPE HANDLING EQUIPMENT 4' 00:00 00:30 0.50 10/27/2017 FISH N 3,223.27 DECOMP CONTINUE TO WAIT FOR E-LINE TO ARRIVE i ON LOCATION SIMOPS - CONTINUE BUILDING STANDS OF 5" DRILL PIPE OFF -LINE 00 30 02:30 FISH P 3,223.27 DECOMP RIG UP SCHLUMBERGER E-LINE UNIT 2.00 SPOT E-LINE UNIT MOBILIZE GAUGE RING / JUNK BASKET TOOL STRING TO RIG FLOOR MOBILIZE E-LINE SHEAVES TO RIG FLOOR RIG UP E-LINE SHEAVES AND MAKE UP TOOL STRING SIMOPS: CONTINUE BUILDING STANDS OF 5" DRILL PIPE OFF -LINE 02:30 04:00 1.50 FISH P 3,223.27 DECOMP PICK UPAND RUN IN THE HOLE WITHA5.90" OD GUAGE RING AND JUNK BASKET TO 3194' SLMD. PULL OUT OF THE HOLE AND LAY DOWN THE GUAGE RING AND JUNK BASKET. 04:00 10:30 6.50 FISH P 3,223.27 DECOMP MAKE UPAND RUN IN THE HOLE WITH ISOLATION SCANNER - LOG WELL WITH SEVERAL PASSES FROM 3100' TO SURFACE LOG TOP OF CEMENT AT 3076' SLMD LOG COLLAR TO CUT BELOW AT 2776' SLMD 10:30 - 12:00 1.50 FISH P 3,223.27 DECOMP RIG DOWN SCHLUMBERGER E-LINE UNIT AND CLEAR RIG FLOOR 12:00 13:00 1.00 FISH P 3,223.27 _ DECOMP PICK UPAND RUN IN THE HOLE WITH SLB HYDRAULIC CASING CUTTER ASSEMBLY DRESSED TO CUT 7" 26 LB/FT CASING MOBILIZE TOOLS TO RIG FLOOR MAKE UP AND RUN IN THE HOLE TO 42' MD 13:00 14:30 1.50 FISH P 3,223.27 DECOMP RUN IN THE HOLE WITH SLB HYDRAULIC CASING CUTTER ASSEMBLY ON 4" DRILL PIPE FROM 42' MD TO 2400' MD PU 68 KLBS, SO 68 KLBS AT 2400' MD _ 14:30 16:30 2.00 FISH P 3,223.27 DECOMP PERFORMED D1 / D5 DRILLANDAAR WITH RIG CREW - SHUT IN THE WELL PER STANDING ORDERS, AAR D1 DRILL - PROCEED WITH STRIPPING DRILL: APPLIED 100 PSI WORKING PRESSURE TO WELLBORE AND STRIPPED IN WITH 100 PSI WORKING 'PRESSURE Printed 1/10/2018 5:03.39PM *All depths reported in Drillers Depths` North America - ALASKA - BP Operation Summary Report Page 5 of 67 Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 16:30 - 17:00 0.50 FISH P 3,223.27 DECOMP CONTINUE TO RUN IN THE HOLE WITH SLB HYDRAULIC CASING CUTTER ASSEMBLY ON 4" DRILL PIPE - FROM 2400' MD TO 2786' MD 17:00 19:30 2.50 FISH P 3,223.27 DECOMP CUT 7" CASING AT 2788' MD PER SLB FISHING REPRESENTATIVE - VERIFY LINE UP OF OA TO TIGER TANKAND BLOW AIR TO CONFIRM CLEAR - SHUT IN OA TO A MONITORED MANUAL PRESSURE GAUGE ESTABLISH PARAMETERS AND OPEN KNIVES, 1 BPM, 100 PSI - LOCATE CASING COLLAR AT 2778' MD WITH CUTTER KNIVES - SPACE OUT AND SET CUTTER ON DEPTH 10' BELOW COLLAR AT 2788' MD - CUT 7" CASING PER SLB REPRESENTATIVE: 60 RPM, 2-3 KFT-LBS TORQUE, 3 BPM, 670 PSI - OBSERVE PRESSURE DROP TO 450 PSI AFTER 15 MIN OF CUTTING WITH NO 'INCREASE ON OA PRESSURE GAUGE SHUT DOWN AND ATTEMPT TO ESTABLISH CIRCULATION THROUGH OA CLOSE ANNULAR PREVENTER AND LINE UP TO TIGER TANK PRESSURE UP TO 450 PSI WITH NO RETURNS TO TIGER TANK SHUT DOWN AND RE -LINE UP TO CONTINUE CUT CONTINUE CUTTING OPERATIONS PER SLB REPRESENTATIVE: 60 RPM, 2 KFT-LBS TORQUE, 3 BPM, 670 PSI - OBSERVE PRESSURE SLOWLY DECREASE TO 280 PSI OVER 40 MIN WITH NO INCREASE ON OA PRESSURE GAUGE - SHUT DOWN AFTER 40 MIN ANDATTEMPT TO ESTABLISH CIRCULATION THROUGH CUT 19:30 21:00 1.50 FISH P 3,223.27 DECOMP CLOSED THE ANNULAR AND CIRCULATEDA BARA-KLEAN SOAP PILL THROUGH THE CUT AT 2788' MD AND OUT THE OA TO THE TIGER TANK TOOK 8 BBLS AT 1/2 BPM, 800 PSI TO GET RETURNS OUT THE OA STAGE UP PUMPS TO 2 BPM, 1500 PSI 21:00 22:00 1.00 FISH P 3,223.27 DECOMP j PULL OUT OF THE HOLE ON ELEVATORS WITH SLB HYDRAULIC CASING CUTTER ASSEMBLY FROM 2788' MD TO 42' MD MONITOR WELL FOR 10 MIN. STATIC PU 71 KLBS, SO 69 KLBS AT 2780' MD SIGNS OF WEAR IN MULTIPLE SPOTS ON DRILL PIPE: 256' (2522' MD), 124' (2654' MD), 42'(273& MD) AND 22' (2756' MD) BACK FROM CUTTER 22:00 - 22:30 0.50 FISH P 3,223.27 DECOMP LAY DOWN SLB HYDRAULIC CASING CUTTER ASSEMBLY - SIGNIFICANT SIGNS OF WEAR AND GOOD CASING CUT ON KNIFE BLADES Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Page s of 6i Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor. PARKER DRILLING CO. BPUOI: USA00000172 Active datum: 5-200A Actual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT ! Total Depth Phase Description of Operations (hr) (usft) ''MAKE UP SPEAR ASSEMBLY FOR SPEARING 22:30 23:00 0.50 FISH P 3,223.27 DECOMP 7" CASING - SPEAR WITH PACK -OFF (DRESSED TO CATCH 7.'26 LB/FT CASING), SPEAR EXTENSION AND STOP 3,223.27 DECOMP BACK OUT LOCK DOWNS AND PULL 10" ID 23:00 23:30 0.50 FISH P WEAR RING 0.50 FISH P 3,223.27 DECOMP SERVICE TOP DRIVE AND RIG FLOOR 2330 00:00 EQUIPMENT 10/28/2017 00:00 01:30 1.50 FISH P 3,223.27 DECOMP - PULL 7" CASING HANGER TO RIG FLOOR - MAKE UP SPEAR TO 2 JOINTS OF 4" DRILL PIPE RUN IN THE HOLE AND ENGAGE 7" CASING BELOW HANGER WITH SPEAR j SUCK OUT STACK AND BACK OUT LOCK DOWN SCREWS PER FMC REP PULL 7" CASING FREE WITH 110 KLBS (ESTIMATED STRING WEIGHT 62 KLBS + 35 KLBS P272 BLOCKS = 97 KLBS) = PULL HANGER TO RIG FLOOR, PU 95 KLBS 3,223.27 DECOMP BREAK OUT AND LAY DOWN SLB CASING 01 30 0200 0.50 FISH P — SPEARASSEMBLY 3,223.27 DECOMP RIG UP TO LAY DOWN 7" CASING WITH 0200 02:30 0.50 CASING P DOYON CASING MOBILIZE TONGS TO RIG FLOOR -VERIFY FOSV AND XO ON RIG FLOOR FOR 3.00 CASING P 3,223.27 DECOMP 7" BTC CASING 02:30 - 05:30 PULL AND LAY DOWN 7" CASING FROM CUT AT 2788' MD PU 95 KLBS, SO 95 KLBS AT 2700' MD LAY DOWN 66 FULL JTS, (1) 20' PUP JT, AND (1) 10.35' CUT JT 05:30 - 06:30 1.00 CASING P 3,223.27 DECOMP RIG DOWN DOYON CASING. CLEAN AND CLEAR RIG FLOOR. 06:30 - 07:00 0.50 WHSUR P 3,223.27 DECOMP INSTALL 9-1/16" ID WEAR RING, RUN IN LOCK DOWN SCREWS. DECOMP PICK UP AND RUN IN THE HOLE WITH HES 07:00 09:00 2.00 FISH P 3,223.27 9-5/8" EZSV ON 4" DRILL PIPE TO 2740' MD PU 70 KLBS, SO 71 KLBS AT 2740' MD MONITOR DISPLACEMENT WITH TRIP TANK; CORRECT DISPLACEMENT 09:00 09:30 0.50 FISH P 2,775.27 DECOMP _ SET EZSV ON DEPTH AT 2776' MD PER HES REPRESENTATIVE 35 TURNS TO THE RIGHT, PU IN 10 KLBS INCREMENT f - PACKER SHEAREDAND SETAT 50K OVER (120 KLBS HOOKLOAD) 09:30 10:30 1.00 FISH N 2,775.27 DECOMP ATTEMPT TO PRESSURE TEST 9-5/8" CASING AND EZSVAT 2776' MD TO 2900 PSI - REVIEW WORKING WITH PRESSURE CROSSCHECK CHECKLIST - CLOSE ANNULAR PREVENTER AND PRESSURE UP TO 3000 PSI - SIMILAR BLEED OFF PATTERNS EACH TIME, ALL IN EXCESS OF 15 PSI/MIN - BLEED OFF PRESSURE AND OPEN ANNULAR Printed 1/10/2018 5 03 39P 'All depths reported in Drillers Depths' North America - ALASKA - BP Page 7 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) OMP PULLOUT OF THE HOLE AND LAY DOWN THE 10:30 12:00 1.50 FISH P 2,775.2E EZSV RUNNING TOOL FROM 2740' MD - MONITOR WELL FOR 10 MIN; STATIC MONITOR HOLE FILL WITH TRIP TANK; I CORRECT FILL 12:00 13:30 FISH P 1.50 2,775.27 DECOMP PRESSURE TEST 9-5/8" CASING AND EZSV AT 12776'MU 10 2900 PSI FOR 30 CHARTMW� PURGE AIR FROM SYSTEM REVIEW WORKING WITH PRESSURE CROSSCHECK CHECKLIST - CLOSE BLIND/SHEAR RAMS AND PRESSURE UP TO 3000 PSI GOOD TEST, MET BP TESTING CRITERIA FtH BF FRAMICE 100218 LOST 50 PSI IN THE FIRST 15 MIN, 10 PSI IN THE SECOND 15 MIN PUMPED 2.1 BBLS, BLED BACK 2.1 BBLS i WSUP REVIEWED AND APPROVED PRESSURE TEST RESULTS SEE ATTACHED TEST CHART AND TEST 0.50 FISH P CRITERIA CALCULATOR 13:30 - 14:00 2,775.274 DECOMP'' DRAIN STACK, BACK OUT LOCK DOWN SCREWS AND REMOVE 9-1/16" ID WEAR RING 14:00 - 15:00 1.00 FISH ,. P 2,775.27 DECOMP - 'PRESSURETEST ANNULAR PREVENTER WITH 4" TEST JOINT TO CONFIRM OPERATIONAL INTEGRITY INSTALL TEST PLUG AND 4" TEST JOINT PURGE AIR FROM SYSTEM REVIEW WORKING WITH PRESSURE CROSSCHECK CHECKLIST - PRESSURE TEST ANNULAR 250 PSI LOW / 3500 PSI HIGH FOR 5 CHARTED MIN EACH -GOOD TEST 15:00 15:30 0.50 FISH P 2,775.27 DECOMP PULL TEST PLUG AND INSTALL 9-1/16" ID WEAR RING, RUN IN LOCK DOWN SCREWS RIG DOWN TEST EQUIPMENT AND BLOW DOWN ALL LINES 15:30 16:30 1.00 FISH P 2,775.27 DECOMP CHANGE SAVER SUB FROM HT -38 TO NC50 'THREAD MONITOR WELL WITH TRIP TANK; STATIC SERVICE TOP DRIVE AND BLOCKS. 16:30 17:00 0.50 FISH P 2,775.27 DECOMP 17:00 19:00 2.00 WHIP P 2,775.27 WEXIT PICK UP AND MAKE UP SLB 9-5/8" TRACKMASTER WHIPSTOCK MAKE UP MWD, FLEX JOINT, FLOAT SUB AND TRI-MILLASSEMBLY SCRIBE MWD TO WHIPSTOCK PLUG IN AND VERIFY COMMUNICATION WITH MWD 2,775.27 19:00 21:30 2.50 WHIP P WEXIT MAKE UP WHIPSTOCKTO MILLASSEMBLY AND RUN IN THE HOLE TO 1166' MD - MAKE UP WHIPSTOCK TO MILLASSEMBLY AND VERIFY 30K SHEAR BOLT INSTALLED - PICK UP (9) 6-1/2" SPIRAL DRILL COLLARS FROM PIPE SHED PICK UP 25 JOINTS OF 5" HWDP FROM PIPE SHED Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Operation Summary Report Common Well Name: 5-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Page 8 of 67 Date From - To Hrs 23 00 Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 21:30 22:30 1.00 WHIP P 2,775.27 WEXIT CONTINUE TO RUN IN THE HOLE WITH SLB 9-5/8" TRACKMASTER WHIPSTOCK ON 5" DRILL PIPE STANDS OUT OF THE DERRRICK FROM 1166' MD TO 2744' MD PU 129 KLBS, SO 127 KLBS AT 2744' MD MONITOR DISPLACEMENT WITH TRIP TANK; CORRECT DISPLACEMENT 22:30 23:00 0.50 WHIP P 2,775.27 WEXIT ORIENTANDSET 9-5/8"WHIPSTOCK TO90- 0° 23:00 - 00:00 1.00 WHIP 10/29/2017 00:00 10:00 10:00 14:00 RIGHT OF HIGH SIDE - ORIENT WHIPSTOCK PER BAKER DD TO 90° ROHS - SHUT DOWN PUMPS AND SLACK OFF TO TOP OF EZSV AT 2776' MD - SET DOWN 8 KLBS ON EZSV TO ACTIVATE THE MECHANICAL ANCHOR - PICK UP 19' AND SET WHIPSTOCK, SHEAR BOLT SHEARED WITH 28 KLBS DOWN - PICK UP AND CONFIRM WHIPSTOCK SET WITH 10 KLBS TOP OF WHIPSTOCK AT 2734' MD (TOW) BOTTOM OF SLIDE AT 2748' MD (BOW) BOTTOM OF WHIPSTOCKAT 2757' MD P 2,775.27 WEXIT DISPLACE WELL TO 9.6 PPG MILLING FLUID 750 GPM, 1900 PSI MONITOR WELL FOR 10 MIN; STATIC MW IN/OUT 9.6 PPG TAKE SPR AT 2752' MD: MP1: 30/40 SPM, 150/190 PSI }_ MP2: 30/40 SPM, 150/190 PSI 10.00 WHIP P 2,749.27 WEXIT MILL WINDOW IN 9-5/8" CASING PER SLB 14:00 - 14:30 0.50 WHIP FISHING REPRESENTATIVE _1140w FROM 2734' MD TO 2750' MD 80 RPM, 2-8MFT-LBS TORQUE, 442 GPM, 800 PSI, 2-6 KLBS WOB TOW: 2734' MD, BOW: 2748' MD 7 WEXIT MILL 30' OF NEW FORMATION AFTER EXITING THE WINDOW FROM 2750' MD TO 2778' MD 425 GPM, 800 PSI, 80 RPM, 2 KFT-LBS TORQUE, 2-3 KLBS WOB PU 128 KLBS, SO 123 KLBS, ROT 127 KLBS WORK MILLS THROUGH WINDOW WITH PUMPS ON/OFF - 3 KLBS DRAG ON UP-STROKE, 2 KLBS DRAG ON THE DOWN -STROKE THROUGH THE WINDOW P 2,777.27 WEXIT CIRCULATE THE HOLE CLEAN, PUMP 35 BBL HIGH -VIS SWEEP - 425 GPM, 775 PSI, 20 RPM, 2 KFT-LBS TORQUE MUD WT IN/OUT = 9.6 PPG TAKE SPR AT 2778' MD: MP1: 30/40 SPM, 150/190 PSI MP2: 30/40 SPM, 150/190 PSI MONITOR THE WELL FOR 10 MIN; STATIC Printed 1/10/2018. 5:03:39PM `All depths reported in Drillers Depths' Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths' NOrti1 AfY1erlCa - ALASKA - BP Page 9 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00 OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) — — _ 14:30 - 15:00 0.50 _ _ _ WHIP P 2,777.27 WEXIT PERFORMED UNANNOUNCED KICK WHILE DRILLING DRILLAND AAR WITH RIG CREW AND WITNESSED BY WSLAND WELL SUPPORT SUPERINTENDENT, LEN SEYMOUR ESCALATED DRILL DURING AAR TO INCLUDE DISCUSSIONS ON MASP, GAS MIGRATION AND KICK TOLERANCE. j REVIEWED METHODS FOR MANAGING A WELL CONTROL SITUATION WERE SHUT-IN PRESSURES ARE REACHING MASP. 15:00 16:00 1.00 WHIP P 2,777.27 WEXIT PERFORM LEAK OFF TEST TO 14.4 PPG EMW REVIEW WORKING WITH PRESSURE CROSSCHECK CHECKLIST 1.0 BBLS PUMPED, 0.8 BBLS BLED BACK TEST DEPTH TVD = 2748' DEVIATION FROM LINEAR TREND AT 685 PSI PROVIDE ODE WITH TEST DOCUMENTATION AND RECEIVE APPROVAL TO PROCEED. 16:00 - 17:00 1.00 WHIP P 2,777.27 WEXIT PULL OUT OF THE HOLE WITH MILLING ASSEMBLY ON ELEVATORS FROM 2778' MD TO 1166' MD MONITOR WELL FOR 10 MIN: STATIC PU 91 KLBS, SO 91 KLBS AT 11 70'MD MUD WT IN/OUT = 9.6 PPG MONITOR HOLE FILL WITH TRIP TANK: GOOD HOLE FILL 17:00 19:00 2.00 WHIP P 2,777.27 WEXIT PULL OUT OF THE HOLE AND LAY DOWN MILLING BHA PER SCHLUMBERGER REP - FROM 11 66'MD MONITOR WELL FOR 10 MINUTES BEFORE PULLING NON SHEARABLES THROUGH THE STACK: STATIC STARTER MILL 3/16" UNDER -GAUGE WITH SIGNIFICANT WEAR MIDDLE MILL 1/8" UNDER -GAUGE UPPER MILL IN -GAUGE 1900 2030 1.50 WHIP P 2,777.27 WEXIT CLEAN AND CLEAR RIG FLOOR AND FLUSH STACK 20:30 21:00 0.50 WHIP P 2,777.27 WEXIT SERVICE TOP DRIVE AND WELL CENTER ST -80 21:00 23:00 2.00 WHIP P 2,777.27 WEXIT MAKE UP AND RUN IN HOLE WITH 8-1/2", 1.3" MOTOR ASSEMBLY WITH GR/RES/DIR/GWD FROM SURFACE TO 740' MD ON ELEVATORS MUD WT IN/OUT = 9.6 PPG 23:00 00:00 1.00 WHIP P 2,777.27 WEXIT RUN IN HOLE WITH 8-1/2",1.3- MOTOR ASSEMBLY FROM 740' MD TO 2255' MD ON ELEVATORS WITH 5" DRILL PIPE MUD WT IN/OUT = 9.6 PPG - SHALLOW HOLE TEST MWD TOOLS AT 800' MD: GOOD TEST - MONITOR DISPLACEMENT WITH TRIP TANK: GOOD DISPLACEMENT 10/30/2017 00:00 01:00 1.00 WHIP P 2,777.27 WEXIT RUN IN HOLE WITH 8-1/2", 1.3° MOTOR ASSEMBLY FROM 2255' MD TO 2778' MD ON ELEVATORS WITH 5" DRILL PIPE MUD WT IN/OUT = 9.6 PPG CALIBRATE BLOCKS WITH MWD AND ORIENT - MONITOR DISPLACEMENT WITH TRIP TANK: GOOD DISPLACEMENT Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths' North America - ALASKA - BP Operation Summary Report Page 10 of 67 Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date. 11/24/2017 X3-017WO-C: (6,876.211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00 OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) _ _ _ (usft) 01:00 - 11:30 10.50 DRILL P 3,200.27 INTI DIRECTIONAL DRILL 8-1/2" INTERMEDIATE 11:30 12:00 0.50 DRILL P 12:00 13:30 1.50 DRILL P HOLE FROM 2778' MD TO 3201' MD (3123' TVD) IN THE SV4, SV3 AND SV2 FORMATIONS (423' IN 10.5 HRS = 40.3 FT/HR WTIH CONNECTIONS) - 550 GPM, 1290 PSI ON BOTTOM, 1200 PSI OFF BOTTOM - 50-75 RPM, 3-4 KFT-LBS TORQUE ON BOTTOM, 1-3 KFT-LBS TORQUE OFF BOTTOM, 12-20 KLBS WOB PU 125 KLBS, SO 117 KLBS, ROT 115 K LBS SURVEY EVERY -90 FT NO LOSSES WHILE DRILLING AHEAD AVERAGE BACKGROUND GAS 40 UNITS, MAX 2190 UNITS MUD WT IN/OUT = 9.6 PPG 3,200.27 INTI CIRCULATE HIGH -VIS SWEEP 550 GPM, 1330 PSI, 70 RPM, 2 KFT-LBS TORQUE MONITOR WELL FOR 10 MINUTES PRIOR TO PULLING OFF BOTTOM: STATIC 3,200.27 INT1 PULL OUT OF HOLE ON ELEVATORS FROM 3201' MD TO 740' MD PU = 124 KLBS, SO = 121 KLBS AT 2721' MD MUD WT IN/OUT = 9.6 PPG MONITOR HOLE FILL WITH TRIP TANK: GOOD HOLE FILL Printed 1/10/2018 5:03:39PM "All depths reported in Drillers Depths" MONITOR WELL FOR 10 MINUTES PRIOR TO PULLING NON-SHEARABLES THROUGH THE STACK: STATIC 2.00 DRILL 13:30 15:30 P 3,200.27 INTI PULL OUT OF THE HOLE AND LAY DOWN 8-1/2", 1.3° MOTOR ASSEMBLY FROM 740' MD BIT GRADE: 1 -1 -BT -M -3 -1 -WT -BHA 15:30 16:00 0.50 DRILL P 3,200.27 INT1 CLEAN AND CLEAR RIG FLOOR 16:00 18:30 2.50 DRILL P 3,200.27 INT1 MU 8-1/2" RSS DRILLING BHA WITH FROM SURFACE TO 470' MD - HYCALOG 616-J1 D PDC BIT WITH GR@BIT/G R/RES/DI R/PWD/VSS/CO-PILOT/AN DERREAMER - RIH ON ELEVATORS, PICKING UP TOOLS FROM PIPE SHED PLUG IN AND UPLOAD TOOL SHALLOW HOLE TEST TOOLS AT 470' MD MUD WT IN/OUT = 9.6 PPG MONITOR DISPLACEMENT WITH TRIP TANK: GOOD DISPLACEMENT 1.50 DRILL 18:30 20:00 P 3,200.27 INTI RUN IN HOLE WITH 8-1/2" RSS DRILLING BHA FROM 470' MD TO 2550' MD ON ELEVATORS - MONITOR DISPLACEMENT WITH TRIP TANK: GOOD DISPLACEMENT FILL PIPE EVERY 2000' MD PU 92 KLBS, SO 92 KLBS AT 2550' MD MUD WT IN/OUT = 9.6 PPG 20:00 - 21:30 1.50 DRILL P 3,200.27 INT1 I CUT AND SLIP 51' OF DRILL LINE HANG OFF BLOCKS CUT AND SLIP CALIBRATE BLOCKS WITH BAKER MWD SERVICE TOP DRIVE AND BLOCKS Printed 1/10/2018 5:03:39PM "All depths reported in Drillers Depths" North America - ALASKA - BP Page 11 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211,00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPU01: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 1.50 3,200.27 INT1 CONTINUE TO RUN IN HOLE WITH 8-1/2" RSS 21:30 - 23:00 DRILL P DRILLING BHA FROM 2550' MD TO 2837' MD ON ELEVATORS - MONITOR DISPLACEMENT WITH TRIP TANK: GOOD DISPLACEMENT - WASH DOWN AND OBTAIN TIE-IN LOGS FROM 2550' TO 2739' MD - 550 GPM, 1750 PSI, 50 RPM, 1 KFT-LBS TORQUE, 275 FPH ! PU 100 KLBS, SO 97 KLBS AT 2800' MD I- IUD WT IN/OUT = 9.6 PPG 23:00 00:00 1.00 DRILL N 3,201.00 INTI SET DOWN 25 KLBS AT 2834' MD (8-3/8" OD STRING STABILIZER AT CASING WINDOW) ATTEMPT TO WORK THROUGH SEVERAL TIMES WITH AND WITHOUT PUMPS AND ROTATING PIPE 1/2 TO 3/4 TURNS BETWEEN ATTEMPTS. SEVERALTIMES TOOK JARS WITH 35 KLBS OVERPULL TO PULL FREE. NOTIFY ODE AND PUMP 35 BBL EP -MUD LUBE SWEEP. 10/31/2017 00:00 00:30 0.50 DRILL N 3,201.00 t INT1 CIRCULATE EP MUD LUBE PILLAROUND 420 GPM / 925 PSI 00:30 04:00 3.50 DRILL N 3,201.00 INT1 CONTINUE TO WORK 8.5" RSS DRILLING BHA FROM 2837' TO 2934' MD WORK STABILIZERS AND UNDERREAMER THROUGH WINDOW WITH 10-15 KLBS, ROTATING PIPE 1/2 - 3/4 TURN AS REQUIRED - MAX SET DOWN LIMIT 25 KLBS, JARS AND 35 KLBS OVERPULLTO PULL FREE MULTIPLE TIMES DIFFICULTY GETTING DOWN EVEN AFTER BHA COMPLETELY THROUGH WINDOW, CONTINUE TO WORK BHA DOWN. DRILL P 04:00 05:00 1.00 3,201.00 INT1 WASH DOWN FROM 2934' MD TO 3201' MD 300 GPM, 530 PSI DROP BALL,OPEN UNDERREAMER AND VERIFY PARAMETERS PER NOV REP Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - Blo Operation Summary Report Page 12 of 67 Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 05:00 - 12:00 7.00 DRILL P 3874.00 INT1 DRILL AHEAD IN 8-1/2" x 9-7/8" INTERMEDIATE HOLE WITH RSS AND UNDERREAMER DRILLING ASSEMBLY FROM 3201' MD TO 3874' MD / 3588' TVD IN THE SV2/SV3 FORMATIONS (673 FT IN 7 HOURS = 96.1 FT/HR WITH CONNECTIONS) - 750 GPM, 2615 PSI ON BOTTOM, 2660 PSI OFF BOTTOM - 150 RPM, 5 KFT-LBS TORQUE ON BOTTOM, 3 KFT-LBS TORQUE OFF BOTTOM, 10 KLBS WOB - PU = 115 KLBS, SO = 104 KLBS, ROT = 105 KLBS SURVEY EVERY STAND BUILD INCLINATION ANGLE FROM 35° TO 56° AT 3833' MD ECD ACTUAL = 10.6 PPG EMW NO LOSSES OBSERVED MUD WEIGHT IN/OUT = 9.6 PPG NOVOS AND SOFTSPEED ENABLED -AVE BACKGROUND GAS ON GAS WATCH = 27 UNITS, MAX = 27 UNITS PUMPED 35 BBL HI VIS SWEEPS: @ 3700' MD: 35 BBL HI VIS SWEEP, 50% INCREASE IN CUTTINGS 12:00 00:00 12.00 DRILL P 5,011.00 INTI DRILLAHEAD IN 8-1/2" x 9-7/8" INTERMEDIATE HOLE WITH RSSAND UNDERREAMER DRILLING ASSEMBLY FROM 3874' MD TO 5011' MD / 4037' TVD IN THE UG4/UG4A FORMATIONS (1137 FT IN 12 HOURS = 94.8 FT/HR WITH CONNECTIONS) - 750 GPM, 3070 PSI ON BOTTOM, 3060 PSI OFF BOTTOM - 150 RPM, 5 KFT-LBS TORQUE ON BOTTOM, 2 KFT-LBS TORQUE OFF BOTTOM, 8 KLBS WOB PU = 127 KLBS, SO = 105 KLBS, ROT = 109 KLBS SURVEY EVERY STAND CONTINUE TO BUILD INCLINATION ANGLE FROM 560 TO 750 AT 4780' MD, HOLD 750 INCLINATION - START LEFT TURN FROM 331 ° AZIMUTH AT 4615' MD TO 314° AZIMUTH AT 5064' MD: TARGET HEADING 3070 AZIMUTH ECD ACTUAL = 10.27 PPG EMW NO LOSSES OBSERVED MUD WEIGHT IN/OUT = 9.6 PPG NOVOS AND SOFTSPEED ENABLED AVE BACKGROUND GAS ON GAS WATCH = 300 UNITS. MAX = 1400 UNITS PUMPED 35 BBL HI VIS SWEEPS: @ 4180' MD: 35 BBL HI VIS SWEEP, 50% INCREASE IN CUTTINGS @ 4730' MD: 35 BBL HI VIS SWEEP, NO INCREASE IN CUTTINGS Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Page 13 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr).. — (usft) 11/1/2017 100:00 06:00 6.00 DRILL P 5,586.00 INT1 DIRECTIONAL DRILL 8-1/7'x 9-7/8" INTERMEDIATE HOLE FROM 5040' MD TO 5586' MD / 4182' TVD IN THE UG3 FORMATION - 546' IN 6 HOURS = 91 FPH WITH CONNECTIONS INSTANTANEOUS ROP = 150-200 FPH 750 GPM, 3280 PSI ON BOTTOM, 3270 PSI OFF BOTTOM, 150 RPM, 6 KFT-LBS TORQUE ON BOTTOM, 4 KFT-LBS TORQUE OFF BOTTOM, 10 KLBS WOB - PU = 130 KLBS, SO = 109 KLBS, ROT = 112 KLBS SURVEY EVERY STAND FOR DOGLEGS < 5°/100' CONTINUE TO HOLD 75° INCLINATION CONTINUE LEFT TURN FROM 310° AZIMUTH AT 5159' MD TO 307° AZIMUTH AT 5538' MD ECD ACTUAL ='1'1.12 PPG EMW: CALCULATED 10,30 PPG NO LOSSES OBSERVED PRESSURIZED MUD WEIGHT IN/OUT = 9.6/9.6+ PPG, NON -PRESSURIZED MUD WEIGHT IN/OUT = 9.2/9.2 PPG FLOWLINE TEMPERATURE = 115°F ADDING WATER AT 30 BPH NOVOS AND SOFTSPEED ENABLED GAS WATCH: AVERAGE BACKGROUND= 1100-300 UNITS, MAXIMUM = 400 UNITS PUMPED SWEEPS AS FOLLOWS: 5206' MD: 35 BBL HI -VIS SWEEP, 25% INCREASE IN CUTTINGS Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Page 14 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3 -017W0 -C: (6,876,211.00) Project: Prudhoe Bay Site. PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:00AM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 06:00 12:00 6.00 DRILL P 6,050.00 INT1 DIRECTIONAL DRILL 8-1/2" x 9-7/8" INTERMEDIATE HOLE FROM 5586' MD TO 6050' MD / 4299' TVD IN THE UG3 FORMATION - 464' IN 6 HOURS = 77 FPH WITH CONNECTIONS INSTANTANEOUS ROP = 50-200 FPH 750 GPM, 3280-3400 PSI ON/OFF BOTTOM, 150 RPM, 5-8 KFT-LBS TORQUE ON BOTTOM, 4-5 KFT-LBS TORQUE OFF BOTTOM, 7-15 KLBS WOB - PU = 143 KLBS, SO = 112 KLBS, ROT = 116 KLBS - SURVEY EVERY STAND FOR DOGLEGS < 5°/100' - CONTINUE TO HOLD 75° INCLINATION, HOLD 307° - 304° AZIMUTH -ECD ACTUAL= 11.02 PPG, CALCULATED 10.42 PPG -NO LOSSES OBSERVED PRESSURIZED MUD WEIGHT IN/OUT = 9.6/9.6+ PPG, NON -PRESSURIZED MUD WEIGHT IN/OUT = 9.2/9.1+ PPG FLOWLINE TEMPERATURE= 116°F ADDING WATER AT 30 BPH NOVOS AND SOFTSPEED ENABLED GAS WATCH: AVERAGE BACKGROUND = 70-200 UNITS, MAXIMUM = 376 UNITS PUMPED SWEEPS AS FOLLOWS: 5680' MD: 35 BBL HI -VIS SWEEP, 25% INCREASE IN CUTTINGS Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* Printed 1/10/2018 5:03:39PM 'All depths reported in Drillers Depths' North America - ALASKA - BP Page 15 of 67 Operation Summary Report Common Well Name: 5-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (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 6,623.00 INT1 DIRECTIONAL DRILL 8-1/2" x 9-7/8" INTERMEDIATE HOLE FROM 6050' MD TO 6623' MD / 4443' TVD IN THE UG3/UG1 FORMATIONS - 573' IN 6 HOURS = 95.5 FPH WITH CONNECTIONS INSTANTANEOUS ROP = 150-200 FPH 750 GPM, 3425-3415 PSI ON/OFF BOTTOM, 150 RPM, 8 KFT-LBS TORQUE ON BOTTOM, 6 KFT-LBS TORQUE OFF BOTTOM, 10-15 KLBS WOB PU = 153 KLBS, SO = 114 KLBS, ROT = 118 KLBS SURVEY EVERY STAND FOR DOGLEGS < 5°/100' - CONTINUE TO HOLD 75° INCLINATION, HOLD 304'- 308° AZIMUTH - ECD ACTUAL= 10.93 PPG, CALCULATED 10.42 PPG - NO LOSSES OBSERVED - PRESSURIZED MUD WEIGHT IN/OUT = 9.6/9.6+ PPG, NON -PRESSURIZED MUD WEIGHT IN/OUT = 9.2/9.3+ PPG FLOWLINE TEMPERATURE = 118°F ADDING WATER AT 30-40 BPH NOVOS AND SOFTSPEED ENABLED GAS WATCH: AVERAGE BACKGROUND = 100 UNITS, MAXIMUM = 1786 UNITS TOP OF UG1 6577' MD, 4432' TVD PUMPED SWEEPS AS FOLLOWS: 6160' MD: 35 BBL WEIGHTED (1.5 PPG OVER), 50% INCREASE IN CUTTINGS Printed 1/10/2018 5:03:39PM 'All depths reported in Drillers Depths' Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* lqw North America - ALASKA - BP Page 16 of 67 Operation Summary Report Common Well Name: 5-200 _ AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 18:00 00:00 6.00 DRILL P 6,906.00 INT1 DIRECTIONAL DRILL 8-1/2" x 9-7/8" INTERMEDIATE HOLE FROM 6623' MD TO 6906' MD / 4514' TVD IN THE UG1 FORMATION - 283' IN 6 HOURS = 47 FPH WITH CONNECTIONS INSTANTANEOUS ROP = 50-200 FPH — 750 GPM, 3480-3450 PSI ON/OFF BOTTOM, 150 RPM, 8 KFT-LBS TORQUE ON BOTTOM, 6 KFT-LBS TORQUE OFF BOTTOM, 10-14 KLBS WOB - PU = 160 KLBS, SO = 98 KLBS, ROT = 122 KLBS - SURVEY EVERY STAND FOR DOGLEGS < 5°/100' - CONTINUE TO HOLD 75° INCLINATION, HOLD 308° AZIMUTH - ECD ACTUAL = 10.83 PPG, CALCULATED 10.46 PPG -NO LOSSES OBSERVED PRESSURIZED MUD WEIGHT IN/OUT = 9.6+/9.7 PPG, NON -PRESSURIZED MUD WEIGHT IN/OUT = 9.5/9.5+ PPG FLOWLINE TEMPERATURE = 116°F ADDING WATER AT 30 BPH NOVOS AND SOFTSPEED ENABLED GAS WATCH: AVERAGE BACKGROUND = 70 UNITS, MAXIMUM = 690 UNITS TOTAL OF 1 HR OF LOST TIME DUE TO NOVOS TROUBLESHOOTING OVER 24 HR PERIOD ACTUAL ON BOTTOM DRILLING TIME DURING 24 REPORT PERIOD = 15.4 HRS (64%) JAR HOURS = 31.4 HRS PUMPED SWEEPS AS FOLLOWS: 6628' MD: 35 BBL WEIGHTED (1.5 PPG OVER), 25% INCREASE IN CUTTINGS - 6738' MD: TANDEM 35 BBL LOW -VIS / 35 BBL WEIGHTED (1.5 PPG OVER), 25% INCREASE IN CUTTINGS Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Page 17 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) INT1 DIRECTIONAL DRILL 8-1/2" x 9-7/8" 11/2/2017 00:00 06:00 6.00 DRILL P 7,350.00 INTERMEDIATE HOLE FROM 6906' MD TO 7350' MD / 4631' TVD IN THE UG1 FORMATION 444' IN 6 HOURS = 74 FPH WITH I CONNECTIONS INSTANTANEOUS ROP = 25-150 FPH 750 GPM, 3490-3480 PSI ON/OFF BOTTOM, 150 RPM, 9 KFT-LBS TORQUE ON BOTTOM, 6 KFT-LBS TORQUE OFF BOTTOM, 9-14 KLBS WOB - PU - 171 KLBS, SO = 113 KLBS, ROT = 124 KLBS - SURVEY EVERY STAND FOR DOGLEGS < 5°/100' CONTINUE TO HOLD 75° INCLINATION, HOLD 308'- 310° AZIMUTH - ECD ACTUAL= 11.01 PPG, CALCULATED 10.47 PPG - NO LOSSES OBSERVED PRESSURIZED MUD WEIGHT IN/OUT = 9.6+/9.8 PPG, NON -PRESSURIZED MUD WEIGHT IN/OUT = 9.5/9.6 PPG FLOWLINE TEMPERATURE = 118*F ADDING WATER AT 30 BPH NOVOS AND SOFTSPEED ENABLED GAS WATCH: AVERAGE BACKGROUND = 90 UNITS, MAXIMUM = 360 UNITS PUMPED SWEEPS AS FOLLOWS: 7005' MD: TANDEM 35 BBL LOW -VIS / 35 BBL WEIGHTED (2.0 PPG OVER), 150% INCREASE IN CUTTINGS Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths' North America - ALASKA - BP Page 18 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 06:00 12:00 6.00 DRILL P 7,777.00 INT1 DIRECTIONAL DRILL 8-1/2" x 9-7/8" INTERMEDIATE HOLE FROM 7350' MD TO 7777' MD / 4744' TVD IN THE UG1/UG_MA FORMATIONS - 42T IN 6 HOURS = 71 FPH WITH CONNECTIONS INSTANTANEOUS ROP = 25-150 FPH 750 GPM, 3510-3500 PSI ON/OFF BOTTOM, 150 RPM, 10 KFT-LBS TORQUE ON BOTTOM, 9 KFT-LBS TORQUE OFF BOTTOM, 9-14 KLBS WOB - PU = 164 KLBS, SO = 112 KLBS, ROT = 124 KLBS - SURVEY EVERY STAND FOR DOGLEGS < 5°/100' - CONTINUE TO HOLD 75° INCLINATION, HOLD 308'- 310° AZIMUTH ECD ACTUAL= 10.9 PPG, CALCULATED 10.35 PPG NO LOSSES OBSERVED PRESSURIZED MUD WEIGHT IN/OUT = 9.6/9.7+ PPG, NON -PRESSURIZED MUD WEIGHT IN/OUT = 9.3+/9.5+ PPG FLOWLINE TEMPERATURE = 118°F ADDING WATER AT 30 BPH NOVOS AND SOFTSPEED ENABLED GAS WATCH: AVERAGE BACKGROUND = 75 UNITS, MAXIMUM = 399 UNITS PUMPED SWEEPS AS FOLLOWS: 7400' MD: TANDEM 35 BBL LOW -VIS / 35 BBL WEIGHTED (2.0 PPG OVER), 150% INCREASE IN CUTTINGS Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths' Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Page 19 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 12:00 13:00 1.00 DRILL P 7,830.00 INT1 DIRECTIONAL DRILL 8-1/2" x 9-7/8" INTERMEDIATE HOLE FROM 7777' MD TO 7830' MD / 4759' TVD IN THE UG_MA FORMATION i - 53' IN 1 HOURS = 53 FPH WITH CONNECTIONS INSTANTANEOUS ROP = 25-150 FPH 750 GPM, 3580-3500 PSI ON/OFF BOTTOM, 150 RPM, 10 KFT-LBS TORQUE ON BOTTOM, 10 KFT-LBS TORQUE OFF BOTTOM, 7-14 KLBS WOB - PU = 165 KLBS, SO = 114 KLBS, ROT = 125 KLBS - SURVEY EVERY STAND FOR DOGLEGS < 5°/100' - CONTINUE TO HOLD 75° INCLINATION, HOLD 308'- 310° AZIMUTH - ECD ACTUAL= 10.9 PPG, CALCULATED 10.35 PPG - PRESSURIZED MUD WEIGHT IN/OUT = 9.6/9.7+ PPG, NON -PRESSURIZED MUD WEIGHT IN/OUT = 9.3+/9.5+ PPG FLOWLINE TEMPERATURE= 118°F -ADDING WATER AT 30 BPH NOVOS AND SOFTSPEED ENABLED GAS WATCH: AVERAGE BACKGROUND = 50 UNITS, MAXIMUM = 50 UNITS AT 7825' MD, A PUMP PRESSURE AND FLOW OUT % DECREASE OBSERVED. PICK UP AND FLOW CHECKED WELL: STATIC. LOSSES PRIOR TO PICKING OFF BOTTOM = 32 BBLS PUMPED SWEEPS AS FOLLOWS: - 7800' MD: TANDEM 35 BBL LOW -VIS / 35 BBL WEIGHTED (2.0 PPG OVER), LOST TO HOLE Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - BP S Page 20 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 13:00 - 14:00 1.00 DRILL N 7,830.00 INT1 ESTABLISH DYNAMIC LOSS RATE, SHUT-IN WELLAND PERFORM EXHALE TEST TO DIAGNOSE WELLBORE BREATHING BRING ON PUMPS TO DETERMINE DYNAMIC LOSS RATE OF -420 BPH 14:00 - 15:00 1 1.00 DRILL 15:00 - 15:30 0.50 I DRII N 7,830.00 851.00 750 GPM, 3350 PSI, 20 RPM, 9 KFT-LBS TORQUE - 35 BBLS LOST OVER 5 MIN AFTER REACHING DRILLING RATE - LOST 137 BBLS TOTAL SHUT DOWN PUMPS AND OBSERVED RETURN FLOW = 10-14%. SHUT-IN WELL PER STANDING ORDERS AND MADE TIER 3 NOTIFICATIONS. RECEIVED AUTHORIZATION TO PERFORM EXHALE TEST. - INITIAL SHUT-IN DRILL PIPE PRESSURE _ 130 PSI, SHUT-IN CASING PRESSURE =10 PSI - LINE UPAND FILL CHOKE LINES AND MUD GAS SEPARATOR - ATTEMPT TO PERFORM EXHALE TEST WITH 1 BBL BLEED BACK THROUGH THE CHOKE - NO FLOW OBSERVED AT MUD GAS SEPARATOR - VERIFY NO PRESSURE ON CASING AND OPEN ANNULAR PREVENTER - FLUID IN STACK DROPPED -6', TOOK 1.1 BBLS FOR FILL STACK MONITOR WELLAND DETERMINE WELL TAKING FLUID INTI ATTEMPT TO DETERMINE LOSS RATES AND PUMP LCM DRILLAHEAD PILL - PUMP DOWN DRILL STRING AT 1/2 BPM, 205 PSI, 20 RPM, 9 KFT-LBS TORQUE - HOLE FILL ON AND LINED UP TO TRIP TANK WHILE PUMPING AT 1/2 BPM: NO LOSSES OR GAINS NOTED IN TRIP TANK PUMP 75 BBL, 40 PPB DRILLAHEAD LCM PILL -400 GPM, 1241 PSI ATTEMPT TO DRILLAHEAD AS LCM PILL _EXITED BIT INT1 DIRECTIONAL DRILL 8-1/2" x 9-7/8" INTERMEDIATE HOLE FROM 7830' MD TO 7851' MD / 4764' TVD IN THE UG -MA FORMATION - 21' IN 0.5 HOURS = 42 FPH WITH CONNECTIONS INSTANTANEOUS ROP = 25-150 FPH 750 GPM, 3380-3350 PSI ON/OFF BOTTOM, 150 RPM, 10 KFT-LBS TORQUE ON BOTTOM, 10 KFT-LBS TORQUE OFF BOTTOM, 8 KLBS WOB - PU = 164 KLBS, SO = 114 KLBS, ROT = 125 KLBS - ECD ACTUAL= 10.66 PPG, CALCULATED 10.35 PPG - PRESSURIZED MUD WEIGHT IN/OUT = 9.6/9.7+ PPG, NON -PRESSURIZED MUD WEIGHT IN/OUT = 9.3+/9.5+ PPG FLOWLINE TEMPERATURE= 118°F NOVOS AND SOFTSPEED ENABLED Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Page 21 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 15:30 - 19:30 4.00 DRILL N 7,851.00 INT1 CIRCULATE AND RECIPROCATE PIPE WHILE BUILDING FLUID BEFORE DRILLING AHEAD - 126 GPM, 295 PSI, 24 RPM, 7 KFT-LBS TORQUE - RECIPROCATE PIPE AT 3 FPM -WAITING ON ADDITIONAL MUD FROM MUD PLANT 19:30 00:00 4.50 DRILL P 8,200.00 INT1 DIRECTIONAL DRILL 8-1/2" x 9-7/8" INTERMEDIATE HOLE FROM 7851' MD TO 8200' MD / 4854' TVD IN THE UG_MA FORMATION 349' IN 4.5 HOURS = 77.6 FPH WITH CONNECTIONS INSTANTANEOUS ROP = 25-150 FPH 750 GPM, 3480-3465 PSI ON/OFF BOTTOM, 150 RPM, 11 KFT-LBS TORQUE ON BOTTOM, 8 KFT-LBS TORQUE OFF BOTTOM, 9-12 KLBS WOB PU = 163 KLBS, SO = 106 KLBS, ROT = 130 KLBS - SURVEY EVERY STAND FOR DOGLEGS < 5°/100' CONTINUE TO HOLD 75° INCLINATION, HOLD 308'- 310° AZIMUTH - ECD ACTUAL= 10.95 PPG, CALCULATED 10.37 PPG - PRESSURIZED MUD WEIGHT IN/OUT = 9.6/9.7+ PPG, NON -PRESSURIZED MUD WEIGHT IN/OUT = 9.3+/9.5+ PPG - FLOWLINE TEMPERATURE = 112°F -ADDING WATER AT 20 BPH NOVOS AND SOFTSPEED ENABLED GAS WATCH: AVERAGE BACKGROUND = 200 UNITS, MAXIMUM = 1700 UNITS FINGER PRINTING FLOWBACKAT EACH CONNECTION - FROM 7851'- 7945' MD: LOST 305 BBLS, FLOW BACK 120 BBLS OVER 25 MIN AT CONNECTION - FROM 7945'- 8041' MD: LOST 197 BBLS, FLOW BACK 130 BBLS OVER 25 MIN AT CONNECTION (SIMILAR FLOW OUT % AND VOLUME OVER TIME TREND) - FROM 8041'- 8136' MD: LOST 190 BBLS, FLOW BACK 138 BBLS OVER 25 MIN AT CONNECTION (SIMILAR FLOW OUT % AND VOLUME OVER TIME TREND) Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Page 22 of 67 Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 11/3/2017 00:00 01:00 1.00 DRILL P 8,200.00 INT1 DIRECTIONAL DRILL 8-1/2" x 9-7/8" INTERMEDIATE HOLE FROM 8200' MD TO 8250' MD / 4870' TVD IN THE UG—MB FORMATION - 50' IN 1 HOURS = 50 FPH WITH CONNECTIONS INSTANTANEOUS ROP = 50-180 FPH 750 GPM, 3500-3490 PSI ON/OFF BOTTOM, 150 RPM, 11 KFT-LBS TORQUE ON BOTTOM, 8 KFT-LBS TORQUE OFF BOTTOM, 9-12 KLBS WOB - PU = 163 KLBS, SO = 106 KLBS, ROT = 130 KLBS - SURVEY EVERY STAND FOR DOGLEGS < 5°/100' - PRESSURIZED MUD WEIGHT IN/OUT = 9.7/9.8 PPG, NON -PRESSURIZED MUD WEIGHT IN/OUT = 9.5+/9.1+ PPG FLOWLINE TEMPERATURE = 112°F ADDING WATER AT 20 BPH NOVOS AND SOFTSPEED ENABLED GAS WATCH: AVERAGE BACKGROUND = 92 UNITS, MAXIMUM = 135 UNITS FINGER PRINTING FLOWBACKAT EACH CONNECTION - FROM 8136'- 8231' MD: LOST 261 BBLS, FLOW BACK 161 BBLS OVER 25 MIN AT CONNECTION (SIMILAR FLOW OUT % AND VOLUME OVER TIME TREND) 01:00 01:30 0.50 DRILL N 8,250.00 INT1 TORQUE UP AND STALLED OUT ROTARYAT 8250' MD. SHUT DOWN PUMPS TO RELAX ARMS ON UNDERREAMER ATTEMPT TO PICK UP TO RESEAT BIT, PULLED 25 KLBS OVER, ATTEMPT TO STRAIGHT PULL WITH 25 KLBS OVER SEVERAL TIMES WITH NO SUCCESS. COCK JARS AND JAR WITH 25-30 KLBS OVERPULL SEVERAL TIMES WITH NO SUCCESS. COME BACK TO NEUTRAL WEIGHT, INCREASE TORQUE LIMIT TO 20 KFT-LBS AND ATTEMPT TO APPLY ROTARY, UNABLE TO FREE STRING. REPEAT PROCESS AND INCREASE OVERPULL TO 30-35 KLBS, AFTER 3 ATTEMPTS STILL UNABLE TO JAR STRING FREE COME BACK TO NEUTRAL WEIGHT AND ATTEMPT TO FAIL FORMATION BY APPLYING ROTARY AGAI N. STRING STALLED OUT WITH 20 KFT-LBS TORQUE AND CAME FREE. INCREASED PUMP RATE TO 750 GPM, 3480 PSI, 60 RPM, 8-9 KFT-LBS TORQUE AND BACKREAMED 15' SECTION CLEAN. Printed 1/10/2018 5,03:39PM *All depths reported in Drillers Depths* Printed 1/10/2018 5:03:39PM `All depths reported in Drillers Depths' North America - ALASKA - BP IVPage 23 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3 -017W0 -C: (6.876.211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:00AM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) _ (usft) 01:30 06:00 4.50 DRILL P 8,500.00 INT1 DIRECTIONAL DRILL 8-1/2" x 9-7/8" INTERMEDIATE HOLE FROM 8250' MD TO 8500' MD / 4936' TVD IN THE UG_MB2 FORMATION - 250' IN 4.5 HOURS = 55.6 FPH WITH CONNECTIONS INSTANTANEOUS ROP = 20-180 FPH 750 GPM, 3480-3465 PSI ON/OFF BOTTOM, 150 RPM, 11 KFT-LBS TORQUE ON BOTTOM, 8 KFT-LBS TORQUE OFF BOTTOM, 9-12 KLBS WOB - PU = 163 KLBS, SO = 106 KLBS, ROT = 130 KLBS - SURVEY EVERY STAND FOR DOGLEGS < 5°/100' - CONTINUE TO HOLD 75° INCLINATION, HOLD 307° AZIMUTH - ECD ACTUAL= 10.79 PPG, CALCULATED 10.37 PPG - PRESSURIZED MUD WEIGHT IN/OUT = 9.7+/9.8 PPG, NON -PRESSURIZED MUD WEIGHT IN/OUT = 9.5+/9.6 PPG FLOWLINE TEMPERATURE= 100°F ADDING WATER AT 20 BPH NOVOS AND SOFTSPEED ENABLED GAS WATCH: AVERAGE BACKGROUND = 93 UNITS, MAXIMUM = 1292 UNITS FINGER PRINTING FLOWBACKAT EACH CONNECTION - FROM 8231'- 8326' MD: LOST 204 BELS, FLOW BACK 157 BBLS OVER 20 MIN AT CONNECTION (SIMILAR FLOW OUT % AND VOLUME OVER TIME TREND) - FROM 8326'- 8422' MD: LOST 174 BBLS, FLOW BACK 129 BBLS OVER 15 MIN AT CONNECTION (SIMILAR FLOW OUT % AND VOLUME OVER TIME TREND) Printed 1/10/2018 5:03:39PM `All depths reported in Drillers Depths' Printed 1/10/2018 5:03.39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Page 24 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUO1: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 06:00 12:00 6.00 DRILL P 8,892.00 INT1 DIRECTIONAL DRILL 8-1/2" x 9-7/8" INTERMEDIATE HOLE FROM 8500' MD TO 8892' MD / 5041' TVD IN THE UG—MC / SHRADER BLUFF FORMATION - 392' IN 6 HOURS = 65.3 FPH WITH CONNECTIONS INSTANTANEOUS ROP = 20-180 FPH 750 GPM, 3610-3605 PSI ON/OFF BOTTOM, 160 RPM, 13 KFT-LBS TORQUE ON BOTTOM, 10 KFT-LBS TORQUE OFF BOTTOM, 10-15 KLBS WOB - PU = 172 KLBS, SO = 107 KLBS, ROT = 131 KLBS - SURVEY EVERY STAND FOR DOGLEGS < 5°/100' - CONTINUE TO HOLD 75° INCLINATION, HOLD 307°AZIMUTH ECD ACTUAL= 11.1 PPG, CALCULATED 10.43 PPG - PRESSURIZED MUD WEIGHT IN/OUT = 9.6+/9.8 PPG, NON-PRESSURIZED MUD WEIGHT IN/OUT = 9.6/9.5 PPG FLOWLINE TEMPERATURE = 105°F ADDING WATER AT 20 BPH NOVOS AND SOFTSPEED ENABLED GAS WATCH: AVERAGE BACKGROUND = 138 UNITS, MAXIMUM = 1876 UNITS AT 09:30: NON-PRESSURIZED MUD WEIGHT IN/OUT = 9.5/8.9 PPG, PITWATCHER NOTIFIED WSL OF > 0.4 PPG DISCREPANCY IN IN/OUT WEIGHTS. WSL CONTACTED WSUP PER BARRIER BOARD COMMUNICATION PROTOCOL. NEXT READING WAS 9.4/9.5 PPG CONTINUE TO FINGER PRINTING FLOWBACK AT EACH CONNECTION. FLOW OUT % AND VOLUME OVER TIME TRENDS CONTINUE TO FOLLOW SIMILAR PATTERN. PUMPED SWEEPS AS FOLLOWS: 8800' MD: TANDEM 40 BBL DRILLAHEAD LCM / 40 BBL BARAFIBER (5 PPB), NO CHANGE IN LOSS RATE Printed 1/10/2018 5:03.39PM *All depths reported in Drillers Depths* Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Page 25 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:OO:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (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 9,368.00 INT1 DIRECTIONAL DRILL 8-1/2" x 9-7/8" INTERMEDIATE HOLE FROM 8892' MD TO 9368' MD / 5168' TVD IN THE SHRADER BLUFF FORMATION - 476' IN 6 HOURS = 79.3 FPH WITH CONNECTIONS INSTANTANEOUS ROP = 20-180 FPH 750 GPM, 3675-3620 PSI ON/OFF BOTTOM, 160 RPM, 13 KFT-LBS TORQUE ON BOTTOM, 10 KFT-LBS TORQUE OFF BOTTOM, 10-15 KLBS WOB - PU = 184 KLBS, SO = 107 KLBS, ROT = 132 KLBS - SURVEY EVERY STAND FOR DOGLEGS < 5°/100' - CONTINUE TO HOLD 75° INCLINATION, HOLD 308'- 310° AZIMUTH - ECD ACTUAL= 10.83 PPG, CALCULATED 10.44 PPG - PRESSURIZED MUD WEIGHT IN/OUT = 9.6+/9.7 PPG, NON -PRESSURIZED MUD WEIGHT IN/OUT = 9.4+/9.3 PPG FLOWLINE TEMPERATURE = 110°F ADDING WATER AT 20 BPH NOVOS AND SOFTSPEED ENABLED GAS WATCH: AVERAGE BACKGROUND = 183 UNITS, MAXIMUM = 3175 UNITS CONTINUE TO FINGER PRINTING FLOWBACK AT EACH CONNECTION. FLOW OUT % AND VOLUME OVER TIME TRENDS CONTINUE TO FOLLOW SIMILAR DECREASING PATTERN. PUMPED SWEEPS AS FOLLOWS: 9100' MD: 40 BBL WEIGHTED (2.0 PPG OVER), NO SIGNIFICANT INCREASE IN CUTTINGS Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Operation Summary Report Page 26 of 67 Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 18:00 00:00 6.00 DRILL P 9,840.00 INT1 DIRECTIONAL DRILL 8-1/2" x 9-7/8" INTERMEDIATE HOLE FROM 9368' MD TO 9840' MD / 5294' TVD IN THE SHRADER BLUFF FORMATION - 472' IN 6 HOURS = 78.7 FPH WITH CONNECTIONS INSTANTANEOUS ROP = 20-180 FPH 750 GPM, 3750-3710 PSI ON/OFF BOTTOM, 160 RPM, 11 KFT-LBS TORQUE ON BOTTOM, 14 KFT-LBS TORQUE OFF BOTTOM, 11-15 KLBS WOB - PU = 190 KLBS, SO = 108 KLBS, ROT = 136 KLBS SURVEY EVERY STAND FOR DOGLEGS < 5°/100' - CONTINUE TO HOLD 75° INCLINATION, HOLD 308° - 310° AZIMUTH - ECD ACTUAL = 10.81 PPG, CALCULATED 10.45 PPG - PRESSURIZED MUD WEIGHT IN/OUT = 9.6+/9.7 PPG, NON -PRESSURIZED MUD WEIGHT IN/OUT = 9.4/9.2+ PPG FLOWLINE TEMPERATURE = 112°F ADDING WATER AT 20 BPH NOVOS AND SOFTSPEED ENABLED GAS WATCH: AVERAGE BACKGROUND = 138 UNITS, MAXIMUM = 3809 UNITS NOVOS UTILIZATION AT 75% FOR THE DAY, SOFTSPEED UTILIZATION AT 95% FOR THE DAY WHEN ROTATING - ACTUAL ON BOTTOM DRILLING TIME DURING 24 REPORT PERIOD = 15.5 HRS (65%) JAR HOURS = 57.8 HRS AT 19:45: NON -PRESSURIZED MUD WEIGHT IN/OUT = 9.5/8.9 PPG, PITWATCHER NOTIFIED WSL OF > 0.4 PPG DISCREPANCY IN IN/OUT WEIGHTS. WSL NOTIFIED WSUP PER BARRIER BOARD COMMUNICATION PROTOCOL. NEXT READING WAS 9.5/9.4 PPG CONTINUE TO FINGER PRINTING FLOWBACK AT EACH CONNECTION. FLOW OUT % AND VOLUME OVER TIME TRENDS CONTINUE TO FOLLOW SIMILAR DECREASING PATTERN. PUMPED SWEEPS AS FOLLOWS: - 9490' MD: TANDEM 35 BBL LOW -VIS / 35 BBL WEIGHTED (2.0 PPG OVER), NO SIGNIFICANT INCREASE IN CUTTINGS Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Page 27 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) _ (usft) 11/4/2017 00:00 06:00 6.00 DRILL P 10,321.00 INT1 DIRECTIONAL DRILL 8-1/2" x 9-7/8" INTERMEDIATE HOLE FROM 9840' MD TO 10,321' MD / 5417' TVD IN THE SHRADER BLUFF FORMATION - 481' IN 6 HOURS = 80 FPH WITH CONNECTIONS INSTANTANEOUS ROP = 20-180 FPH 750 GPM, 3750-3710 PSI ON/OFF BOTTOM, 160 RPM, 11 KFT-LBS TORQUE ON BOTTOM, 14 KFT-LBS TORQUE OFF BOTTOM, 11-15 KLBS WOB PU = 190 KLBS, SO = 108 KLBS, ROT = 136 KLBS SURVEY EVERY STAND FOR DOGLEGS < 5°/100' - CONTINUE TO HOLD 75° INCLINATION, HOLD 307° AZIMUTH - ECD ACTUAL= 11.3-11.4 PPG, CALCULATED 10.45 PPG - PRESSURIZED MUD WEIGHT IN/OUT = 9.6+/9.7+ PPG, NON -PRESSURIZED MUD WEIGHT IN/OUT = 9.5/9.5+ PPG FLOWLINE TEMPERATURE = 112°F ADDING WATER AT 20 BPH NOVOS AND SOFTSPEED ENABLED GAS WATCH: AVERAGE BACKGROUND = 202 UNITS, MAXIMUM = 3283 UNITS WELLBORE BREATHING: CONTINUE FINGER PRINTING FLOWBACKAT EACH CONNECTION. FLOW OUT % AND VOLUME OVER TIME TRENDS CONTINUE TO FOLLOW SIMILAR DECREASING PATTERN. Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* Printed 1/10/2018 5:03:39PM 'All depths reported in Drillers Depths' North America - ALASKA - BP Page 28 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 06:00 12:00 6.00 DRILL P 10,796.00 INTI DIRECTIONAL DRILL 8-1/2" x 9-7/8" INTERMEDIATE HOLE FROM 10,321' MD TO 10,796' MD IN THE SHRADER BLUFF FORMATION - 475' IN 6 HOURS = 79 FPH WITH CONNECTIONS INSTANTANEOUS ROP = 120-150 FPH 750 GPM, 3950-4125 PSI ON/OFF BOTTOM, 160 RPM, 14.5-16.5 KFT-LBS TORQUE ON BOTTOM, 13-15 KFT-LBS TORQUE OFF BOTTOM, 10-16 KLBS WOB - SURVEY EVERY STAND FOR DOGLEGS < 5°/100'. NO BACKREAMING AT CONNECTIONS. - CONTINUE TO HOLD 75° INCLINATION, HOLD 307° AZIMUTH - ECD ACTUAL= 11.2-11.5 PPG, CALCULATED 10.5 PPG - PRESSURIZED MUD WEIGHT IN/OUT = 9.6 PPG, NON -PRESSURIZED MUD WEIGHT IN/OUT = 9.3-9.4 PPG FLOWLINE TEMPERATURE= 115°F LOSSES = -35 BPH DYNAMIC NOVOS AND SOFTSPEED ENABLED GAS WATCH: BACKGROUND = 250-400 UNITS, MAXIMUM = 2567 UNITS WELLBORE BREATHING: CONTINUE FINGER PRINTING FLOWBACKAT EACH CONNECTION. FLOW OUT % AND VOLUME OVER TIME TRENDS CONTINUE TO FOLLOW SIMILAR DECREASING PATTERN. Printed 1/10/2018 5:03:39PM 'All depths reported in Drillers Depths' Printed 1/10/2018 5*03:39PM `All depths reported in Drillers Depths' North America - ALASKA - BP Page 29 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211,00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUO1: USA00000172 Active datum: S-200AActual @82.32usft (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 11,269.00 INT1 DIRECTIONAL DRILL 8-1/2" x 9-7/8" INTERMEDIATE HOLE FROM 10,796' MD TO 11,269' MD IN THE SHRADER BLUFF FORMATION - 500' IN 6 HOURS = 83 FPH WITH CONNECTIONS INSTANTANEOUS ROP = 150 FPH 750 GPM, 4075-4250 PSI ON/OFF BOTTOM, 160 RPM, 15.5-7.5 KFT-LBS TORQUE ON BOTTOM, 13.5-15.5 KFT-LBS TORQUE OFF BOTTOM, 8-16 KLBS WOB SURVEY EVERY STAND FOR DOGLEGS < 15°/100'. NO BACKREAMING AT CONNECTIONS. - CONTINUE TO HOLD 75° INCLINATION, HOLD 307° AZIMUTH - ECD ACTUAL= 11.3-11.5 PPG, CALCULATED 10.5 PPG - PRESSURIZED MUD WEIGHT IN/OUT = 9.6 PPG, NON -PRESSURIZED MUD WEIGHT IN/OUT = 9.3-9.4 PPG FLOWLINE TEMPERATURE = 116°F LOSSES = -35 BPH DYNAMIC NOVOS AND SOFTSPEED ENABLED GAS WATCH: BACKGROUND = 225-300 UNITS, MAXIMUM = 2500 UNITS WELLBORE BREATHING: CONTINUE FINGER PRINTING FLOWBACKAT EACH CONNECTION. FLOW OUT % AND VOLUME OVER TIME TRENDS CONTINUE TO FOLLOW SIMILAR DECREASING PATTERN. Printed 1/10/2018 5*03:39PM `All depths reported in Drillers Depths' North America - ALASKA - BP Operation Summary Report Page 30 of 67 Common Well Name: 5-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 18:00 - 22:00 4.00 DRILL P 11,544.00 INT1 DIRECTIONAL DRILL 8-1/2" x 9-7/8" INTERMEDIATE HOLE FROM 11,269' MD TO 11,544' MD IN THE SHRADER BLUFF FORMATION - 276' IN 6 HOURS = 69 FPH WITH CONNECTIONS - INSTANTANEOUS ROP = 50-150 FPH (REDUCE ROPAT MOMENTS TO MAINTAIN ECD < 1 PPG OVER CLEANHOLE) - 750 GPM, 4075-4250 PSI ON/OFF BOTTOM, 160 RPM, 15.5-7.5 KFT-LBS TORQUE ON BOTTOM, 13.5-15.5 KFT-LBS TORQUE OFF BOTTOM, 8-16 KLBS WOB - SURVEY EVERY STAND FOR DOGLEGS < 5°/100'. NO BACKREAMING AT CONNECTIONS. -CONTINUE TO HOLD 75° INCLINATION, HOLD 307° AZIMUTH - ECD ACTUAL= 11.35-11.5 PPG, CALCULATED 10.6 PPG - PRESSURIZED MUD WEIGHT IN/OUT = 9.6 PPG, NON -PRESSURIZED MUD WEIGHT IN/OUT = 9.3-9.4 PPG FLOWLINE TEMPERATURE = 118°F LOSSES = -35 BPH DYNAMIC NOVOS AND SOFTSPEED ENABLED GAS WATCH: BACKGROUND = 150-300 UNITS, MAXIMUM = 2810 UNITS ACTUAL DRILLING/RTOTATING TIME FOR 24 HOUR REPORT PERIOD = 16.1 HRS (67%) WELLBORE BREATHING: CONTINUE FINGER PRINTING FLOWBACKAT EACH CONNECTION. FLOW OUT % AND VOLUME OVER TIME TRENDS CONTINUE TO FOLLOW SIMILAR DECREASING PATTERN. ELECT TO PERFORM SHORT TRIP TO CHECK HOLE CONDITIONS AND REDUCE ECDS PRIOR TO COLVILLE FORMATION 22:00 00:00 2.00 DRILL P 11,544.00 INT1 CIRCULATE HOLE CLEAN WITH 3X BOTTOMS UP IN PREPARATION FOR SHORT TRIP - 750 GPM, 4025-4150 PSI, 60 RPM, 13-14.5 FT -LBS TRQ, RECIPROCATE FULL STAND AT 200 FPH - COMPLETE 370 BBL DILUTION WITH NEW MUD TO ASSIST WITH THINNING BACK MUD SYSTEM - CLEANHOLE ECD = 10.6 PPG, ACTUAL = 11.2 PPG PUMP (2) 40 BBL 3 PPG OVER WEIGHTED SWEEPS SURFACE TO SURFACE WITH 50% INCREASE IN RETURNS 11/5/2017 00:00 00:30 0.50 DRILL P 11,544.00 INT1 CONTINUE TO CIRCULATE HOLE CLEAN WITH 3X BOTTOMS UP IN PREPARATION FOR SHORT TRIP - 750 GPM, 4025-4150 PSI, 60 RPM, 13-14.5 FT -LBS TRQ, RECIPROCATE FULL STAND AT 200 FPH - CLEANHOLE ECD = 10.6 PPG, ACTUAL = 11.2 PPG Printed 1/10/2018 5:03:39PM 'All depths reported in Drillers Depths` North America - ALASKA - BP Operation Summary Report Page 31 of 67 Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3 -017W0 -C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:00AM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 00:30 - 02:00 2.50 DRILL P 11,544.00 INT1 PERFORM A SERIES OF EXTENDED FLOW CHECKS PRIOR TO PERFORMING SHORT TRIP BACK TO 9-5/8" CASING SHOE: ALLOW WELL TO RELAX AND FLOW BACK. FLOW OUT % AND VOLUME OVER TIME TRENDS SHOWA SIMILAR DECREASING TREND AS PREVIOUS CONNECTION FINGERPRINTS. AFTER 30 MIN, FLOW RATE OUT OF THE WELL MEASURED WITH VIS CUP = 2.5 BBLS/HR. TOTAL VOLUME BLED BACK OVER 30 MIN = 92 BBLS. PULL 1 STAND AT 25 FPM (FROM 11,544' MD TO 11,448' MD) TO MOVE PIPE AND CONTINUE MONITORING WELL. WELLAPPEARED TO BE SWABBING WHILE PULLING STAND. ALLOW WELL TO CONTINUE RELAXAND FLOW BACK FOR 20 MIN. FLOW RATE OUT OF THE WELL MEASURED WITH VIS CUP = 2.5 BBLS/HR WITH A DECREASING TREND. TOTAL VOLUME BLED BACK OVER 20 MIN = 2.5 BBLS. PULL 1 MORE STAND AT 25 FPM (FROM 11,448' MD TO 11,348' MD), BRINGING BIT INTO 9-7/8" UNDER REAMED HOLE SECTION. WELL APPEARED TO BE SWABBING WHILE PULLING STAND. ALLOW WELL TO CONTINUE TO RELAX AND FLOW BACK. ESTABLISH A DECREASING TREND WITH FLOW BACK RATE OVER 45 MIN: - OVER FIRST 15 MIN INTERVAL, FLOW OUT RATE MEASURED WITH VIS CUP = 2.3 BBLS/HR - OVER SECOND 15 MIN INTERVAL, FLOW OUT RATE MEASURED WITH VIS CUP = 2.0 BBLS/HR - OVER THIRD 15 MIN INTERVAL, FLOW OUT RATE MEASURED WITH VIS CUP = 1.8 BBLS/HR DISCUSS WITH ODE, WSUP AND WOM. AGREE ON PLAN FORWARD TO CONTINUE WITH SHORT TRIP MONITORING AFTER EVERY 5 STANDS TO VERIFY WELL FLOW BACK TREND CONTINUES TO DECREASE. STOP POINTS AGREED UPON IF WELL CONTINUES TO SWAB WHILE PULLING, FLOW BACK TREND SHOWS SIGNS OF STABILIZATION OR INCREASING TREND OR HOLE CONDITIONS CHANGE. Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Operation Summary Report Page 32 of 67 Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 02:00 - 10:00 8.00 DRILL P 11 544.00 INT1 PULL OUT OF THE HOLE ON ELEVATORS 10:00 - 10:30 0.50 10:30 - 12:30 2.00 FROM 11,348' MD TO 2748' MD PULL 5 STANDS ON ELEVATORS TO 10,874' MD AND MONITOR THE WELL FOR 10 MIN WELL NOT TAKING CORRECT FILL. AFTER 5 MIN, WELL STATIC AND NOT BREATHING BACKANY FLUID CONTINUE TO PULL ON ELEVATORS TO 8100' MD, STOPPING EVERY 5 STANDS TO MONITOR FLOW FOR 10 MIN WELL NOT TAKING CORRECT FILL. WELL TAKING SMALLAMOUNT OF FLUID DURING FLOW CHECKS FROM 9800' TO 8100' MD, < 0.5 BBLS PULLING SPEEDS PER WELL PROGRAM SWAB/SURGE MODELING 25 FPM FROM 11,544' MD - 10,500' MD 30 FPM FROM 10,500' MD - 8000' MD 40 FPM FROM 8000' MD - 7000' MD 50 FPM FROM 7000' MD - 6000' MD 60 FPM FROM 6000' MD - 5000' MD 80 FPM FROM 5000' MD - 9-5/8" WINDOW NO HOLE ISSUES NOTED WHILE PULLING THROUGH 9-7/8" HOLE SECTION TO THE 9-5/8" CASING WINDOW. DRILL P 11,544.00 INT1 DROP THE BALLTO LOCKTHE UNDERREAMER CLOSED PER THE NOV REP AND CIRCULATE A BOTTOMS UP 750 GPM, 2753 PSI DRILL P 11,544.00 INT1 PULL OUT OF THE HOLE ON ELEVATORS FROM 2748' MD TO 400' MD 12:30 14:30 2.00 DRILL P 1430 - 1530 1.00 DRILL P MONITOR WELL FOR 10 MIN; STATIC MUD WEIGHT IN/OUT = 9.7 PPG PU 94 KLBS, SO 94 KLBS AT 2753' MD PULLAT 110 FPM 11,544.00 INT1 PULL AND LAY DOWN 8-1/2" x 9-7/8" RSS AND UNDERREAMER ASSEMBLY FROM 400' MD - MONITOR WELL FOR 10 MIN PRIOR TO PULLING NON-SHEARABLES ACCROSS THE STACK; STATIC RACK BACK HWDP LAY DOWN NM COLLARS, STABILIZERS, MWD COMPONENTS AND BIT BIT GRADE: 1 -1 - BT - A - X - I - CT - TD UNDERREAMER GRADE: 2 - 1 - BT - P - X - I - CT 11,544.00 INT1 CLEAN AND CLEAR RIG FLOOR Printed 1/10/2018 5:03:39PM 'All depths reported in Drillers Depths' North America - ALASKA - BP Operation Summary Report Page 33 of 67 Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00 OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: 5-200A Actual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 15:30 1630 1.00 BOPSUR P 11,544.00 INTI RIG UP TO TEST BOPE - DRAIN STACK, BUILD 7" TEST JOINT AND PULL WEAR RING SIMOPS: SUSPECT POTENTIAL WEAR/DAMAGE TO ANNULAR ELEMENT. CLOSE BLIND/SHEAR RAMS, RUN IN WITH JOINT OF 7", 26 #/FT CASING AND CLOSE ANNULAR ON JOINT. OPEN ANNULAR AND PULL OUT CASING JOINT. OBSERVE DIMPLING AND DAMAGE TO CASING JOINT WHERE ELEMENT CLOSED ON IT. 1630 2030 4.00 BOPSUR N 11,544.00 INT1 CHANGE OUT ANNULAR PREVENTER ELEMENT BLOW DOWN LINES AND RUN IN RAM LOCKS ON BLIND/SHEAR RAMS BLEED OFF ACCUMULATOR REMOVEANNULAR BONNET CAPAND PULL ELEMENT CLEAN OUT SEAL RING, GREASE AND INSTALL NEW ELEMENT RE -INSTALL BONNET CAP AND TORQUE ALL FLANGE NUTS RE-ENERGIZE ACCUMULATOR PERFORM ASSURANCE TEST ON 7", 26 #/FT CASING JOINT: NO DAMAGE NOTED ON JOINT AFTER CLOSING ANNULAR ELEMENT 3X 20:30 22:00 1.50 BOPSUR P 11,544.00 INT1 RIG UP TO TEST BOPE INSTALL TEST PLUG AND RUN IN 2 LOCK -DOWNS RIG UP TO IA WITH CHARGE PUMP TO KEEP HOLE FULL WHILE TESTING BOPE FILL UP SYSTEM AND PURGE AIR PERFORM SHELL TEST WITH 7" TEST JOINT AND ANNULAR PREVENTER 250/3500 PSI: GOOD TEST. 22:00 00:00 2.00 BOPSUR P 11,544.00 INT1 TEST BOPE TO 250 PSI LOW, 3500 PSI HIGH FOR 5 CHARTED MINUTES EACH PER BP AND AOGCC REQUIREMENTS TEST WITH 7", 5" AND 4" TEST JOINTS TEST ALARMS, PVT AND FLOW SHOW ALL TESTS PASS, SEE ATTACHED TEST CHARTS - TEST WITNESS BYAOGCC REP BRIAN BIXBY, WSLAND RIG MANAGER 11/6/2017 00:00 03:30 3.50 BOPSUR P 11,544.00 INT1 CONTINUE TO TEST BOPE TO 250 PSI LOW, 3500 PSI HIGH FOR 5 CHARTED MINUTES EACH PER BP AND AOGCC REQUIREMENTS - ALL TESTS PASS, SEE ATTACHED TEST CHARTS - TEST WITNESS BYAOGCC REP BRIAN BIXBY, WSLAND RIG MANAGER 03:30 05:00 1.50 BOPSUR P 11,544.00 INTI RIG DOWN AND BLOW DOWN ALL TEST EQUIPMENT PULL TEST PLUG AND RUN IN 9-1/16" ID WEAR RING. Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* Printed 1/10/2018 5:03:39PM 'All depths reported in Drillers Depths' North America - ALASKA - BP49 Page 34 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor. PARKER DRILLING CO. BPU01: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs (hr) Task Code NPT Total Depth Phase (usft) Description of Operations 05:00 - 07:30 2.50 DRILL P 11,544.00 INTI MAKE UP AND RUN IN THE HOLE WITH BHA #6, 8-1/2" RSS / UNDERREAMER DRILLING BHA TO 471' MD HYCALOG 616-J1 D PDC BIT WITH GR@BIT/G R/RES/DI R/PWDNSS/CO-P I LOT/AN DERREAMER RIH ON ELEVATORS, PICKING UP TOOLS FROM PIPE SHED PLUG IN AND UPLOAD TOOL SHALLOW HOLE TEST TOOLS AT 471' MD MUD WT IN/OUT = 9.7 PPG 07:30 14:00 6.50 DRILL P 11,544.00 INT1 RUN IN HOLE WITH 8-1/2" RSS DRILLING BHA FROM 471r MD TO 11,417' MD ON ELEVATORS FILL PIPE EVERY 2000' MD PU 92 KLBS, SO 92 KLBS AT 2550' MD MUD WT IN/OUT = 9.7 PPG NO ISSUES RUNNING BHA THROUGH 9-5/8" CASING WINDOW NO HOLE ISSUES NOTED WHILE RUNNING IN. 14 00 16:30 2.50 DRILL P 11,544.00 INT1 CIRCULATE A BOTTOMS UP - STAGE UP PUMPS TO 546 GPM, 2950 PSI, 50 RPM, 15 KFT-LBS TORQUE PU 186 KLBS, SO 107 KLBS, ROT 144 KLBS RECIPROCATE PIPE FULL 90' 80 BPH DYNAMIC LOSS RATE JUST BEFORE FULL BOTTOMS UP STROKES, 3% LELALARM TRIGGERED WITH GAS AND LARGE AMOUNT OF FINE CUTTINGS ACROSS THE SHAKERS. SHUT DOWN PUMPS TO PERFORM A FLOW CHECK. WELLAPPEARED TO BE BREATHING SIMILAR TO WHEN DRILLED. GAS IN AIR MONITORS INDICATED AN INCREASE TO 5% LEL. SHUT-IN WELL. Printed 1/10/2018 5:03:39PM 'All depths reported in Drillers Depths' North America - ALASKA - BP M Page 35 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON)Start Date: 10/24/2017 End Date: 11/24/2017 t X3-017WO-C: (6,876,211,00) -- -- ___ ___ _ - Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: 5-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 16:30 21:30 5.00 DRILL N 11,544.00 INT1 SHUT-IN WELL PER STANDING ORDERS, MAKE NOTIFICATIONS AND ESTABLISH WELLBORE BREATHING TRENDS CLOSED ANNULAR PREVENTER AND OPENED HCR TO A CLOSED CHOKE - SIDPP = 250 PSI, SICP = 180 MADE TIER 3 NOTIFICATIONS AND RECEIVED AUTHORIZATION TO PERFORM EXHALE TEST IN 1 BBL INCREMENTS FILLED CHOKE LINES AND MUD GAS SEPARATOR - ATTEMPTED TO BLEED BACK 1 BBL TO THE TRIP TANK THROUGH THE MGS; 6 BBLS BACK IN -1 MIN NOTIFY WSUP OF RESULT AND LINE UP TO CIRCULATE REMAINDER OF BOTTOMS UP THROUGH THE CHOKE AND MUD GAS SEPARATOR, HOLDING 100 PSI BACK PRESSURE PUMP AT 3.7 BPM FOR 30 MIN TO CIRCULATE OUT GAS AT SURFACE DRILL PIPE PRESSURE = 390 PSI, CASING PRESSURE = 130 PSI WITH OPEN CHOKE LOST 48 BBLS TO WELL AND UNABLE TO HOLE 100 PSI BACK PRESSURE NOTIFY WSUP OF RESULTAND RECEIVE AUTHORIZATION TO PERFORM AN EXTENDED EXHALE TEST WITH LARGER BLEED BACK VOLUMES. BLEED OFF 4 BBLS IN TWO 2 BBL INCREMENTS; SIDPP AND SICP BOTH WENT DOWN 40 PSI - BLEED OFF 8 BBLS IN TWO 4 BBL INCREMENTS; SIDPP AND SICP BOTH WENT DOWN 60 PSI - BLEED OFF 16 BBLS IN TWO 8 BBL INCREMENTS; SIDPP AND SICP BOTH WENT DOWN 90 PSI - TIME TO BLEED OF CONTINUES TO INCREASE (DECREASING RATE OF FLOW BACK) AND SHUT-IN PRESSURES CONTINUE TO STABILIZE LOWER WITH EACH BLEED. NOTIFY WSUP OF RESULT OF BLEED OFF AND RECEIVE AUTHORIZATION TO OPEN CHOKE, BLEED OFF WELLAND OPEN ANNULAR - BLED BACK 10.2 BBLS TO NO -FLOW CONDITION - OPEN ANNULAR PREVENTER AND BLOW DOWN CHOKE AND MUD GAS SEPARATOR Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Operation Summary Report Page 36 of 67 Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 21:30 23:00 1.50 DRILL P 11,544.00 INT1 CIRCULATE A BOTTOMS UP - STAGE UP PUMPS TO 700 GPM, 3950 PSI, 50 RPM, 15 KFT-LBS TORQUE PU 186 KLBS, SO 107 KLBS, ROT 144 KLBS — RECIPROCATE PIPE FULL 90' 60 BPH DYNAMIC LOSS RATE OBSERVED 5% LEL AT SHAKERS AT BOTTOMS UP: NOTIFIED WSUP OF GAS TO SURFACE 23:00 23:30 0.50 DRILL P 11,544.00 INT1 WASH TO BOTTOM FINGER PRINTING FLOWBACKAT CONNECTIONS TO ESTABLISH FLOW BACK TREND FOR DRILLING AHEAD FROM 11,417' MD TO 11,544' MD 700 GPM, 3950 PSI, 50 RPM, 15 KFT-LBS TORQUE PU 186 KLBS, SO 107 KLBS, ROT 144 KLBS 60 BPH DYNAMIC LOSS RATE FLOW OUT % AND VOLUME OVER TIME TRENDS CONTINUE TO FOLLOW SIMILAR DECREASING PATTERN TO WHAT WAS OBSERVED WHEN DRILLING ACROSS THIS DEPTH. 23:30 00:00 0.50 DRILL P 11 555.00 INT1 DIRECTIONAL DRILL 8-1/2" x 9-7/8" INTERMEDIATE HOLE FROM 11,544' MD TO 11,555' MD / 5752' TVD IN THE CM3 FORMATION - 700 GPM, 3850-3850 PSI ON/OFF BOTTOM, 120 RPM, 18 KFT-LBS TORQUE ON BOTTOM, 15 KFT-LBS TORQUE OFF BOTTOM, 8 KLBS WOB - PU = 197 KLBS, SO = 115 KLBS, ROT = 145 KLBS SURVEY EVERY STAND FOR DOGLEGS < 5°/100' - ECD ACTUAL = 11.12 PPG, CALCULATED 10.6 PPG - PRESSURIZED MUD WEIGHT IN/OUT = 9.6+/9.7 PPG, NON -PRESSURIZED MUD WEIGHT IN/OUT = 9.6/9.5 PPG - ACTUAL ON BOTTOM DRILLING TIME DURING 24 REPORT PERIOD = 0.1 HRS - JAR HOURS = 0.1 HRS AFTER DRILLING 11', TO 11,555' MD, PICK UP AND PUMP DOWN ANDERREAMER ACTIVATION BALL PER NOV REP - 400 GPM, 1620 PSI, 30 RPM, 16 KFT-LBS TORQUE -ACTIVATE UNDERREAMER, ESTABLISH PARAMETERS AND PERFORM LEDGE TEST ON NEW HOLE PER NOV REP. Printed 1/10/2018 5:03.39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Operation Summary Report Common Well Name: S-200 Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 AFE No X3 -017W0 -C: (6,876,211.00) Page 37 of 67 Project: Prudhoe Bay ;Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:00AM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 11/7/2017 00:00 00:30 0.50 DRILL P 11,594.00 INT1 DIRECTIONAL DRILL 8-1/2" x 9-7/8" INTERMEDIATE HOLE FROM 11,555' MD TO 11,594' MD IN THE CM3 FORMATION - 700 GPM, 3850-3850 PSI ON/OFF BOTTOM, 120 RPM, 18 KFT-LBS TORQUE ON BOTTOM, 15 KFT-LBS TORQUE OFF BOTTOM, 8 KLBS WOB - PU = 197 KLBS, SO = 115 KLBS, ROT = 145 KLBS - ECD ACTUAL= 11.12 PPG, CALCULATED 10.6 PPG PRESSURIZED MUD WEIGHT IN/OUT = 9.6+/9.7 PPG, NON -PRESSURIZED MUD WEIGHT IN/OUT = 9.5+/9.5 PPG ADDING WATER AT 20 BPH NOVOS AND SOFTSPEED ENABLED 00:30 03:30 3.00 DRILL N 11,594.00 INT1 TROUBLESHOOT AND REPLACE CRACKED SUCTION POD ON MUD PUMP #2, POD #2 CIRCULATE AT 350 GPM, 1300 PSI, 60 RPM, 15-17 KFT-LBS TORQUE RECIPROCATE PIPE 30' DYNAMIC LOSS RATE = 10 BPH 03:30 07:00 3.50 DRILL P 11,594.00 INT1 DIRECTIONAL DRILL 8-1/2" x 9-7/8" INTERMEDIATE HOLE FROM 11,594' MD TO 11,830' MD / 5804' TVD IN THE CM3 FORMATION 156' IN 2.5 HOURS = 62.4 FPH WITH CONNECTIONS INSTANTANEOUS ROP = 90-150 FPH 750 GPM, 4110-4100 PSI ON/OFF BOTTOM, 160 RPM, 16 KFT-LBS TORQUE ON BOTTOM, 15 KFT-LBS TORQUE OFF BOTTOM, 15 KLBS WOB PU = 190 KLBS, SO = 108 KLBS, ROT = 136 KLBS - SURVEY EVERY STAND FOR DOGLEGS < 5°/100' - CONTINUE TO HOLD 75° INCLINATION, HOLD 308° AZIMUTH - ECD ACTUAL = 10.95 PPG, CALCULATED 10.6 PPG - PRESSURIZED MUD WEIGHT IN/OUT = 9.6+/9.6+ PPG, NON -PRESSURIZED MUD WEIGHT IN/OUT = 9.5/9.5 PPG FLOWLINE TEMPERATURE = 89°F ADDING WATER AT 20 BPH DYNAMIC LOSS RATE = 20 BPH NOVOS AND SOFTSPEED ENABLED CONTINUE TO FINGER PRINT FLOWBACKAT EACH CONNECTION. FLOW OUT % AND VOLUME OVER TIME TRENDS CONTINUE TO FOLLOW SIMILAR DECREASING PATTERN. 07.00 10:00 3.00 DRILL P 11,594.00 INT1 DISCUSS WELL CONTROL CONTINGENCY PLANS WITH ANCHORAGE OFFICE (BULLHEADING VS DRILLER'S METHOD) - CIRCULATE AT 750 GPM, 3880 PSI, 60 RPM WITH 14K TQ, RECIPROCATE PIPE 90' Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths' North America - ALASKA - BP Page 38 of 67 Operation Summary Report r Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00 OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. _ BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth ''I Phase Description of Operations (hr) (usft) P 12,211.00 INT1 DIRECTIONAL DRILL 8-1/2" x 9-7/8" 10:00 - 14:00 4.00 DRILL INTERMEDIATE HOLE FROM 11,830' MD TO 12,211' MD IN THE CM2 FORMATION 381' IN 8 HOURS = 95 FPH WITH CONNECTIONS INSTANTANEOUS ROP = 90-120 FPH - 700 - 750 GPM, 4150-4020 PSI ON/OFF BOTTOM, 160 RPM, 18 KFT-LBS TORQUE ON BOTTOM, 15 KFT-LBS TORQUE OFF BOTTOM, 15 KLBS WOB - PU = 223 KLBS, SO = 110 KLBS, ROT = 146 KLBS - SURVEY EVERY STAND FOR DOGLEGS < 5°/100' - CONTINUE TO HOLD 7$° INCLINATION, HOLD 308° AZIMUTH 'ECD ACTUAL= 11.04 PPG, CALCULATED 10.6 PPG PRESSURIZED MUD WEIGHT IN/OUT = 9.6+/9.6+ PPG, NON -PRESSURIZED MUD WEIGHT IN/OUT = 9.5/9.5 PPG — FLOWLINE TEMPERATURE = 89*F ADDING WATER AT 20 BPH = DYNAMIC LOSS RATE = 20 BPH NOVOS AND SOFTSPEED ENABLED 40 BBL LOW VIS / WEIGHTED SWEEP AT 12,117' MD- 10% INCREASE IN CUTTINGS AT BOTTOMS UP - CONTINUE TO FINGER PRINT FLOWBACKAT EACH CONNECTION. FLOW OUT % AND VOLUME OVER TIME TRENDS CONTINUE TO FOLLOW SIMILAR DECREASING PATTERN. 14:00 - 15:00 1.00 DRILL P f 12,211.00 INT1 CHANGE OUT DISCHARGE VALVE AND SEAT i I I I I I ON MUD PUMP #2 Printed 1/10/2018 5:03:39PM *Ali depths reported in Drillers Depths* Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Page 39 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Daterrime: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. _ BPUOI: USAD0000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 15:00 00:00 9.00 DRILL P 12,872.00 INTI DIRECTIONAL DRILL 8-1/2" x 9-7/8" INTERMEDIATE HOLE FROM 12,211' MD TO 12,872' MD IN THE CM2 FORMATION (661' IN 9 HOURS = 73 FPH WITH CONNECTIONS) INSTANTANEOUS ROP = 90-120 FPH 700 GPM, 4250-4020 PSI ON/OFF BOTTOM, 160 RPM, 18 KFT-LBS TORQUE ON BOTTOM, - 15 KFT-LBS TORQUE OFF BOTTOM, 15 KLBS WOB PU = 227 KLBS, SO = 111 KLBS, ROT = 148 KLBS - SURVEY EVERY STAND FOR DOGLEGS < 5°/100' CONTINUE TO HOLD 75° INCLINATION, HOLD 308° AZIMUTH' ECD ACTUAL= 11.31 PPG, CALCULATED 10.4 PPG PRESSURIZEDMUD WEIGHT IN/OUT = 9.6+/9.6+ PPG, NON -PRESSURIZED MUD WEIGHT IN/OUT = 9.5/9.5 PPG DYNAMIC LOSS RATE = 15-20 BPH - NOVOS AND SOFTSPEED ENABLED 40 BBL LOW VIS / WEIGHTED SWEEP AT 12,782' MD- 10% INCREASE IN CUTTINGSAT BOTTOMS UP. ACTUAL DRILLING HOURS FOR PAST 24 HOUR REPORTING PERIOD = 12.3 HOURS (72%) CONTINUE TO FINGER PRINT FLOWBACKAT EACH CONNECTION. FLOW OUT %AND VOLUME OVER TIME TRENDS CONTINUE TO FOLLOW SIMILAR DECREASING PATTERN. Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Page 40 of 67 Operation Summary Report Common Well Name: 5 200 - AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3 -017W0 -C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12.00:00AM Rig Release: 11/27/2017 Rig Contractor. PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations -- — -(hr) -- i (usft) 00: 11/8/2017 00 04:30 4.50 DRILL P 13,155.00 INTI DIRECTIONAL DRILL 8-1/2" x 9-7/8" INTERMEDIATE HOLE FROM 12872' MD TO 13155' MD IN THE CM2 FORMATION (283' IN 4.5 HOURS = 63 FPH WITH CONNECTIONS) - INSTANTANEOUS ROP = 90-150 FPH i - 675 GPM, 4150-4300 PSI ON/OFF BOTTOM, 150-180 RPM, 20-21.5 KFT-LBS TORQUE ON BOTTOM, 18-19 KFT-LBS TORQUE OFF BOTTOM, 14-16 KLBS WOB - SURVEY EVERY STAND FOR DOGLEGS < 5°/100', NO BACKREAMINGAT CONNECTIONS 1- HOLDING 75° INCLINATION, HOLD 308° AZIMUTH PRESSURIZED MUD WEIGHT IN/OUT = 9.6 PPG, NON -PRESSURIZED MUD WEIGHT IN/OUT = 9.5 PPG NOVOS AND SOFTSPEED ENABLED BLEND IN SPIKE FLUID BEGINNING AT 12850' MD TO INCREASE MW FROM 9.6 PPG TO 10.5 PPG AHEAD OF CM1. WEIGHT UP COMPLETE BY 13050' MD (03:00) - NEW DYNAMIC LOSS RATE WITH 10.5 PPG MUD IN/OUT = 400 BPH - ECD WITH NEW 10.5 PPG MUD ACTUAL = *11.9 PPG - CONNECTION GAS DOWN TO MINIMAL AMOUNT, -200 UNITS, AT 10.5 PPG MW CONTINUE TO FINGER PRINT FLOWBACKAT 1 EACH CONNECTION. FLOW OUT % AND VOLUME OVER TIME TRENDS CONTINUE TO FOLLOW SIMILAR DECREASING PATTERN. 0430 1200 7.50 DRILL N 13,155.00 INT1 LOAD PITS WITH MUD IN PREPARATION FOR DRILLING AHEAD WITH MAJOR LOSSES RECIPROCATE PIPE FULL STAND, NO SIGNS OF HOLE ISSUES PU = 228 KLBS, SO = 121 KLBS PERFORM UNANNOUNCED KICK WHILE DRILLING DRILL WITH WOODS CREW. HOLD _ AAR AND DISCUSS MAASP COMPLICATIONS 12:00 13:00 1.00 DRILL P 13,185.00 INT1 DRILLAHEAD FROM 13155' MD TO 13185' MD, SAME PARAMETERS AS PREVIOUS DRILLING INTERVAL - DYNAMIC LOSS RATE, 800+ BPH, TOO HIGH TO CONTINUE DRILLING ACTUAL DRILLING HOURS FOR PAST 24 HOUR REPORTING PERIOD = 12.3 HOURS =- (72%) 13:00 16:00 3.00 DRILL N 13,185.00 INT1 BUILD MUD VOLUME AND DEVELOP PLAN ,FORWARDS PUMP OUT OF THE 8-1/2" HOLE INTO THE 9-7/8" HOLE FROM 13,185' MD TO -13,033' MD - RECIPROCATE PIPE 90' WITH NO PUMP AND NO ROTATION. - HOLE FILL ON. - SLIGHT FLOW INCREASE DUE TO BREATHING OBSERVED WHEN DRILL STRING IN THE UP STROKE. BUILD MUD VOLUME AND DISCUSS PLAN FORWARD WITH ANCHORAGE TEAM. Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Page 41 or 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3 -017W0 -C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:00AM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To I Hrs Task Code NPT Total Depth Phase Description of Operations T(hr) - . -. - (usft) 16:00 - 00:00 8.00 DRILL N 13,185.00 INTI DECISION MADE TO MAKE WIPER TRIP 11/9/2017 0000 - 01:30 1.50 DRILL N 01:30 - 02:30 1 1.00 DRILL N ABOVE THE LOSS ZONE AT -7,800' MD - 10 MIN FLOW CHECK OFF BOTTOM- WELL STATIC. PUMP AND PULL FROM 13,030' MD TO 12,021' MD DUE TO SWABBING / BREATHING INSIDE THE DRILL PIPE. 2 BPM, 365-500 PSI, PULL ON ELEVATORS FROM 12,021' MD TO 9,275' MD. HOLE NOT TAKING CORRECT HOLE FILL DUE TO WELL BREATHING STATUS. - PERFORM 10 MIN FLOW CHECK IN BETWEEN EACH SET OF 5 STANDS. PER AGREED PLAN FOR POOH WITH BREATHING WELL. - TRIP LIMITS PER THE WELL PROGRAM: 25 FPM FROM TD TO,10,500' MD , 30 FPM FROM 10,500' MD TO 8,000' MD 13,185.00 INTI UNPLANNED WIPER TRIP DUE TO EXCESSIVE LOSSES, TRIP ABOVE THE LOSS ZONE AT -7,800' MD - PULL ON ELEVATORS FROM 9,275' MD TO 7,550' MD - HOLE NOT TAKING CORRECT HOLE FILL DUE TO WELL BREATHING STATUS, PERFORM 10 MIN FLOW CHECK IN BETWEEN EACH SET OF 5 STANDS. PER AGREED PLAN FOR POOH WITH BREATHING WELL. TRIP LIMITS PER THE WELL PROGRAM: 25 FPM FROM TD TO 10,500' MD , 30 FPM FROM 10,500' MD TO 8,000' MD, 40 FPM FROM 8,000' MD TO 7,000' MD 13,185.00 j INT1 ESTABLISH CIRCULATION ABOVE THE LOSS WLY IN 1 BBL Printed 1/10/2018 5:03:39PM 'All depths reported in Drillers Depths" 1 BBL, 160 PSI ICP, 160 FCP- NO RETURNS 2 BPM, 245 PSI - 10 MIN 3 BPM, 330 PSI ICP, 325 PSI FCP- 10 MIN 4 BPM, 440 PSI ICP, 430 PSI FCP- 10 MIN 5 BPM, 560 PSI ICP, 550 PSI FCP -15 MIN , STARTED GETTING MINIMAL RETURNS AT FLOW LINE 6 BPM, 735 PSI ICP, 1% RETURNS AT FLOW LINE. FOR 5 MIN., -240 BPH LOSS RATE - 33% RETURNS, RETURNS NOT GETTING BETTER LOST -195 BBLS WHILE STAGING UP. MONITOR WELL 10 MIN - WELL BREATHING. VERIFY DIMINISHING FLOW. - MW -10.5 PPG IN / OUT Printed 1/10/2018 5:03:39PM 'All depths reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth (hr) (usft) 02:30 - 05:00 2.50 DRILL N 13,185.00 05:00 - 10:30 1 5.50 1 DRILL I N 110:30 - 15:00 4.50 DRILL N 13.185.00 Page 42 of 67 Phase Description of Operations INT1 PULL OUT OF THE HOLE FROM 7,550' MD TO 6,550' MD - HOLE NOT TAKING CORRECT HOLE FILL DUE TO WELL BREATHING STATUS. - PERFORM 10 MIN FLOW CHECK IN BETWEEN EACH SET OF 5 STANDS. PER AGREED PLAN FOR POOH WITH BREATHING +; WELL. - FLOW CHECK AFTER FIRST 5 STANDS SHOWED WELL BREATHING UP THE DRILL PIPE, KELLY UP AND PUMP OUT FROM 7030' MD TO 6,550' MD TRIP LIMITS PER THE WELL PROGRAM: 40 FPM FROM 8,000' MD TO 7,000' MD INT1 'ESTABLISH CIRCULATION ABOVE THE LOSS ZONE AT -6,550' MD - STAGE PUMPS UP SLOWLY IN 1 BBL INCREMENTS ALLOWING PRESSURE TO STABILIZE - RECIPROCATE PIPE 75' WHILE ROTATING AT 60 RPM'S - STAGE PUMPS UP TO 600 GPM, MONITORING LOSSES. LOSSES RANGING FROM 50-150 BPH. RACKASTAND BACK EVERY THREE CYCLES UP TO 6,262' MD - AT BOTTOMS UP THE HOLE CLEANED UP, UNLOADING LARGE AMOUNT OF FINE SOLIDS. - FLOW CHECK THE WELL- 30 MIN. WELL BREATHING. FINGER PRINT FLOW BACK ENSURE DIMINISHING FLOW RATE OVER TIME. - MW 10.5 PPG IN / OUT INT1 15:00 - 17:00 I 2.00 DRILL I N 1 1 13,185.00 1 INTI Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* - TRIP IN THE HOLE FROM 6,300' MD TO -7,100 'M D. - STAGE PUMPS UP IN 1 BBL INCREMENTS WHILE MONITORING LOSS RATE. RECIPROCATE PIPE 75' WITH 60 RPM STAGE UP TO 11 BPM PER THE AGREED PLAN FORWARD LOSSES RANGED BETWEEN 25 - 120 BPH. FLOW CHECKTHE WELL- 10 MIN. WELL BREATHING. FINGER PRINT FLOW BACK ENSURE DIMINISHING FLOW RATE OVER TIME. MW 10.5 PPG IN / OUT TRIP IN THE HOLE FROM-7,100'MD TO -7,500' MD - STAGE PUMPS UP IN 1 BBL INCREMENTS WHILE MONITORING LOSS RATE. RECIPROCATE PIPE 75' WITH 60 RPM STAGE UP TO 11 BPM MONITORING LOSSES LOSSES RANGED BETWEEN 25 - 170 BPH. FLOW CHECK THE WELL- 15 MIN. WELL BREATHING. FINGER PRINT FLOW BACK ENSURE DIMINISHING FLOW RATE OVER TIME. - MW 10.5 PPG IN / OUT North America - ALASKA - BP a Page 43 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations hr 17:00 - 21:30 4.50 DRILL N 13(185)00 INT1 + TRIP IN THE HOLE FROM -7,500' MD TO 21:30 - 00:00 2.50 DRILL N 11/10/2017 100:00 - 01:00 I 1.00 DRILL N 13,185.00 13,185.00 -8000' MD - STAGE PUMPS UP IN 1 BBL INCIMENTS WHILE MONITORING LOSS RATE. - RECIPROCATE PIPE 75' WTIH 60 RPM -STAGE UP TO 11 BPM MONITORING LOSSES LOSSES RANGED BETWEEN 60 - 150 BPH. AT 7 BPM LOSSES INCREASED TO 150 BPH, THEN STARTED DECREASING WHEN PUMP RATE WAS INCREASED TO 11 BPM. - AT 11 BPM LOSSES DECREASED TO ALMOST ZERO. - FLOW CHECK THE WELL- 15 MIN. WELL BREATHING. FINGERPRINT FLOW BACK ENSURE DIMINISHING FLOW RATE OVER TIME. - MW 10.5 PPG IN / OUT INT1 TRIP IN THE HOLE FROM -8000' MD -9,000' MD STAGE PUMPS UP IN 1 BBL INCREMENTS WHILE MONITORING LOSS RATE. RECIPROCATE PIPE 75' WTIH 60 RPM STAGE UP TO 11 BPM MONITORING LOSSES 2 BBL, 315 PSI ICP, 280 FCP- FL- 10% 3 BPM, 351 PSI. ICP, 345, FCP, FL- 13% 4 BPM, 449 PSI ICP, 450 PSI FCP- FL -14% - 50 BPH LOSS RATE - 5 BPM, 563 PSI ICP, 563 PSI FCP- FL -15%- 80 BPH LOSS RATE - 6 BPM, 713 PSI, FL -16%,120 BPH LOSS RATE - 7 BPM, 880 PSI ICP, FL -16% -120 BPH LOSS RATE - 8 BPM, 1096 PSI ICP, FL -16% -170 BPH LOSS RATE - 9 BPM, 1335 PSI ICP, FLA 5% -300 BPH LOSS RATE - 10 BPM, 1570 PSI ICP, FL -16% -0 BPH LOSS RATE - 11 BPM, 1735 PSI ICP, FL -26% -0 BPH LOSS RATE LOSSES RANGED BETWEEN 0 - 300 BPH. FLOW CHECK THE WELL- 15 MIN. WELL BREATHING. FINGER PRINT FLOW BACK ENSURE DIMINISHING FLOW RATE OVER TIME. - MW 10.5 PPG IN / OUT INT1 CIRCULATING WHILE MONITORING LOSS RATE - 11 BPM, WITH 1735 PSI, 60 RPM, RECIPROCATING PIPE 75' - FLOW CHECK THE WELL- 15 MIN. WELL BREATHING. FINGER PRINT FLOW BACK ENSURE DIMINISHING FLOW RATE OVER TIME. - MW 10.5 PPG IN / OUT Printed 1/10/2018 5:03:39PM `All depths reported in Drillers Depths` North America - ALASKA - BP49 Page 44 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations 01.00 04:00 (hr)- 3.00 DRILL (usft) -- - - N 13,185.00 INT1 TRIP IN THE HOLE FROM -9,000' MD TO 9,900' MD STAGE PUMPS UP IN 1 BBL INCREMENTS ALLOWING PRESSURE TO STABILIZE, WHILE MONITORING LOSS RATE. RECIPROCATE PIPE 75' WITH 60 RPM. STAGE UP TO 11 BPM MONITORING LOSSES. -STAGE UP PRESSURES AND LOSSES ARE FOLLOWING THE SAME PATTERN AS THE PREVIOUS STAGING. LOSSES BETWEEN 50-200 BPH AT 11 BPM LOSSES CAME DOWN FROM 200 BPH TO 75 BPH. FLOW CHECK THE WELL- 20 MIN. WELL BREATHING. FINGER PRINT FLOW BACK ENSURE DIMINISHING FLOW RATE OVER TIME. MW 10.5 PPG IN / OUT 04:00 10:30 6.50 DRILL N 13,185.00 INT1 TRIP IN THE HOLE FROM -9,900' MD TO 11,400' MD - STAGE PUMPS UP IN 1 BBL INCREMENTS TO A RATE OF 11 BPM ALLOWING FOR PRESSURE TO STABILIZE BEFORE INCREASING RATE, MONITORING LOSS RATE. - REPEAT PROCESS FROM 11,400' MD TO 12,600' MD STAGING PUMPS UP WHILE MONITORING LOSSES. RECIPROCATE PIPE 75' WITH 60 RPM WHILE _ STAGING PUMPS. 10:30 14:30 4.00 DRILL IN 13,185.00 INT1 WASH DOWN FROM 12,600' MD TO 13,185' MD STAGE PUMPS UP TO DRILLING RATE EACH STAND DOWN 650-700 GPM, 3515 PSI / 4015 PSI - 60 RPM, 15-16K TQ LOSSES STILL BETWEEN 50-200 BPH WHILE PUMPING - WELLBORE BREATHING ON CONNECTIONS. ! FLOW SHOWING SIGNS OF DIMINISHING RETURN ON EACH CONNECTION FINGER PRINTING EACH CONNECTION. NO ISSUES WHILE RIH ON ELEVATORS OR WASHING DOWN TO TD Printed 1/10/2018 5.03:39PM *All depths reported in Drillers Depths* Printed 1/10/2018 5:03:39PM 'All depths reported in Drillers Depths` North America - ALASKA - BP Page 45 of 67 49 Operation Summary Report Common Well Name: S-200 _ AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S -200A Actual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 14:30 00:00 9.50 DRILL P 13,820.00 INT1 DIRECTIONAL DRILL 8-1/2" x 9-7/8" INTERMEDIATE HOLE FROM 13,185' MD TO 13,820' MD IN THE CM2 FORMATION (635' IN 9.5 HOURS = 67 FPH WITH CONNECTIONS) - INSTANTANEOUS ROP = 60-120 FPH - 650-700 GPM, 3750-3920 PSI ON BOTTOM, 160 RPM, 19-20.5 KFT-LBS TORQUE ON BOTTOM, 18 KFT-LBS TORQUE OFF BOTTOM, 14-16 KLBS WOB - PU = 232 KLBS, SO = 117 KLBS, ROT = 155 KLBS - SURVEY EVERY STAND FOR DOGLEGS < 5°/100', NO BACKREAMING AT CONNECTIONS HOLDING 75° INCLINATION, HOLD 308° AZIMUTH, STARTED DROP TURN PER DIRECTIONAL PLAN AT 13,300' MD - PRESSURIZED MUD WEIGHT IN/OUT = 10.4+/10.5+ PPG, NON -PRESSURIZED MUD WEIGHT IN/OUT = 10.2 / 10.3 PPG NOVOS AND SOFTSPEED ENABLED ECD ACTUAL = 11.78 PPG, CALCULATED 11.43 PPG - DYNAMIC LOSS RATE = 100-150 BPH NOVOS AND SOFTSPEED ENABLED 40 BBL LOW / HIGH VIS SWEEP AT 13,538' MD- 25% INCREASE IN CUTTINGS AT BOTTOMS UP. ACTUAL DRILLING HOURS FOR PAST 24 HOUR REPORTING PERIOD = 7.3 HOURS (30%) CONTINUE TO FINGER PRINT FLOW BACK AT EACH CONNECTION. FLOW OUT % AND VOLUME OVER TIME TRENDS CONTINUE TO FOLLOW SIMILAR DECREASING PATTERN. Printed 1/10/2018 5:03:39PM 'All depths reported in Drillers Depths` North America - ALASKA - BP Operation Summary Report Common Well Name: S-200 Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Contractor: PARKER DRILLING CO. Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase (hr) (usft) 11/11/2017 00:00 - 07:30 ` 7.50 DRILL P 14,150.00 INT1 0730 - 10:00 2.50 DRILL P I. 14,150.00 I NT1 Printed 1/10/2018 5:03:39PM 'All depths reported in Drillers Depths* Page 46 of 67 - AFE No X3-017WO-C: (6,876,211.00) Rig Release: 11/27/2017 BPUOI: USA00000172 Description of Operations DIRECTIONAL DRILL 8-1/2" x 9-7/8" INTERMEDIATE HOLE FROM 13,820' MD TO 14,150' MD IN THE CM1 / HRZ FORMATION. (330' IN 7.5 HOURS = 44 FPH WITH CONNECTIONS) INSTANTANEOUS ROP = 60-120 FPH. 650-700 GPM, 3750-3920 PSI ON BOTTOM, 160 RPM, 19-20.5 KFT-LBS TORQUE ON BOTTOM, 18 KFT-LBS TORQUE OFF BOTTOM, 14-16 KLBS WOB. - PRESSURIZED MUD WEIGHT IN/OUT = 10.5/10:5+ PPG, NON -PRESSURIZED MUD WEIGHT IN/OUT = 10.3 / 10.3 PPG. - PU = 235 KLBS, SO = 124 KLBS, ROT = 163 KLBS. - SURVEY EVERY STAND FOR DOGLEGS < 5`/100', NO BACKREAMING AT CONNECTIONS. - ECD ACTUAL= 11.70 PPG, CALCULATED 11.43 PPG. - NOVOS AND SOFTSPEED ENABLED. - 40 BBL LOW/ HIGH VIS SWEEP AT 14,015' MD- 25% INCREASE IN CUTTINGS AT BOTTOMS UP. - 40 BBL LOW/ HIGH VIS SWEEP AT 14,150' MD- 25% INCREASE IN CUTTINGS AT BOTTOMS UP. -ACTUAL DRILLING HOURS FOR PAST 24 HOUR REPORTING PERIOD = 5.9 HOURS (24%) CONTINUE TO FINGER PRINT FLOW BACKAT EACH CONNECTION. FLOW OUT %AND VOLUME OVER TIME TRENDS CONTINUE TO FOLLOW SIMILAR DECREASING PATTERN. - GEOLOGY: TOP OF HRZ- 14,132' MD. TD IS 18' INTO THE HRZ - DIRECTIONAL: DRILLED TO DIRECTIONAL WPO8, 59° INC, 292° AZ. CIRCULATE AND CONDITION WELLBORE PER THE WELL PLAN - PUMP LOW/ HIGH VIS SWEEP AT TD - NO INCREASE IN CUTTINGS AT BOTTOMS UP - 685 GPM, 3715 PSI. 60 RPM. 18.5 K TQ, RECIPROCATE PIPE 65' TOTAL OF 2.5 BOTTOMS UP MW 10.5 PPG IN /OUT FLOW CHECK THE WELL - 10 MIN. WELL BREATHING. FINGER PRINT FLOW BACK ENSURE DIMINISHING FLOW RATE OVER TIME. North America - ALASKA - BP Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017End Date: 11/24/2017 IX3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad j Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Page 47 of 67 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 10:00 - 11:30 1.50 DRILL P 14,150.00 INTI I PLANNED WIPER TRIP: PUMP OUT OF THE HOLE FROM 14,150' MD TO 13,942' MD DROP 1-7/8" BALL TO DEACTIVATE ANDERREAMER UNDERREAMER. PULLAT 100 FPM AND PUMP AT 200 GPM, 611 PSI. NO PRESSURE INCREASE OBSERVED. PUMP AT 250 GPM, 850 PSI WHILE ROTATING AT 60 GPM, NO PRESSURE INCREASE OBSERVED, BALL DID NOT SEAT. ATTEMPT TO BRING PRESSURE UP TO 1500 PSI TO SEAT BALL. NO PRESSURE SPIKE INDICATING UNDERREAMER CLOSURE. - ATTEMPT TO PULL OUT. ON ELEVATORS. WELL BREATHING UP THE DRILL PIPE. KELLY UP AND PUMP OUT OF THE HOLE. 11:30 12:00 0.50 DRILL P 14,150.00 INTI FLOW CHECK THE WELL FLOW CHECK THE WELL- 10 MIN. WELL BREATHING. FINGER PRINT FLOW BACK ENSURE DIMINISHING FLOW RATE OVER TIME. 12:00 18:00 6.00 DRILL P 14,150.00 INT1 PLANNED WIPER TRIP: FROM 13,942' MD TO 11,023' MD PUW-235K , SOW -115K, PUMP OUT OF THE HOLE DUE TO WELLBORE BREATHING UP THE DRILL PIPE. 2 BPM, 340 PSI, LOST 6 BBLS WHILE PUMPING OUT OF THE HOLE. 18 00 2030 2.50 DRILL P 14,150.00 INT1 PLANNED WIPER TRIP: - MONITOR WELL 10 MIN PRIOR TO GOING BACK TO TD. TIH FROM 11,023' MD TO 14,150' MD. MONITOR WELL ON TRIP TANK. WASH LAST 150' DOWN AT 1 BPM. PUSHED AWAY 50 BBLS TOTAL FOR TRIP IN. NO HOLE ISSUES DURING WIPER TRIP. 20:30 00:00 3.50 DRILL P 14,150.00 INT1 CIRCULATE AND CONDITION HOLE AT INTERMEDIATE TD, 14,150' MD - STAGE PUMPS UP IN 1 BBL INCREMENTS TO 650 GPM, ALLOWING FOR PRESSURE STABILIZATION BEFORE INCREASING. RECIPROCATE PIPE 80', CIRCULATE BOTTOMS UP WHILE IN THE 8-1/2" HOLE FLOW CHECK THE WELL- 10 MIN. WELL BREATHING. FINGER PRINT FLOW BACK ENSURE DIMINISHING FLOW RATE OVER TIME. RACK BACK ONE STAND AND CONTINUE CIRCULATING IN THE 9-7/8" HOLE PUMP 40 BBL HIGH VIS SWEEP - NO INCREASE IN CUTTINGS AT BOTTOMS UP. RUNNING WATER AND MIXING DESCO TO CONDITION MUD TO 18 YP IN AND 19 YP OUT. 10.5 PPG IN /OUT Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Page 46 of 67 Operation Summary (Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr)---- - (usft) 11/12/2017 00:00 02:30 2.50 DRILL P 14,150.00 INTI CIRCULATE AND CONDITION HOLE AT INTERMEDIATE TD, 14,000' MD CIRCULATE AT 650 GPM, 3405 PSI, 60 RPM, 16K TQ. TOTAL OF 4.5 BOTTOMS UP. LOSS RATE DURING FIRST TWO BOTTOMS UP: 150-240 BPH. - LOSSES REDUCED TO 20-30 BPH AFTER SECOND BOTTOMS UP - LOST TOTAL OF 440 BBLS WHILE CIRCULATING, MW-10.5 PPG IN / OUT, YP-18 IN, YP-19 OUT, .ACTUAL ECD-11.42 PPG 02:30 03:00 0.50 DRILL P 14,150.00 INTI FLOW CHECK THE WELL PRIOR TO FINAL �TRIP. 30 MIN. WELL BREATHING. FINGER PRINT FLOW BACK ENSURE DIMINISHING FLOW RATE OVER TIME. FLOW OUT % DECLINE FROM 26% TO 5% TOTAL-140-BBLS FLOW BACK DURING FLOW CHECK. O EC 03:00 - 12:00 9.00 DRILL P 14,150.00 INT1 FIANAL'TRIP: PULLOUT OF THE HOLE WITH 8-1/2" X 9-7/8" DRILLING ASSEBLLY FROM INT1 TD PUMP AND PULL FROM 14,030' MD TO 8,500' MD DUE TO SWABBING / BREATHING INSIDE THE DRILL PIPE. 2 BPM, 275-300 PSI, PULLING SPEED= 25 FPM FROM TD TO 10,500' MD , 30 FPM FROM 10,500' MD TO 8,500' MD - RACKING BACK 5" DRILL PIPE & LAYING DOWN OFFLINE. WELL BREATHING DURING TRIP: MONITORING DECLINING FLOW TREND ON TRIP SHEET PERFORM 10 MIN FLOW CHECK IN BETWEEN EACH SET OF 5 STANDS. PER AGREED PLAN FOR NON-PROPER HOLE FILL. (2-3) BBL GAIN DURING 10 MIN FLOW CHECK. TRIP LIMITS PER THE WELL PROGRAM: BREATHING UP THE DRILL PIPE STOPPED AROUND 12,160' MD ** UNSUCESSFULLY ATTEMPT TO PULL (3) STANDS ON ELEVATORS FROM 12,150' - 11,865' MD & (2) STANDS 10,790' - 10,600' MD. (SWABBING) 12:00 - 13:30 _ 1.50 DRILL P 14,150.00 INTI FINAL TRIP: PULL OUT OF THE HOLE WITH 8-1/2" X 9-7/8" DRILLING ASSEBLLY. PUMP AND PULL FROM 8,500' MD TO 7,600' MD 2 BPM, 255-300 PSI, PULLING SPEED= 30 FPM FROM 10,500' MD TO 8,500' MD, 40 FPM FROM 8,000'- 7,000' MD - PERFORM 10 MIN FLOW CHECK IN BETWEEN EACH SET OF 5 STANDS. PER AGREED PLAN FOR NON-PROPER HOLE FILL. - POOH RACKING BACK, WHILE LAYING DOWN DP OFFLINE. Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Page 49 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017W0-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:00AM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 13:30 16:00 2.50 DRILL P 14,150.00 INT1 CIRCULATE BOTTOMS UP ABOVE THE LOSS ZONE AT (-7,834) -STAGE PUMPS UP TO 600 GPM, 2430 PSI, 60 RPM, 7K TQ. - RACK STANDS BACK FROM 7,600' - 7,300' MD WHILE OBTAINING BOTTOMS UP. WELL BREATHING BACK ON CONNECTIONS FLOW CHECK & FINGER PRINT FLOW BACK- ENSURE DIMINISHING FLOW RATE OVER TIME. MW 10.5 PPG IN / 10.6 PPG OUT. 16:00 17:30 1.50 DRILL P 14,150.00 INTI FIANALTRIP: PULLOUT OF THE HOLE WITH 8-112" X 9-7/8" DRILLING ASSEBLLY - PUMPAND PULL FROM 7,300' MD TO 6,400' MD 2 BPM, 185-200 PSI, PULLING SPEED= 50 FPM FROM 7,300' MD TO 6,000' MD ' - RACKING BACK 5" DRILL PIPE & LAYING DOWN OFFLINE.- - PERFORM 10 MIN FLOW CHECK IN BETWEEN EACH SET OF 5 STANDS. PER AGREED PLAN FOR NON-PROPER HOLE FILL. 17:30 23:30 6.00 DRILL P 14,150.00 INT1 FINAL TRIP: PULL OUT OF THE HOLE ON ELEVATORS WITH 8-1/2" X 9-7/8" DRILLING ASSEBLLY TOH FROM 6,400' MD TO 470' MD PULLING SPEED: - 60 FPM FROM 6000' MD - 5000' MD - 80 FPM FROM 5000' MD - 9-5/8" WINDOW RACKING BACK 5" DRILL PIPE & LAYING DOWN OFFLINE. PERFORM 10 MIN FLOW CHECK IN BETWEEN EACH SET OF 5 STANDS. PER AGREED PLAN FOR NON-PROPER HOLE FILL. NO HOLE ISSUES NOTED WHILE PULLING THROUGH 9-7/8" HOLE SECTION TO THE 9-5/8" CASING WINDOW. MUD WEIGHT IN/OUT = 10.5 PPG 23:30 00:00 0.50 DRILL P 14,150.00 INTI PULLAND LAY DOWN 8-1/2" x 9-7/8" RSS AND UNDERREAMER ASSEMBLY FROM 470' MD TO 350' MD MONITOR WELL FOR 10 MIN PRIOR TO PULLING NON-SHEARABLES ACCROSS THE STACK; STATIC LAY DOWN HWDP AND JARS LAY DOWN NM COLLARS, STABILIZERS, MWD COMPONENTS AND BIT 11/13/2017 00:00 01:30 1.50 DRILL P 14,150.00 INT1 PULLAND LAY DOWN 8-1/2" x 9-7/8" RSS AND UNDERREAMER ASSEMBLY FROM -350' MD TO SURFACE BIT GRADE: 1 - 1 - WT - N - X - I - NO - TD - UNDERREAMER GRADE: 4 - 2 - BT - A - X - I - CT- TD I FOUND PLASTIC DEBRIS IN THE UNDERREAMER TOOL. SAME DEBRIS FOUND IN THE FILTER SUB OF THE BHA. 0.50 CLEAN AND CLEAR RIG FLOOR 01:30 02:00 DRILL P 14,150.00 INTI Printed 1/10/2018 5:03:39PM `All depths reported in Drillers Depths' Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Page 50 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr)— _ (usft) 02:00 04:00 2.00 BOPSUR P 14,150.00 INT1 PRESSURE TEST ANNULAR PREVENTER & HCRS TO 250 PSI LOW/ 3500 PSI HIGH FOR 5 MIN EACH FOLLOWING WELL SHUT IN FOR BREATHING ON 11/6/17 AS FOLLOWS: DRAIN STACKAND PULL WEAR RING, WELL STATIC INSTALL TEST PLUG AND 4" TEST JOINT PULL TEST PLUG AFTER PASSING TEST, SEE ATTACHED DOCUMENTATION PERFORM WEEKLY FUNCTION TEST OF ALL BOPE. MAKE UP 7" CASING JOINT AND PERFORM FUNCTION TEST PERAPI STANDARD 53 FROM DRILLER'S REMOTE PANEL FLOW CHECK WELL 10 MIN PRIOR TO RIH _ WITH CASING (WELL STATIC). 04:00 06:00 2.00 CASING P 14,150.00 INTI RIG UP TO RUN 7' CASING WITH DOYON CASING 320T 7.0 VOIANT CRT, 250T SIDE DOOR ELEVATORS, 8-5/8" DOUBLE STACK TONGS, 8-1/2' BAIL EXTENSIONS, PS -21 SLIPS, FILL UP HOSE MAKE UP SAFETY JOINT WITH RIG FLOOR FOSV WITH CROSSOVERS j CONFIRM HANDLING EQUIPMENTAND PIPE COUNT/LAYOUT IN PIPE SHED. �, HOLD PJSM AND REVIEW CASING RUN SPECIFIC STANDING ORDERS 06:00 10:30 4.50 CASING P 14,150.00 ; INT1 I RUN 7", 26#, INTERMEDIATE CASING FROM SURFACE FROM SURFACE TO 2,733' MD CHECK FLOATS (GOOD) - RUN (3) TOTAL FLOATS IN SHOE TRACK AS CONTINGENCY - APPLY 1.0 FF JET LUBE SEAL GUARD AND TORQUE TURN CONNECTIONS WITH TONGS TO 11950 FT -LBS OPT MU TRQ (VAM REP WITNESS) CENTRALIZER'S INSTALLED IN PIPE BARN (14150' - 7467' MD): CENTEK BOWSPRING JTS 1-26, OMD HYDROFORM JTS 27-126, CENTEK JTS 127-152, OMD JTS 153-159 RUNNING SPEED IN CASED HOLE = 100 FPM, OPENHOLE SHOE TO 2748' MD = 50-70 FPM - FILL PIPE ON THE FLY AND TOP OFF EVERY 10 JOINTS IN CASING. CIRCULATE EVERY 5TH JOINT DOWN IN OPENHOLE TO BASE OF UGNU AT 8800' MD. MW IN/OUT = 10.5 PPG PUSH AWAY 43 BBLS Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Page 51 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 10:30 11:30 1.00 CASING P 14,150.00 INTI CIRCULATE BOTTOMS UPAT THE 9-5/8" SHOE AT 2,733' MD - STAGE PUMPS UP TO 5 BPM ALLOWING FOR PRESSURE TO STABILIZE. 5 BPM, 205 PSI CIRCULATE BOTTOMS UP, 160 BPH LOSS RATE WHILE PUMPING AT 5 BPM. - EXTENDED FLOW CHECK AFTER BOTTOMS j UP- 40 MIN. WELL BREATHING. FINGER PRINT FLOW BACK ENSURE DIMINISHING FLOW RATE OVER TIME. 30 BBLS BACK IN 40 MIN " KICK WHILE TRIPPING (D1). DRILL WITH VOLANT AND CASING FLOATS COMPLICATIONS: AAR 11:30 13:00 1.50 CASING P 14,150.00 INT1 RUN 7",•26#, INTERMEDIATE CASING FROM SURFACE FROM 2,733' MD TO 2,947' MD RUNNING SPEED IN OPENHOLE TO 2947' MD = 50-70 FPM - FILL PIPE ON THE FLY AND TOP OFF EVERY 10 JOINTS IN CASING. CIRCULATE EVERY 5TH JOINT DOWN IN OPENHOLE TO BASE OF I UGNU AT 8800' MD. MW IN/OUT = 10.5 PPG 9.50 13:00 22:30 CASING N 14,150.00 WT1 NON RIG DOWN TIME: UPPER IBOP VALVE ACTUATOR FAILED ATTEMPTS TO FUNCTION VALVE WERE UNSUCCESSFUL. PJSM FOR CHANGE OUT OF THE IBOP j VALVE AND ACTUATOR ASSEMBLY j WELL STATUS: NO LOSS NO GAIN WHILE MONITORING PRIOR TO START OF THE JOB. HOLE FILL ON FOR CONTINUOUS MONITORING. " FUNCTION & PRESSURE TEST UPPER -BOP, 250 LOW/ 3500 PSI HIGH, ALL TESTS PASSED. Printed 1/10/2018 5:03:39PM `All depths reported in Drillers Depths' North America - ALASKA - BP Page 52 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11124/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 22:30 - 00:00 1.50 CASING P 14,150.00 INTI RUN 7",26#, INTERMEDIATE CASING FROM SURFACE FROM 2,947' MD TO 3170 AT MIDNIGHT APPLY 1.OFF JET LUBE SEAL GUARD AND TORQUE TURN CONNECTIONS WITH TONGS TO 11950 FT -LBS OPT MU TRQ (VAM REP WITNESS) - CENTRALIZERS INSTALLED IN PIPE BARN (14150' - 7467' MD): CENTEK BOWSPRING JTS 1-26, OMD HYDROFORM JTS 27-126, CENTEK JTS 127-152, OMD JTS 153-159 - RUNNING SPEED IN OPENHOLE TO MD = 50-70 FPM - FILL PIPE ON THE FLYAND TOP OFF EVERY 10 JOINTS IN CASING. CIRCULATE EVERY 5TH JOINT DOWN IN OPENHOLE. RAW IN/OUT = 10.5 PPG � I - PUSH AWAY 32 BBLS AT 3,170' STAGE PUMPS TO 5 BPM OVER TWO STANDS TO GET BOTTOMS UP DUE TO EXTENDED TIME WITH NO FLUID MOVEMENT. LOST 80 BBLS DURING CIRCULATION. 10 MIN FLOW CHECK - WELL BORE BREATHING- 18 BBLS BACK IN 10 MIN. WITH SIGNS OF DIMINISHING FLOW 11/14/2017 00:00 12:00 12.04 DRILL P 14,150.00 INT1 j RUN 7",26#, INTERMEDIATE CASING FROM SURFACE FROM 3,170 AT MIDNIGHT TO -7,699' MD AVERAGE 9-10 JOINTS PER HOUR WITH CIRCULATION PUW-170K, SOW -90K APPLY 1.0FF JET LUBE SEAL GUARD AND TORQUE TURN CONNECTIONS WITH TONGS TO 11950 FT -LBS OPT MU TRQ (VAM REP WITNESS) - CENTRALIZERS INSTALLED IN PIPE BARN (14150' - 7467' MD): CENTEK BOWSPRING JTS 1-26, OMD HYDROFORM JTS 27-126, CENTEK JTS 127-152, OMD JTS 153-159 -RUNNING SPEED 70 FPM - FILL PIPE ON THE FLY AND TOP OFF EVERY j 10 JOINTS IN CASING. CIRCULATE EVERY 5TH JOINT DOWN IN OPENHOLE TO -7800' MD CIRCULATE DOWN EVERY 10TH JOINT FROM 7,800' MD TO (TD) AT 5 BPM, 275-300 PSI OBTAIN PU, SO EVERY 10TH JOINT MW IN/OUT = 10.5 PPG PUSHING AWAY AVERAGE 10-17 BBLS PER 10 JOINTS RAN ON ELEVATORS " STAGE PUMPS TO 5 BPM OVER THREE JOINTS TO GET BOTTOMS UP ABOVE THE LOST CIRCULATION ZONE AT -7700' MD. 5 BPM, 300 PSI Printed 1/10/2018 5:03:39PM `All depths reported in Drillers Depths` North America - ALASKA - BP Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876.211.00) Page 53 of 67 Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 12:00 00:00 12.00 DRILL P 14,150.00 INT1 RUN 7",26#, INTERMEDIATE CASING FROM SURFACE FROM 7,699' MD TO 11,575' MD - AVERAGE 9-10 JOINTS PER HOUR WITH CIRCULATION PUW-260K, SOW -84K APPLY 1.OFF JET LUBE SEAL GUARD AND TORQUE TURN CONNECTIONS WITH TONGS TO 11950 FT -LBS OPT MU TRQ (VAM REP WITNESS) - CENTRALIZERS INSTALLED IN PIPE BARN (14150'- 7467' MD): CENTEK BOWSPRING JTS 1-26, OMD HYDROFORM JTS 27-126, CENTEK JTS 127-152, OMD JTS 153-159 RUNNING SPEED 70-80 FPM FILL PIPE ON THE FLY AND TOP OFF EVERY 10 JOINTS IN CASING. CIRCULATE EVERY 5TH JOINT DOWN IN OPENHOLE TO -7800' MD. - CIRCULATE DOWN EVERY 10TH JOINT FROM 7,800' MD TO (TD) OBTAIN PU, SO EVERY 10TH JOINT MW IN/OUT = 10.5 PPG PUSHING AWAYAVERAGE 8-15 BBLS .AVERAGE PER 10 JOINTS RAN ON ELEVATORS MONITORING BROOM STICK PLOT FOR HOLE CONDITIONS CIRCULATE BOTTOMS UP OVER THREE JOINTS TO THE TOP OF THE LOSS ZONE AT 7,700' MD - 5 BPM, 375-300 PSI, LOSING -110 BPH ** CIRCULATE BOTTOMS UP FROM -10,300 TO 10,600' OBTAIN BOTTOMS UP ABOVE THE CM2 AT 11,597' MD. CIRCULATED EARLY DUE TO HOLE CONDITIONS SHOWING INCREASING DRAG. - PU-260K, SO -93K, 5 BPM, 300 PSI, PUMPED 500 BBLS, LOST 400 BBLS RIH FROM 10,600' MD TO 11,570' MD WITH ADDITIONAL CIRCULATION DUE TO EXCESSIVE DRAG 280K PUW, 87K SOW CIRCULATE ADDITIONAL 3000 STROKES TO HELP CLEAR THE ANNULUS - 7 BPM, 485 PSI, PUMPED 280 BBLS, LOST 200 BBLS - PU WTAFTER CIRCULATION 260K, SOW 80K Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Page 54 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 IX3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) 5.00 (usft) DRILL P 14,150.00 INTI i RUN 7', 26#, INTERMEDIATE CASING FROM 11/15/2017 00:00 05:00 SURFACE FROM 11,575' MD TO 14,150' MD AVERAGE 9-10 JOINTS PER HOUR WITH CIRCULATION PUW-280K, SOW -89K APPLY 1.0FF JET LUBE SEAL GUARD AND TORQUE TURN CONNECTIONS WITH TONGS TO 11950 FT -LBS OPT MU TRQ (VAM REP WITNESS) '-CENTRALIZERS INSTALLED IN PIPE BARN (14150' - 7467' MD): CENTEK BOWSPRING JTS 1-26, OMD HYDROFORM JTS 27-126, CENTEK JTS 127-152, OMD JTS 153-159 RUNNING SPEED 70-80 FPM - FILL PIPE ON THE FLYAND TOP OFF EVERY 10 JOINTS IN CASING - CIRCULATE DOWN EVERY 10TH JOINT OBTAIN PU, SO EVERY 10TH JOINT MW IN/OUT = 10.5 PPG PUSHING AWAY AVERAGE 8-15 BBLS AVERAGE PER 10 JOINTS RAN ON ELEVATORS MONITORING BROOM STICK PLOT FOR HOLE CONDITIONS FINAL PU = 305 KLBS, SO = 95 KLBS TOTAL MUD LOSSES WHILE RIH WITH 7" CASING= 1346 BBLS 05:00 08:30 3.50 DRILL P 14150.00 INT1 STAGE UP TO CEMENTING RATE IN 1 BPM INCREMENTS TO FINAL CIRCULATING RATE OF 5 BPM @ 2 BPM, 425 PSI, 3% RETURN FLOW @ 3 BPM, 460 PSI, 3% RETURN FLOW @ 4 BPM, 487 PSI, 5% RETURN FLOW @ 5 BPM, 508 PSI, 7% RETURN FLOW INITIAL PRESSURE AT CEMENTING RATE: 508 PSI - FINAL PRESSURE AT CEMENTING RATE AFTER HOLE CONDITIONED: 420 PSI CIRCULATE TOTAL OF 1X BU RECIPROCATING PIPE STRETCH MUD LOSSES = 230 BPH AT 5 BPM Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Operation Summary Report Common Well Name: S-200 Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date 11/24/2017 AFE No _ ^X3 -017W0 -C: (6,876,211.00 ) Page 55 of 67 Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00 00AM i Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. ' BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code ! NPT Total Depth Phase Description of Operations ! (hr) - - - - (usft) 08:30 13:00 4.50 DRILL P 14,150.00 INT1 CEMENT 7" INTERMEDIATE CASING AS FOLLOWS: - HOLD PJSM WITH ALL PARTIES INVOLVED IN CEMENT JOB, REVIEW PRESSURE CROSSCHECK FILL LINES WITH 12 PPG MUDPUSH II SPACER AND PRESSURE TEST TO 4500 PSI FOR 5 MINUTES: GOOD TEST - PUMP 50 BBLS OF 12 PPG MUDPUSH II SPACER AT 6 BPM, 500 PSI UNSTING VOLANT TOOLAND RELEASE BOTTOM PLUG PUMP 41R BBLS OF 13 PPG ARCTIC SET LEAD CEMENT AT 6 BPM, EXCESS VOLUME 40% (YIELD 1.5 CU.FT/SK), ICP 850 PSI, FCP 400 PSI - PUMP 33 BBLS OF 15.8 PPG CLASS G TAIL CEMENTAT 6 BPM, EXCESS VOLUME 40% (YIELD 1.17 CU.FT/SK), ICP 800 PSI, FCP 850 PSI UNSTING VOLANT TOOLAND DROP TOP (PLUG SCHLUMBERGER CEMENTERS KICK OUT WITH 10 BBLS WATER PERFORM DISPLACEMENT WITH RIG PUMPS AND 10.5 PPG LSND MUD PER SLB CEMENTICS MODEL 91 BBLS DISPLACED AT 7 BPM: ICP 180 PSI, FCP 180 PSI (DID NOT CATCH PRESSURE) OBSERVE BOTTOM PLUG LANDING AND CEMENT EXITING SHOE OBSERVE 500 PSI SHEAR OF BOTTOM PLUG ATDISPLACED !9-1'+BBLS f1 BBLS DISPLACED AT 7 BPM: ICP 180 PSI, F72981 PSI, -85% RETURN FLOW, DECREASE FLOW RATE DUE TO INCREASING PUMP PRESSURE 19 BBLS DISPLACED AT 5 BPM: ICP 2677 PSI, FU"170 PSI, -65% RETURN FLOW, DECREASE FLOW RATE DUE TO INCREASING PUMP PRESSURE, STOP RECIPROCATING PIPE STRETCH AT THIS POINT §,9-BBLS DISPLACED AT 4 BPM: ICP 3222 PSI, FCP 4116 PSI, ^-45% RETURN FLOW, DECREASE FLOW RATE DUE TO INCREASING PUMP PRESSURE -j7 BBLS DISPLACED AT 3 BPM: ICP 4098 PSI, FCP 4782 PSI, UNABLE TO CONTINUE li PUMPING v> Z' 6 01.5 SHUT DOWN PUMPS AND CLOSE ANNULAR TO PREVENT WELL FROM BREATHING BACK - BLEED OFF PUMP PRESSURE AND CHECK FLOATS: GOOD - CEMENT IN PLACE AT 12:10 TOTAL VOLUME 10.5 PPG LSND PUMPED = 0 BB BQLS LEFT INSIDE -21-5 THE7" CASING Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* Printed 1/10/2018 5:03:39PM 'All depths reported in Drillers Depths' North America - ALASKA - BP1p Page 56 of 67 Operation Summary Report - Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations - - (hr) (usft) 13:00 - 00:00 11.00 DRILL P 141150.00 INT1 WAIT ON CEMENT TO REACH 500 PSI COMPRESSIVE STRENGTH (12 HRS 37 MIN) 500 PSI COMPRESSIVE STRENGTH WILL BE REACHED AT 00:47 11/16/17 LAY DOWN 5" DRILLPIPE FROM DERRICK CLEAN PITS 11/16/2017 00:00 02:00 2.00 DRILL P 14,150.00 INT1 WAIT ON CEMENT TO REACH 500 PSI COMPRESSIVE STRENGTH TO COMPLY WITH BP PRACTICE SIMOPS: - LAY'DOWN STANDS OF DRILLPIPE PRESSURE TEST 7" INTERMEDIATE CASING 02:00 - 03:00 1.00 DRILL P 14,150.00 INTI 3500 PSI FOR 30 CHARTED MIN PER WELL PROGRAM TEST PAGE " REVIEW PRESSURE CROSSCHECK CHECKLIST GOOD TEST; TEST MET BP TESTING CRITERIA PER, BP PRACTICE 100218 - SEE ATTACHED TEST CHART AND TEST CRITERIA CALCULATOR. RECIEVE AUTHORIZATION TO PROCEED FROM WSUP - f - 500 PSI COMPRESSIVE STRENGTH WAS REACHED AT (00:47) 11/16/17 03:00 04:00 1.00 EVAL P 14,150.00 INTI PREPARE FOR ELINE RIG UP j BREAK 5' PUP FROM TOP OF 7" CASING, MAKE UP VT (XO) TO IF REMOVE VOLANT FROM TOP DIVE. I - SPOT ELINE UNIT ON LOCATION AND START LOADING TOOLS. ELINE UNIT ON LOCATION AT 03:30. 0400 1430 10.50 EVAL P 14,150.00 INT1 RIG UP WIRELINE WITH TRACTOR FOR CEMENT EVALUATION LOG. I RIG UP (5K) PRESSURE CONTROL EQUIPMENT PER THE (GWO AK REGION SOP i FOR DRILLING AND WORK OVER WIRELINE PRESSURE CONTROL) SECTION 5.6.1 B FOR NON-SHEARABLES ACROSS THE STACK PRESSURE CONTROL CRITERIAAND RIG UP AGREED AND APPROVED BY ROTARY SUPERINTENDENT. MOBILIZE SLB TOOLS TO THE RIG FLOOR. PRESSURE CONTROL AS FOLLOWS FROM TOP TO BOTTOM: LINE WIPER PACK OFF GREASE TUBE / PACK OFF BALL SEAT HEAD CATCHER - PUMP IN SUB (ATTACHED TO THE CEMENT LINE TO THE FLOW LINE FOR WELLBORE MONITORING WELL WHILE RUNNING IN THE HOLE) XO TO OTIS CONNECTION. SIMOPS: - LAY DOWN 4" AND 5" STANDS OF DRILLPIPE OFFLINE. Printed 1/10/2018 5:03:39PM 'All depths reported in Drillers Depths' North America - ALASKA - BP Page 57 of 67 Operation Summary Report Common Well Name: S-200 _ — AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) 1 Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 14:30 21:30 7.00 DRILL P 14,150.00 INTI PLANNED LOGGING RUN FOR CEMENT EVALUATION. FIRST RUN: RIH WITH 5.7" OD GAUGE RING JUNK BASKET / GR/CCL AND 3-1/8" RUFF -TRACK TRACTOR TOOL. RIH ON ELINE TO 4,610' MD WITH OUT TRACTOR ENGAGED TRACTOR FROM 4,610' MD TO 12,818' MD. (TOTAL RIH TIME 6 HRS) - MONITOR DISPLACEMENT AT TRIP TANK MAINTAIN TRIP GAIN LOSS ALARM AND FLOW OUT % FOR WELL CONTROL. CEMENT STRINGERS AT -12,818' MD, VERALATTEMPTS TO MAKE IT PAST (�0.s // IJ OBSTRUCTION, OBSERVE EXCESSIVE OVERPULL EACH TIME, C's L_, DECISION MADE TO PULL OUT OF THE HOLE AND LOG FROM THIS POINT. SFMOPS: MAKE UP 3.5" DP STAND OFFLINE 2.50 EVAL P _ POOH WITH GAUGE RING JUNK BASKET / GR 21:30 00:00 14,150 00 INT1 CCLASSEMBLY POOH AT 150 FPM. -AT SURFACE WITH THE LOG ASSEMBLY AT (22:45) PJSM FOR CHANGING OUT BHA. BREAKAND SET BACK PRESSURE CONTROL EQUIPMENT CHANGE OUT TRACTOR AS A PRECAUTION. MAKE UP IBC/DSLT LOG TOOL PER SLB 'PROCEDURE. SIMOPS: - MAKE UP 3.5" DP STAND OFFLINE 11/17/2017 00:00 - 01:30 1.50 EVAL P 14,150.00 INTI CONTINUE FROM PREVIOUS TIME BLOCK- LOCK- -FINISH LAYING DOWN PREVIOUS GAUGE RING BHA MAKE UP IBC/DSLT LOGGING TOOL TO GR/CCLAND NEW TUFF TRACK 3-1/8" TRACTOR Printed 1/10/2018 5:03:39PM 'All depths reported in Drillers Depths` North America - ALASKA - BP Operation Summary Report Page 58 of 67 Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr)-- (usft) 01:30 16:00 14.50 EVAL P 14,150.00 INT1 RIH WITH IBC/DSLT (USIT) ,GR/CCLAND NEW TUFF TRACK 3-1/8" TRACTOR - RIH ON E LINE TO 4,450' MD WITH OUT TRACTOR - ENGAGED TRACTOR FROM 4,450' MD TO ^11,550' MD. -MONITOR DISPLACEMENT AT TRIP TANK. MAINTAIN TRIP GAIN LOSS ALARM AND FLOW OUT % FOR WELL CONTROL. - RIH WITH TRACTOR AT 45 FPM TO 12,654' MD USIT LOG FROM 12,654' MD TO 6,400' MD. LOGGING SPEED -42 FPM REPEAT PASS MADE FROM 8,56' MD TO 6,376' MD LOG DATA SENT TO PETROPHYSICIST FOR TOC & ZONAL ISOLATION EVALUATION. RECEIVED IBC LOG INTERPRETATION CONFIRMATION EMAIL FROM ODE CONFIRMING STATE APPROVAL SIMOPS: MAKE UP 3.5" DP STAND OFFLINE VAM USA REP INSPECT 4-1/2" TUBING IN THE PIPE SHED. PRESSURE TEST CHOKE MANIFOLD OFFLINE. 250/3500 PSI FOR 5 CHARTED MIN EACH 16:00 17:30 1.50 EVAL P 14,150.00 INTI RIG DOWN WIRELINE EQUIPMENT LAY DOWN WIRELINE EQUIPMENT TO THE GROUND. 17:30 21:00 3.50 CASING P 14,150.00 INT1 INSTALL EMERGENCY SLIPS: FOR 7" CASING - CLEAN OUT THE FLOW BOX PRIOR TO NIPPLE DOWN OF THE RISER NIPPLE DOWN AND SPLIT STACK FROM WELLHEAD SPOOL. CLEAN BOWLAND PREP CASING FOR CUT. MONITOR WELLAND WAIT ON CEMENT PRIOR TO BREAKING CONTAINMENT PER GWO ALASKA REGION SOP: SETTING CASING SLIPS ON INTERMEDIATE AND PRODUCTION CASING. - REQUIREMENTS FOR BREAKING CONTAINMENT EXCEEDED DUE TO CEMENT EVALUATION LOGGING RUN. - MORE THAN EXCEEDED THE REQUIRED 12 HR MONITORING PERIOD (3 XAMOUNT OF TIME TO COMPLETE BREAKING CONTAINMENT WORK) - THE 200 PSI COMPRESSIVE STRENGTH FOR BREAKING CONTAINMENT WAS REACHED AT -20:00- 11/15/16. Printed 1/10/2018 5,03:39PM *All depths reported in Drillers Depths' North America - ALASKA - BP Operation Summary Report Page 59 of 67 Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S -200A Actual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 21:00 00:00 3.00 WHSUR P 14,150.00 INT1 INSTALL 10" X 7" EMERGENCY CASING SLIPS (LWI) ON 7" CASING IN CASING SPOOL PER FMC PROCEDURE FOR SETTING SLIPS FMC GENERATION 5 STANDARD SYSTEM PULL 100K OVER ON STRING INSTALL CASING SLIPS AND SLACK OFF ON 7" CASING AS DIRECTED BY WELLHEAD REP. - ENSURE SLIPS ARE CORRECTLY CENTERED IN CASING BOWL. - RIG UP WACH CASING CUTTER, ESTABLISH CORRECT MEASUREMENTS FOR CASING CUT. -ATTACH CUTTER UPSIDE DOWN PER PROCEDURE DUE TO SPACE RESTRICTION, ADJUST ACCORDINGLY. - MAKE CUT 7" CASING CUT. (ACTUAL CUT TIME (45 MIN) REMOVE AND CUTTER AND DRESS OFF CUT FOR PACK -OFF INSTALLATION. 11/18/2017 00:00 05:30 5.50 WHSUR P 14,150.00 INT1 NIPPLE DOWN BOPE STACKAND HIGH PRESSURE RISER- FOR NEW 7" PACK -OFF INSTALL - BREAK OUT 7" CUT JOINTAND LAY DOWN TO PIPE SHED. REMOVE JNT # 341 AND 6.33' OF JNT #340 - NIPPLE DOWN BOP STACK AND SET BACK ON STUMP. - PULL HIGH PRESSURE RISER AND DROP OFF BOTTOM 24" SPACER SPOOL INSTALL NEW PACK -OFF USE DP STAND WITH PACK OFF RUNNING TOOL TO PRESS PACK -OFF OVER 7" CUT. RILDS ON CASING SPOOL. NIPPLE UP TUBING SPOOL. SIMOPS: -STRAP, TALLY AND DRIFT 4-1/2" VAM TOP LINER IN THE PIPE SHED. 05:30 07:30 2.00 WHSUR P 14,150.00 INT1 PRESSURE TEST NEW 7" PACK -OFF & OLD TUBING SPOOL PER WELL PROGRAM. 3500 PSI FOR 15 MIN - PRESSURE TEST ACCEPTANCE CRITERIA TO BP STANDARD 100218, TABLE 2, 3B - REVIEW PRESSURE CROSSCHECK CHECKLIST. - GOOD TEST; TEST MET BP TESTING CRITERIA PER BP PRACTICE 100218 ACTING WSUP APPROVED TEST. SEE ATTACHED TEST CHART SIMOPS: - CHANGE OUT UPPER RAMS IN BOP STACK WHILE STOOD BACK ON STUMP FROM 7" FIXED BORE RAM TO 2-7/8" x 5" VARIABLE BORE RAM. 07:30 10:00 2.50 BOPSUR P 14,150.00 INT1 NIPPLE UP BOPE EQUIPMENT AFTER 7" CASING CUT AND PACK -OFF INSTALL - NU 13-5/8" 5K BOP STACK AND 13-5/8" 5K HIGH PRESSURE RISERS. - INSTALL FLOW LINE AND FLOW BOX WITH AIR BOOTS. - CHANGE OUT DRILL PIPE GUIDES AND SAVER SUB TO HT -38 FROM 4-1/2" IF Printed 1/10/2018 5:03.39PM 'All depths reported in Drillers Depths' North America - ALASKA - BP Operation Summary Report Page 60 of 67 Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) 1 Start Date: 10/24/2017 End Date: 11/24/2017 X3 -017W0 -C: (6,876,211.00 ) Project: Prudhoe Bay +Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:00AM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 10:00 - 11:00 1.00 BOPSUR P 14,150.00 INT1 RIG UP TO TEST BOPE 11:00 - 15:30 4.50 BOPSUR P 14,150.00 l i 15:30 16:00 0.50 WHSUR P 14,150.00 Ili I 16:00 00:00 8.00 CLEAN N 14,150.00 - MAKE UP TEST JOINT INSTALL TEST PLUG FILL STACKAND PURGE SYSTEM OF AIR - MAKE UP TEST MANIFOLD ON RIG FLOOR PERFORM SHELL TEST ON STACKAND RISER INT1 +TEST BOPE: - PRESSURE TEST ACCEPTANCE CRITERIATO BP STANDARD 100218, TABLE -2, 1A 250/3500 PSI FOR 5 CHARTED MIN EACH - TEST ANNULAR WITH 3.5" TEST JOINT - TEST UPPER AND LOWER PIPE RAMS WITH 3-1/2" AND 4-1/2" TEST JOINT - TEST ALL CHOKE MANIFOLD VALVES, VALVES #6, 8, 9 AND 12 TESTED FROM BOTH DfRECTIONS -TEST BLIND/ SHEAR RAMS - PERFORM ACCUMULATOR DRAW DOWN TESTAND OPERATE ALL RAMS FROM BOTH REMOTE STATIONS TESTED GAS ALARMS, PVT AND FLOW SHO FUNCTION TEST HI/LOW BY-PASS, BLACKOUT DRILL CONDUCTED WHERE REMOTE BOP CONTROL PANEL MUST FUNCTION BOP WITH NO SUPPLIED POWER. NO FAILURES. SEE ATTACHED TEST 24 HR NOTIFICATION SUBMITTED ONLINE WAIVE OF WITNESS EMAIL RETURNED BY GUY COOK INT1 PULL TEST PLUG AND INSTALL WEAR RING - BLOW DOWN SURFACE LINES AND TEST EQUIPMENT DRAIN STACKAND PULL TEST PLUG RUN IN AND INSTALL 6-15/16" ID WEAR RING AND RUN IN LOCK DOWNS INT1 MAKE UP 6-1/8" BAKER CEMENT CLEAN OUT ASSEMBLY BHA FROM SURFACE TO 30' MD - USED SMITH TRI -CONE BIT, BENT HOUSE MOTOR WITH 0° AKO, PORTED FLOAT 48 STANDS OF 3.5" HT -38 DP - 1 JOINT OF 4" DP, 4" HWDP RUN JARS 1,703' BEHIND THE BIT PER SLB MODELING - 4" HWDP TOTAL BHA LENGTH: 1,947' MD RIH WITH CLEAN OUT BHA ON TAPERED STRING FROM 30' MD TO 4,300' MD - FULL STRING 3.5" HT -38 DRILL PIPE, 12,865' TOTAL - 4" HT38 DP TO SURFACE - FLOW CHECK WELL FOR 10 MIN PRIOR TO RUNNING IN HOLE, -WELL STATIC. " D1 DRILL PERFORMED IN CASING: AAR SIMOPS: FREEZE PROTECT 9-5/8" x 7" ANNULUS - INJECT 55 BBLS OF 6.8 PPG DIESEL; 2 BPM, ICP 650 PSI, FCP 750 PSI Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Page 61 of 67 Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 11/19/2017 00:00 - 04:30 4.50 WHSUR N 14,150.00 INT1 UNPLANNED TRIP IN HOLE WITH 7" CASING CLEAN OUR ASSEMBLY FROM 4,300 TO 12,750' MD ON ELEVATORS FILL PIPE EVERY 2000' MD TRIPPING SPEED = 265 FPM MONITOR WELL ON TRIP TANK (PROPER DISPLACEMENT) MUD WEIGHT 10 5 PPG IN/OUT 04:30 - 13:00 NO ISSUES TRIPPING IN HOLE TAKE SPR'S AT 12,750' MD WASH AND REAM DOWN FROM 12,750' MD TO 13,157' MD - 200 GPM, 2050 PSI 40 RPM, 3K TQ NO ISSUES WASHING DOWN. CEMENT STRINGER AT 13,148', MAX 8K WOB TO GET THROUGH -TAG UPON CEMENTAT 13,157' MD 8.50 WHSUR N 14,150.00 INT1 DRILL CEMENT FROM 13,157' MD TO 14,138' MD - 300 GPM, 3800 - 4100 PSI, 100 RPM, 12K TQ, 10K WOB 10.5 PPG MW IN/OUT ROT = 125 KLBS OBSERVE TOP PLUG OVER SHAKERS AT BOTTOMS UP AFTER INITIATING ROTATION AT 13,157' MD - WASH AND REAM CEMENT STRINGERS AT ABOVE PARAMETERS AT 200 FPH WITH NO ISSUES. - TAG UP ON FLOAT COLLAR AND BOTTOM PLUG AT EXPECTED DEPTH. 10 MIN TO DRILL t UP 14,150.00 INT1 PUMP 35 BBL HI -VIS SWEEP AT 14138' MD WITH RECIPROCATION 300 GPM, 3900 PSI 120 RPM, 12-13 KFT-LBS TORQUE OBSERVE CEMENT RETURNS OVER SHAKERS, 0% INCREASE IN RETURNS AT SWEEP TO SURFACE - SPOT LUBE PILL IN ANNULUS, 300 GPM, 3800 PSI - MUD WEIGHT IN/OUT = 10.5 PPG - FLOW CHECK WELL FOR BEFORE PULLING OFF BOTTOM: STATIC 14,150.00 INT1 PULL OUT OF THE HOLE WITH 7" CASING CLEAN OUT ASSEMBLY FROM 14,138' MD TO 2069 ON ELEVATORS - MONITOR HOLE FILL WITH TRIP TANK: GOOD HOLE FILL MUD WEIGHT IN/OUT = 10.5 PPG PULLING SPEED = 150 FPM PER THE _APPROVED WELL PROGRAM Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Page 62 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 1 21:00 - 23:30 2.50 WHSUR N 14,150.00 INT1 FLOWCHECK THE WELL BEFORE PULLING NON-SHEARABLES FROM 2069' MD TO BHA AT 30' CHANGE OUT SLIP SEGMENTS STAND BACK HWDP PULLAND LAYDOWN BHAAS DIRECTED BY BAKER DD FLOW CHECK WELL FOR 10 MIN PRIOR TO PULLING BHA THROUGH THE STACK, STATIC - BREAK BIT AND LAYDOWN MOTOR. - BREAK OFF 6-1/8" HCC VG-18DX INSERT BIT, GR_ADED2-4-WT-A-E-IN-ER- BHA 23:30 00:00 0.50 WHSUR N 14,150.00 ,' INTI CLEAN AND CLEAR RIG PLOOR PREP FOR RSS BHA MAKE UP. 11/20/2017 00:00 01:00 1.00 CEMT P 14,150.00 INT1 MAKE UP 6-1/8" RSS DRILLING ASSEMBLY PER BAKER DD AND MWD AND RUN IN HOLE FROM SURFACE TO 152' MD 6-1/8" RSS WITH T406FSX PDC BIT + DIR/GR/RESA/SS/PWD DRILLING JARS 1825' BACK FROM BIT (8) HWDP, JARS, 3-1/2" DP, (3) HWDP, XO, FLOAT SUB, FILTER SUB, (3) DRILL COLLARS, STOP SUB, BCPM, STABALIZER, ONTRAK, RSS, PDC BIT - FLOW CHECK WELL FOR 10 MINUTES BEFORE PLACING NON-SHEARABLES 'THROUGH THE STACK: STATIC MONITOR DISPLACEMENT WITH TRIP TANK: GOOD DISPLACEMENT MONITOR WELL 10 MIN PRIOR TO ENTERING THE WELBORE- STATIC 01:00 09:00 8.00 CLEAN P 14,150.00 INT1 RUN IN HOLE WITH 6-1/8" RSS DRILLING ASSEMBLY ON ELEVATORS AND 3-1/2" HT-38" DRILLPIPE FROM 152' MD TO 14,100' MD TRIP IN HOLE WITH 6-1/8" PRODUCTION HOLE DRILLING ASSEMBLY ON 3.5" HT38 DP FROM BHA AT 152' MD TO -12,865' MD - RIH FROM 12,865' MD TO 14,100' MD ON 4" HT38 DP FILL PIPE EVERY 2000' MD TRIPPING SPEED = 90-115 FPM IN CASED HOLE, - MONITOR WELL ON TRIP TANK (PROPER DISPLACEMENT) MUD WEIGHT 10.5 PPG IN/OUT NO ISSUES TRIPPING IN HOLE j SHALLOW HOLE TEST MWD TOOLS AT -300' MD: 250 GPM, 850 PSI 09:00 - 10:30 1.50 CLEAN P 14,150.00 INTI CUT AND SLIP DRILLING LINE CUT 96' OF DRILL LINE RESET CROWN SAVER CALIBRATE BLOCKS D1 DRILL WITH AAR Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Page 63 of 67 Operation Summary Report Common Well Name: 5-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Daterrime: 12/15/1997 12:00 OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 10:30 - 12:30 2.00 CLEAN P 14,170.00 INT1 TRIP IN THE HOLE WITH 6-1/8" RSS DRILLING ASSEMBLY FROM 14,100' MD TO 14,138' MD DRILL OUT REMAINING 10' OF SHOE TRACK CEMENT AND FLOAT SHOE. FROM 14,138' MD TO 14,150' MD - 200 GPM, 2361 PSI, 60 RPM, 14 KFT-LBS TRQ, 10 KLBS WOB - DRILL NEW FORMATION FROM 14,150' MD TO (FIT DEPTH) 14,170' MD SLOW PUMP RATES @ 14,138' MD / 6685' TVD WITH 10.5 PPG LSND: 12:30 14:00 1.50 CLEAN P 14,170.00 INT1 CIRCULATE BOTTOMS UP TO CONDITION HOLE PRIOR TO FIT - 200 GPM, PSI, NO RECIPROCATION OR ROTATION MW IN/OUT = 10.5 PPG + PULL INSIDE THE 7" SHOE. 14:00 15:00 1.00 DRILL P 14,170.00 PROD1 PERFORM FIT ON 7" L SHOE TO 12.7 PPG EMW 14,148' MD, 6,583 TVD, 10.5 PPG MW, 754 'PSI APPLIED SURFACE PRESSURE 2.0 BBLS TO PRESSURE UP, 2.0. BBLS BLED BACK HOLD PRESSURE 10 MIN. -10 PSI BLEED OFF OBTAIN AUTHORIZATION TO PROCEED FROM ODE SEE ATTACHED FIT CHART Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Operation Summary Report Page 64 of 67 Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3 -017W0 -C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00 00AM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 15:00 00:00 9.00 DRILL P 14,363.00 PROD1 DIRECTIONAL DRILL 6-1/8" PROD HOLE BUILD SECTION - HRZ FORMATION FROM 14,170' MD TO 14,363 ' MD (6712' TVD) - 213 ' IN 9 HRS = 24 FPH WITH CONNECTIONS MAX ROP SET AT 50 FPH 200 GPM, 2300-2330 PSI OFF BOTTOM, 2330-2360 PSI ON BOTTOM, ROT 120-150 RPM, 12-13 KFT-LBS TRQ, 10-12 KLBS WOB ECD ACTUAL= 11.86 PPG EMW MUD WEIGHT IN/OUT = 10.5 PPG NO LOSSES TO FORMATION WHILE DRILLING AHEAD ACTUAL DRILLING TIME: 7.2 HRS JAR HOURS: 7.2 SURVEY EVERY 30' FOR DOGLEGS > 51/100' NO BACKREAMING AT CONNECTIONS NO LOSSES TO THE FORMATION. OBTAIN 1 ST DIRECTIONAL SURVEY 64 FROM LAST SURVEY IN INTERMEDIATE HOLE -DIRECTIONAL UPDATE: DRILLING ON ORIGINAL DIRECTIONAL PLAN (WP08A) WITH NO ISSUES, GEOLOGY UPDATE: SAMPLES SHOWING HRZ NOVOS / DRILL SHARK ENABLED FOR ENTIRE TOWER. NOVOS WELL PLAN CONFIGURED FOR RECOMMENDED CONNECTION PRACTICES TO HELP REDUCE ECD AND SHALE CYCLES. - 27 MIN ON AVERAGE FOR CONNECTION FROM KELLY DOWN TO BACK ON BOTTOM DRILLING WITH 4 MIN DOWNLING INCLUDED. 7" LINER SHOE OFFICIALLY LOGGED AFTER DRILL OUT AT 14,153' MD (5' DIFFERENT THAN LINER TALLY. NO DEPTH CORRECTIONS MADE TO LINER TALLY). - GAS WATCH: AVERAGE BACKGROUND = 18-20 UNITS, MAXIMUM = 61 UNITS 11/21/2017 00:00 12:00 12.00 DRILL P 14,682.00 PROD1 DIRECTIONAL DRILL 6-1/8" PRODUCTION HOLE BUILD SECTION FROM 14,363' MD TO 14,682' MD, 6893' TVD - 319' IN 12 HRS = 26.6 FPH WITH CONNECTIONS - WORK ROP LIMIT UP FROM 50 FPH TO 70 FPH PU 194 KBLS, SO 100 KLBS, ROT 134 KLBS 200 GPM, 2285 PSI ON BOTTOM, 2274 PSI OFF BOTTOM, ROT 120-150 RPM, 12-13 KFT-LBS TRQ, 10-15 KLBS WO ECD ACTUAL= 11.7 PPG EMW MUD WEIGHT IN/OUT = 10.5 PPG NO LOSSES TO FORMATION WHILE DRILLING AHEAD SURVEY EVERY 30' FOR DOGLEGS > 51/100' NO BACKREAMING AT CONNECTIONS DIRECTIONAL DRILL ON PLAN: BUILD STARTING AT 14,550' MD FROM 51 ° TO 1070 Printed 1/10/2018 5:03:39PM 'All depths reported in Drillers Depths` North America - ALASKA - BP Page 65 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 iX3-017WO-C: (6,876,211.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations - - .— (hr) (usft) 12:00 00:00 12.00 DRILL P 15,060.00 PROD1 DIRECTIONAL DRILL 6-1/8" PRODUCTION HOLE BUILD SECTION FROM 14,682' MD TO 15,060' MD, 6904' TVD - 378' IN 12 HRS = 31.5 FPH WITH CONNECTIONS j ROP LIMIT 70 FPH - PU 198 KBLS, SO 100 KLBS, ROT 130 KLBS -200 GPM, 2350 PSI ON BOTTOM, 2337 PSI OFF BOTTOM, ROT 120-150 RPM, 12-13 KFT-LBS TRQ, 12-17 KLBS WOB ECD ACTUAL= 11.9 PPG EMW MUD WEIGHT IN/OUT = 10.5 PPG NO LOSSES TO FORMATION WHILE DRILLING AHEAD SURVEY EVERY 30' FOR DOGLEGS > 5°/100' NO BACKREAMING AT CONNECTIONS DIRECTIONAL DRILL ON PLAN: LAND BUILD SECTION AT 14;878' MD (6935' TVD) AND BUILD TO 104- 12.00 DRILL P 15,435.00 PROD1 DIRECTIONAL'DRILL6-1/8"PRODUCTION 11/22/2017 00:00 12:00 HOLE BUILD SECTION FROM 15,060' MD TO 15,435' MD IN THE KUPARUK RESERVOIR - 375' IN 12 HRS = 31.3 FPH WITH CONNECTIONS ROP LIMIT 70 FPH PU 179 KBLS, SO 100 KLBS, ROT 130 KLBS 200 GPM, 2347 PSI ON BOTTOM, 2305 PSI OFF BOTTOM, ROT 150 RPM, 13-14 KFT-LBS TRQ, 14-16 KLBS WOB ECD ACTUAL = 11.96 PPG EMW MUD WEIGHT IN/OUT = 10.5 PPG SURVEY EVERY 30' FOR DOGLEGS > 5°/100' NO BACKREAMING AT CONNECTIONS DYNAMIC LOSS RATE 120 BPH INITIAL, SLOWED TO 30 BPH. NOVOS ENABLED AND ALL CONNECTIONS MADE PER THE AGREED CONNECTION PRACTICES 12:00 - 19:00 7.00 DRILL P 15,693.00 PROD1 DIRECTIONAL DRILL 6-1/8" PRODUCTION HOLE BUILD SECTION FROM 15,435' MD TO 15,693' MD (6832' TVD) IN THE KUPARUK RESERVOIR 258' IN 7 HRS = 36.9 FPH WITH CONNECTIONS ROP LIMIT 70 FPH PU 174 KBLS, SO 95 KLBS, ROT 133 KLBS 200 GPM, 2330 PSI ON BOTTOM, 2270 PSI OFF BOTTOM, ROT 150 RPM, 13-14 KFT-LBS 'TRQ, 14-16 KLBS WOB ECD ACTUAL = 11.84 PPG EMW MUD WEIGHT IN/OUT = 10.5 PPG SURVEY EVERY 30' FOR DOGLEGS > 51/100' NO BACKREAMING AT CONNECTIONS DYNAMIC LOSS RATE 30 BPH NOVOS ENABLED AND ALL CONNECTIONS MADE PER THE AGREED CONNECTION PRACTICES OBSERVED SIGNIFICANT GAMMA SPIKE AT 15,693' MD (6832' TVD). DRILLED UP INTO THE KALUBIK. GEOLOGIST CALLED TD -46' MD EARLY Printed 1/10/2018 5:03:39PM `All depths reported in Drillers Depths` North America - ALASKA - BP Page 66 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00) - - - -- Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 19:00 - 22:00 3.00 DRILL P 15,693.00 PROD1 CIRCULATE HOLE CLEAN WITH 2X BOTTOM UP 200 GPM, 2330 PSI, 140 RPM, RECIPROCATING AT 300 FPH PU 178 KLBS, SO 104 KLBS, 130 KLBS RACK BACK A STAND WITH EACH BOTTOMS UP 2.00 DRILL DYNAMIC LOSS RATE 25 BPH P 15,693.00 PROD1 SHORT TRIP BACK TO THE 7" CASING SHOE: 22:00 00:00 PUMP OUT OF THE HOLE AT 2 BPM, 630 PSI PULLING AT <70 FPM FROM 15,600' MD TO 14,900' MD MONITOR • THE WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM: STATIC 11/23/2017 00:00 01:30 1.50 DRILL P 15,693.00 PROD1 CONTINUE SHORT TRIP BACK TO THE 7" CASING SHOE: PUMP OUT OF THE HOLE AT 2 BPM, 630 PSI PULLING AT <70 FPM - FROM 14,900' MD TO 14,100' MD, INSIDE THE 7" CASING SHOE - MONITOR THE WELL FOR 10 MIN AT THE 7" CASING SHOE: STATIC 15,693.00 PROD1 CONDITION MUD AND CIRCULATE 3X 101:30 06:00 4.50 DRILL P BOTTOMS UP AT THE 7" CASING SHOE 200 GPM, 2250 PSI, 120 RPM, RECIPROCATING AT 300 FPH DYNAMIC LOSS RATE 15 BPH 06:00 07:00 1.00 DRILL - P- 15,693.00 PROD1 RUN IN THE HOLE ON ELEVATORS FROM 14,100' MD TO 15,693' MD RUN IN THE HOLE AT 75 FPM MONITOR DISPLACEMENT WITH THE TRIP TANK 07:00 - 10:00 3.00 DRILL P - 15,693.00 PROD1 STAGE UP PUMPS IN 1 BBL INCREMENTS AND CIRCULATE HOLE CLEAN WITH 2X BOTTOM UP - 200 GPM, 2340 PSI, 120 RPM, RECIPROCATING AT 300 FPH - PU 178 KLBS, SO 104 KLBS, 130 KLBS 110:00 13:30 3.50 DRILL _ P 15,693.00 PROD1 PUMP OUT OF THE HOLE AT 2 BPM, 670 PSI PULLING AT <70 FPM - FROM 15,693' MD TO 14,021' MD, INSIDE THE 7" CASING SHOE - MONITOR THE WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM: STATIC PU 185 KLBS, SO 105 KLBS AT 14,021' MD 13:30 - 16:30 3.00 DRILL P 15,693.00 PROD1 CONDITION MUD AND CIRCULATE 3X BOTTOMS UP AT THE 7" CASING SHOE - 200 GPM, 2255 PSI, 120 RPM, RECIPROCATING AT 300 FPH 16:30 - 00:00 7.50 DRILL P 15,693.00 PROD1 CONTINUE TO PUMP OUT OF THE HOLE AT 2 BPM PULLING AT <70 FPM FROM 14,021' MD TO 7965' MD MONITOR THE WELL FOR 10 MIN AT THE 7" CASING SHOE: STATIC - PU 167 KLBS, SO 110 KLBS AT 14,021' MD 11/24/2017 00:00 0900 9.00 DRILL P 15,693.00 PROD1 CONTINUE TO PUMP OUT OF THE HOLEAT2 BPM PULLING AT <70 FPM - FROM 7965' MD TO 200' MD - MONITOR THE WELL FOR 10 MIN AT THE BHA: STATIC Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths* North America - ALASKA - BP Page 67 of 67 Operation Summary Report Common Well Name: S-200 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 X3-017WO-C: (6,876,211.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 09:00 09:30 0.50 BOPSUR P 15,693.00 PROD1 PERFORM WEEKLY BOPE FUNCTION TEST SUCK OUT STACKAND FUNCTION ANNULAR, PIPE RAMS AND HCR VALVES ANNULAR 15 SEC TO CLOSE UPPER RAMS 7 SEC TO CLOSE LOWER RAMS 6 SEC TO CLOSE HCR KILLAND CHOKE 2 SEC EACH TO 'CLOSE WILL FUNCTION BLIND RAMS WHEN BHA IS OUT OF THE HOLE 1.00 DRILL P 15,693.00 PROD' LAY DOWN &1/V' DRILLING BHAAND CLEA 09:30 10:30 RIG FLOOR DULL BIT GRADE: 2 -2 -WT -S -X -I -CT - TD COMPLETE WEEKLY BOPE FUNCTION TEST, BLIND / SHEAR RAMS 9 SEC TO CLOSE END OP S -200A RON EVENT. BEGIN S -200A CON EVENT. Printed 1/10/2018 5:03:39PM *All depths reported in Drillers Depths` • 0 Printed 1/10/2018 5:05:o4PM 'All dephts reported in Drillers Depths' North America - ALASKA - BP Page 1 of 6 Operation Summary Report Common Well Name: S-200 AFE No Event Type: COM- ONSHORE (CON) Start Date: 11/24/2017 End Date: 11/27/2017 X3-017WO-C: (3,220,789.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USAOO000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations -- (hr) (usft) 11/24/2017 10:30 - 11:30 1.00 CASING P 15,693.00 RUNPRD RIG UP TO RUN 4-1/2", 13.5 LB/FT, 13CR85 HYDRIL 521 LINER - RIG UP DOYON CASING WITH TORQUE TURN 11:30 16:00 4.50 CASING P 15,693.00 ! RUNPRD RUN 4-1/2", 13.5 LB/FT, 13CR85 HYDRIL 521 LINER TO 1688' MD VERIFY FLOATS: GOOD BAKERLOK SHOE TRACK JTS - USE JET LUBE SEAL GUARD (F.F = 1.0) ON ALL HYDRIL CONNECTIONS - TORQUE ALL HYDRIL 521 CONNECTIONS TO 5000 FT -LB - RUN 2 FLOATING CENTRALIZERS ON JOINTS 1-36 TOTAL CENTRALIZERS RUN = 75, TOTAL STOP RINGS = 113 - RATAG 1N STOP RING ON JOINT #6 (PLANNED RA TAG DEPTH 15,391' MD) TOP OFF LINER EVERY 20 JOINTS -RUN IN THE -HOLE AT 45 FPM {MAKE UP WEATHERFORD WTSP4H3/WPHR 7" x 5" LINER HANGER / LINER TOP PACKER ASSEMBLY PER WEATHERFOR REPRESENTATIVE LINER HANGER PINNED TO SHEAR AT 2200 PSI - LINER TOP PACKER PINNED TO SHEAR AT 34 KLBS - BREAK CIRCULATION AND STAGE PUMPS UP 4 BPM, 195 PSI PU 68 KLBS, SO 68 KLBS SIMOPS: HELD RIG MOVE PLANNING MEETING FOR UPCOMING MOVE TO L -205A 16:00 - 00:00 8.00 CASING L P 15,693.00 RUNPRD RUN 4-1/2", 13.5 LB/FT HYDRIL 521 LINER ON 3-1/2" DRILL PIPE FROM 1754' MD TO 12,074' MD RUN IN THE HOLE ON ELEVATORS AT 45 FPM FILL PIPE EVERY -1000' MD OBTAIN PU/SO WEIGHTS EVERY -1000' PU 144 KLBS, SO 98 KLBS AT 12,074' MD 11/25/2017 00:00 01:30 1.50 CASING P 15,693.00 RUNPRD RUN 4-1/2", 13.5 LB/FT HYDRIL 521 LINER ON 3-1/2" DRILL PIPE FROM 12,074' MD TO 14,052' MD -RUN IN THE HOLE ON ELEVATORS AT 45 FPM FILL PIPE EVERY -1000' MD -OBTAIN PU/SO WEIGHTS EVERY -1000' Printed 1/10/2018 5:05:o4PM 'All dephts reported in Drillers Depths' North America - ALASKA - BP Page 2 of 6 Operation Summary Report Common Well Name: S-200 AFE No Event Type: COM- ONSHORE (CON) Start Date: 11/24/2017 End Date: 11/27/2017 X3-017WO-C: (3,220,789.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To i Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 01:30 - 05:30 4.00 CASING P 15,693.00 RUNPRD CIRCULATEANDCONDITIONMUD AT 7" CASING SHOE STAGE UP PUMPS TO 4.5 BPM, 1375 PSI CIRCULATE A TOTAL OF 2.5x BOTTOMS UP INDICATIONS OF BARITE SAG NOTED WITH LIGHTER MUD WEIGHTS OUT MW IN/OUT 10.5 PPG - CHANGE OUT PS21 SLIP INSERTS FOR 4" DRILL PIPE 05:30 08:30 3.00 CASING P 15,693.00 RUNPRD CONTINUE TO RUN 4-112",13.5 LB/FT HYDRIL 521 LINER ON 4" DRILL PIPE FROM 14,052' MD TO TD AT 15,659' MD - RUN IN THE HOLE ON ELEVATORS AT 45 FPM FILL PIPE EVERY 1000' MID MUD WEIGHT IN/OUT =-10.5 PPG PU = 170 KLBS, SO = 95 KLBS 35K DRAG ENCOUNTERED -14,770' MD WASH DOWN (2) STANDS FROM 14,770' MD TO 14,900' MD NO ISSUES RUNNING LINER TO TD FROM 14,900' MD WASH DOWN LAST STAND AND TAG 0.50 CASING P 15,693.00 BOTTOM WITH 10 KLBS DOWN RUNPRD SPACE OUT AND RIG UP CEMENT HEAD AND 08:30 09:00 CEMENT HOSE PER WEATHERFORD REP 0_ 0 14:30 5.50 CASING P 15,693.00 RUNPRD STAGE UP PUMPS IN 1 BBL INCREMENTS AND CONDITION MUD TO CEMENTING PROPERTIES @ 1 BPM = 500 PSI @ 2 BPM = 700 PSI @3BPM =1140 PSI @ 4 BPM = 1650 PSI INITIAL PRESSURE AT CIRCULATING RATE _ 1610 PSI - FINAL CIRCULATING PRESSURE = 1330 PSI MUD WEIGHT IN/OUT = 10.5 PPG NO RECIPROCATION WHILE CIRCULATING Printed 1/10/2018 5:05:04PM *All dephts reported in Drillers Depths` Printed 1/10/2018 5:05:04PM `All dephts reported in Drillers Depths` North America - ALASKA - BP Page 3 of 6 Operation Summary Report Common Well Name: S-200 AFE No Event Type: COM- ONSHORE (CON) Start Date: 11/24/2017 End Date: 11/27/2017 X3-017WO-C: (3,220,789.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 114:30 16:30 2.00 CEMT P i5,643.013 RUNPRD I CEMENT 4-1/2" PRODUCTION LINER AS FOLLOWS: - FILL LINES WITH MUD PUSH AND PRESSURE TEST TO 4500 PSI FOR 5 MINUTES PUMP 25 BBLS OF 13 PPG MUD PUSH II SPACER @ 3.5 BPM, 930 PSI PUMP 65 BBLS OF 15.8 PPG GASBLOK CEMENT @ 3.5 BPM, EXCESS VOLUME -95% (YIELD 1.17 CUFT/SK), ICP = 903 PSI, FCP = 509 PSI - WASH UP CEMENT IN LINES (NO CEMENT LEFT ON TOP OF DRILL PIPE DART) RELEASE DART FROM WEATHERFORD CEMENT HEAD PERFORM DISPLACEMENT WITH SCHLUMBERGER CEMENT UNIT: - 85 BBLS 9.8 PPG BRINE @ 3.5 BPM: ICP = 1327 PSI, FGP = 1246 PSI - 10 BBLS 9.8 PPG BRINE @ 3 BPM FOR DART LATCH. OBSERVE DART LATCH WITH 400 PSI, AT 97 BBLS DISPLACED - 13 BBLS 9.8 PPG BRINE @ 3.5 BPM, ICP 1717 PSI, FCP 1517 PSI - 11.3 BBLS 9.8 PPG BRINE @ 3 BPM, OBSERVE PLUG BUMP AT 121.3 BBLS AWAY - TOTAL: 121.3 BBLS DISPLACED AT 3-3.5 - BPM: ICP 1327 PSI, 1517 PSI INCREASE PRESSURE TO 2578 PSI, 1000 PSI j OVER FINAL CIRCULATING PRESSURE, HOLD 5 MIN - CHECK FLOATS: FLOATS HOLDING TOTAL DISPLACEMENT VOLUME 121.3 BBLS (MEASURED BY SCHLUMBERGER MICROMOTION) - TOTAL LOSSES FROM START OF JOB TO CEMENT IN PLACE: 15 BBLS - TOTAL LOSSES AFTER CEMENT ROUNDED THE SHOE: 3 BBL CEMENT IN PLACE AT 16:10 HRS 1000 PSI CEMENT COMPRESSIVE STRENGTH REACHED AT 05:17 HRS ON 11/25/2017 - NO RECIPROCATION DURING CEMENT JOB SEE ATTACHED CEMENTING DOCUMENTS Printed 1/10/2018 5:05:04PM `All dephts reported in Drillers Depths` North America - ALASKA - BP Page 4 of 6 Operation Summary Report Common Well Name: S-200 AFE No Event Type: COM- ONSHORE (CON) Start Date: 11/24/2017 End Date: 11/27/2017 X3-017WO-C: (3,220,789.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO_ BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 16:30 19:30 3.00 CEMT P 15,693.00 RUNPRD SET LINER HANGER / LINER TOP PACKER AND CIRCULATE OUT EXCESS CEMENT - INCREASE PRESSURE TO 3500 PSI AND SET LINER HANGER PER WEATHERFORD REPRESENTATIVE - SET DOWN 70 KLBS AND CONFIRM HANGER SET - PRESSURE UP TO 4000 PSI AND RELEASE THE LINER RUNNING TOOL. - PICK UP AND EXPOSE DOG SUB ROTATE AT 15 RPM AND SET DOWN 70 KLBS TO SET LINER TOP PACKER PRESSURE UP TO 1000 PSI PICK UP TO PULL PACK -OFF OUT OF PBR AND OBSERVE PRESSURE DROP OFF - BRING ON PUMPS TO CIRCULATE OUT EXCESS CEMENT AND PULL PACK -OFF CLEAR OF PBR 7.5 GPM, 3650 PSI CIRCULATEOUT30 BBLS OF CEMENT AND DISPLACE WELL TO 9.8 PPG KCL 2.50 19:30 22:00 CEMT P 15,693.00 RUNPRD LAY DOWN CEMENT HEAD AND PULL OUT OF THE HOLE, LAYING DOWN 4" DRILL PIPE TO THE PIPE SHED, FROM 13,936' MD TO 12,393' MD FLOW CHECK WELL FOR 10 MIN: STATIC PU 174 KLBS, SO 108 KLBS AT 13,936' MD MONITOR HOLE FILL WITH THE TRIP TANK: GOOD FILL. 22 00 00:00 2.00 CEMT P 15,693.00 RUNPRD PULL OUT OF THE HOLE, STANDING BACK 3-1/2" DRILL PIPE, FROM 12,393' MD TO 9365' MD CHANGE OUT PS21 INSERTS FOR 3-1/2" DRILL PIPE - PU 166 KLBS, SO 102 KLBS AT 12,393' MD - MONITOR HOLE FILL WITH THE TRIP TANK: GOOD FILL. SIMOPS: - LAY DOWN 3-1/2" DRILL PIPE STANDS WITH OFF-LINE STAND BUILDING EQUIPMENT WHILE PULLING OUT OF THE HOLE 15,693.00 RUNPRD CONTINUE TO PULL OUT OF THE HOLE, 11/26/2017 00:00 03:30 3.50 CEMT P STANDING BACK 3-1/2" DRILL PIPE, FROM 9365' MD TO SURFACE PU 130 KLBS, SO 95 KLBS AT 8020' MD MONITOR HOLE FILL WITH THE TRIP TANK: GOOD FILL. - LAY DOWN LINER RUNNING TOOL; NO ISSUES NOTED SIMOPS: LAY DOWN 3-1/2" DRILL PIPE STANDS WITH OFF-LINE STAND BUILDING EQUIPMENT WHILE PULLING OUT OF THE HOLE 15,693.00 RUNCMP PULL 6-15/16" WEAR BUSHING 03:30 04:00 0.50 RUNCOM P CLEAN AND CLEAR RIG FLOOR SUCK OUT STACK +_PULL WEAR RING Printed 1/10/2018 5:05:04PM *All dephts reported in Drillers Depths* North America - ALASKA - BP Page 5 of 6 Operation Summary Report Common Well Name: S-200 AFE No Event Type: COM- ONSHORE (CON) Start End Date: 11/27/2017 X3-017W0-C: (3,220,789.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:00AM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 04:00 05:30 1.50 RUNCOM P 15,693.00 RUNCMP RIG UP TO RUN 4-1/2",12.6 LB/FT VAMTOP COMPLETION (- RIG UP DOYON CASING TONGS AND TORQUE TURN EQUIPMENT - ORGANIZE COMPLETION JEWELRY IN PIPE SHED 05:30 06:30 1.00 RUNCOM P 15,693.00 RUNCMP RIG UP AND PRESSURE TEST 4-1/2" LINER AtjD LINER TOP PACKER TO 3500 PSI FOR 45 CHARTED MIN WITH 9.8 PPG KCL BRINE - REVIEW WORKING WITH PRESSURE CROSSCHECK CHECKLIST - 6.4 BBLS TO PRESSURE UP, BLED BACK 6.4 BBLS - HELD TEST FOR AN ADDITIONAL 15 MIN (45 MIN TOTAL) TO MEET BP TESTING CRITERIA PER 100218 SEE ATTACHED TEST CHARTAND CRITERIA j CALCULATOR TESTAPPROVED BY WSUP RICH BURNETT RUNCMP RUN 4-1/2"; 12.6 LB/FT, 13CR-85, VAMTOP 06:30 - 00:00 17.50 RUNCOM P 15,693.00 COMPLETION PER THE APPROVED RUN TALLY TO 13,320' MD BACKERLOK ALL CONNECTIONS BELOW THE PACKER USE JET LUBE SEAL GUARD PIPE DOPE ON ALL VAMTOP CONNECTIONS TORQUE TURN ALL VAMTOP CONNECTIONS TO 4440 FT-LBS RUN IN THE HOLE AT 90 FT/MIN PU 130 KLBS, SO 80 KLBS AT 13,320' MD REPLACE JTS #220 AND #221 WITH SPARES DUE TO POOR MAKE UP SIMOPS: - LAY DOWN 3-1/2" DRILL PIPE STANDS WITH OFF -LINE STAND BUILDING EQUIPMENT WHILE RUNNING COMPLETION RUNCOM P 15,693.00 RUNCMP CONTINUE TO RUN 4-1/2", 12.6 LB/FT, 11/27/2017 00:00 01:30 1.50 13CR-85, VAMTOP COMPLETION FROM 13,320' MD TO 13,886' MD USE JET LUBE SEAL GUARD PIPE DOPE ON ALL VAMTOP CONNECTIONS TORQUE TURN ALL VAMTOP CONNECTIONS TO 4440 FT-LBS RUN IN THE HOLE AT 90 FT/MIN t j PU 140 KLBS, SO 80 KLBS AT 13,886' MD SIMOPS: LAY DOWN 3-1/2" DRILL PIPE STANDS WITH OFF -LINE STAND BUILDING EQUIPMENT WHILE RUNNING COMPLETION Printed 1/10/2018 5:05:04PM 'All dephts reported in Drillers Depths' North America - ALASKA - BP Operation Summary Report Page 6 of 6 Common Well Name: S-200 AFE No Event Type: COM- ONSHORE (CON) Start Date: 11/24/2017 End Date: 11/27/2017 X3-017WO-C: (3,220,789.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: PARKER 272 Spud Date/Time: 12/15/1997 12:00:OOAM Rig Release: 11/27/2017 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000172 Active datum: S-200AActual (d82.32usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) _ 01:30 - 03:30 2.00 RUNCOM P 15,693.00 RUNCMP SPACE OUT AND LAND 4-1/2" VAMTOP COMPLETION - TAG BOTTOM OF PBR 8' IN ON JT #329 (13,977' MD) - 4-1/2" LINER TOP AT 13,966' MD - LAY DOWN JTS 329-326 AND PICK UP SPACE OUT PUP JTS - MAKE UP (4) PUPS FOR A TOTAL OF 39.26' AND JT #326 - SPACE OUT WITH WLEG 6.19' INTO PBR ON 4-1/2" LINER (13,972' MD) MAKE UP TUBING HANGER AND TUBING PUP - FINAL PU'140 KLBS,-SO 80 KLBS LAND HANGER AND RUN IN LOCK DOWN SCREWS PER FMC REPRESENTATIVE 03:30 05:00 1.50 RUNCOM P 15,693.00 RUNCMP PUMP 17 BBLS OF DIESEL FREEZE PROTECT RIG UP AND REVERSE IN 17 BBLS OF DIESEL TO THE tAAT 2 BPM ALLOW WELL TO U -TUBE 1 HOUR BLEED OFF PRESSURE, OPEN WELLAND CONFIRM WELL STATIC I SIMOPS: RIG DOWN TUBING HANDLING EQUIPMENT 05:00 06:00 1.00 RUNCOM- P 15,693.00 RUNCMP DRY ROD IN TYPE'H' TWC PER FMC REPRESENTATIVE AND PRESSURE TEST FROM BELOW TO 3500 PSI FOR 5 MIN, GOOD TEST. 06:00 09:30 3.50 RUNCOM P - 15,693.00 RUNCMP NIPPLE DOWN BOPE STACK AND HIGH PRESSURE RISERS BLOW DOWN AND RIG DOWN ALL CIRCULATING LINES f PUMP OUT STACKAND CLEAN OUT FLOW BOX PULL MOUSEHOLE AND RIG DOWN HOLE FILL LINE AND LOW PRESSURE RISER NIPPLE DOWN AND SET BACK BOP STACK ON STUMP NIPPLE DOWN HIGH PRESSURE RISERS AND LAY DOWN TO PIPE SHED 09:30 12:00 2.50 RUNCOM P 15,693.00 RUNCMP NIPPLE UPADAPTER FLANGE AND TREE I- NIPPLE UP ADAPTER FLANGE AND DRY HOLE TREE - PRESSURE TEST TUBING HANGER VOID TO 4500 PSI FOR 15 MIN, GOOD TEST - WSUP APPROVED PRESSURE TEST INSTALLANNULUS VALVE JEWELRY PRESSURE TEST TREE TOO 4500 PSI LEAK TIGHT FOR 5 MIN, GOOD TEST - SECURE TREE CELLAR RELEASE RIG AT 12:00 HRS SIMOPS: GENERAL RIG DOWN OPERATIONS THROUGHOUT RIG Printed 1/10/2018 5:05:04PM *All dephts reported in Drillers Depths' 0 Daily Report of Well Operations S -200A Arl-rR 1ITVfI ATC CI IMMARV 0 T/1/0= BPV/0/0. Barriers= BPV x MV (23.5 turns) . Removed Piggyback valves TEMP # 11 and TEMP #74 . Removed 4" SV TEMP #17 . Installed 4" upper tree, serial #121018560-2 . Torqued to API specs. PT'd IA, OA tapped blind flanges. RDMO***Job 11/29/2017 In Progress'. SEE LOG FOR DETAILS. Final T/1/0= BPV/0/0. T/I/O=TWC/0/0 PT'd production tree against TWC. Pulled 4" CIW "H" TWC #439. FWP's 12/13/2017 0/0/0 see log for details T/1/0=50/50/130 SI Assist SL with CircOut/MITs (SIDETRACK) MIT T to 3862 psi ***PASSED*** Target pressure=3500 psi Max applied=4000 psi CMIT TxIA to 3880/3920 psi ***PASSED*** Target pressure=3500 psi Max applied=4000 psi Pumped 5 bbls 60/40 followed by 412 bbls Corrosion Inhibited Brine, 69 bbls crude down IA up TBG taking returns to S-118 FL. Pumped 5 bbls 60/40 down S-118 FL for FP. U -Tube crude TxIA for 1 hr. SL dropped Rollerstem B&R downhole. Pumped 2.7 bbls crude down TBG to achieve test pressure of 4000 psi and set TNT packer. 15 min loss of 22 psi, 30 min loss of 17 psi, for total loss of 39 psi in 30 mins. Bleed TBG to IA for CMIT. Pumped 4.5 bbls crude down TxIA to achieve test pressure of 4000 psi. 15 min loss of 20/13 psi, 30 min loss of 18/11 psi, for total loss of 38/24 psi in 30 mins. Bleed TxIA to 0 psi. Bled back 7.2 bbls. See log for details Hang tags on WV/IA AFE sign hung on MV ***FLUID PACKED WELL*** SL 12/20/2017 on well upon departure. CVs OTG Hardline SI FWHP=40/45/80 ***WELL S/I ON ARRIVAL*** (Sidetrack) DRIFT W/ 3.00" S-BLR TO 4-1/2" RHC -M BODY @ 13,927' SLM / 13,955' MD (No issues). LRS CIRCULATED 406 BBLS OF 120* INHIBITED BRINE THEN U -TUBED 76 BBL FREEZE PROTECT. DEPLOY HES ROLLER BALL & ROD (Allowed ball & rod 20 minutes to reach RHC body). LRS SLOWLY PRESSURED UP ON TUBING TO SET 7" x 4-1/2" HES TNT PACKER AT 12,849' MD. LRS PERFORMED SUCCESSFUL MIT -T TO 3500 PSI. LRS PERFORMED SUCCESSFUL CMIT-T x IA TO 3500 PSI. LRS PERFORMED SUCCESSFUL 1000 PSI PRESSURE TEST ON IA TO CONFIRM 12/20/2017 PACKER SET (Tubing remained at 46 psi). ***CONTINUED FROM 12/20/17 WSR*** (Sidetrack) PULLED ST #5 BK-DGLV FROM 4,127' MD (s/d on vlv while rih & pulled w/ friction bind) PULLED ST #4 BK-DGLV FROM 6,886' MD & ST #6 BKE-SHEAR VLV FROM 3,512' MD PULLED BK -DLV FROM 6886' MD. SET BK-LGLV IN STA 6, BK-DGLV IN STA 5AND BK-OGLV IN STA 4. PULLED 4 1/2" RHCM PLUG BODY FROM 13955' MD. 12/21/2017 ***WELL LEFT SHUT IN. DSO WALK THROUGH UPON DEPARTURE*** 12/23/2017 CTU #9 - 1.75" Coil Job Scope: Log, Initial Perf Arrive on location and rig up. Make up 2 7/8" GR/CCL carrier with 3.45" JSN and RIH pumping 1 % KCI w/ SafeLube down the coil. Jet minor obstruction at 15396 CTMD and tag unjettable TD at 15515 CTMD. Log from TD to 9600' painting white/blue tie in flag at 12/23/2017 15425'. = 1640/620/80. RU Crown Valve, temp #24. PT'd, charted & retained. See Log for 12/23/2017 IT/I/O details. ***Job Complete*** 0 0 Daily Report of Well Operations S -200A CTU #9 - 1.75" Coil Job Scope: Log, Initial Perf Arrive on location and rig up. Make up 2 7/8" GR/CCL carrier with 3.45" JSN and RIH pumping 1 % KCI w/ SafeLube down the coil. Jet minor obstruction at 15396 CTMD and tag unjettable TD at 15515 CTMD. Log from TD to 9600' painting white/blue tie in flag at 15425'. OOH and GR on logging tools failed, it never turned on after being connected. Make up back up logging string and RIH w/ same 12/23/2017 ***In Progress*** CTU #9 - 1.75" Coil Job Scope: Log, Initial perf Drift to TD and log up from compression at 15525'. Log up to 9575' painting a new white/blue tie in flag at 15450'. POOH and +25' corr. and PBTD of 15546'. Discuss with town and Make up 2 7/8" motor and 3.66" insert mill. Tie in at flag and mill down to new corrected PBTD of 15589.03'. Chase OOH at 80%. 12/24/2017 ...Job in Progess... CTU #9 - 1.75" Coil Job Scope: Log, Initial pert Drift to TD and log up from compression at 15525'. Log up to 9575' painting a new white/blue tie in flag at 15450'. POOH and +25' corr. and PBTD of 15546'. Discuss with town and Make up 2 7/8" motor and 3.66" insert mill. Tie in at flag and mill down to new corrected PBTD of 15589.03'. Chase OOH at 80%.. OOH and contaminated cement coated on BHA, minimal wear on mill, gauge mill @ 3.65" Down stack to trim pipe and change pack offs 12/24/2017 CTU #9 - 1.75" Coil Job Scope: Log, Initial pert 12/24/2017 CTU #9 - 1.75" Coil 12/25/2017 Job Scope: Log, Initial pert CTU #9 - 1.75" Coil Job Scope: Log, Initial pert Make up 33'x 2 7/8" Maxforce pert gun and RIH. Tag PBTD for tie in and perforate 15554'- 15587'. POOH. Perform Weekly BOP test. Make up and RIH w/ gun run #2; 33'x 2-7/8" HES Maxforce guns 12/25/2017 ...Job in Progress... CTU #9 - 1.75" Coil Job Scope: Log, Initial perf Make up 33'x 2 7/8" Maxforce pert gun and RIH. Tag PBTD fpr tie in and perforate 15554'- 15587'. POOH. Perform Weekly BOP test. 12/25/2017 ...Job in Progress... CTU #9 - 1.75" Coil Job Scope: Log, Initial pert Tag PBTD @ 15589' and correct to top shot. Perforate interval #2; 15535'-15567' w/ 2-7/8" HES Maxforce guns 60* phasing, 6 SPF. Make up P/T gauges inside 2.2" Carrier and RIH taking returns. Perform stop counts at 14475, 14318, 14151. and 13967'. POP well with 0.5 MMscf/d AL rate to unload IA. Once IA was unloaded down to SO @ 6886' increased AL rate to 2.5 MMscf/d, notified PCC to line up for test. After two hours flow appeared to stabilize out at 210 psi WHP 63* F. POOH 12/26/2017 ...Job in Progress... Ll Daily Report of Well Operations S -200A T/1/0=200/1200/200 temp=70* Freeze protect TBG/FL (SIDETRACK) Pumped 38 bbls crude down TBG for FP. Pumped 3 bbls meth down FL for FP. Pad Op notified Vlave positions=SV WV SSV closed MV open CVs OTG AL closed Hardline SI 12/27/2017 FWHP=1200/900/50 CTU #9 - 1.75' Coil Job Scope: Log, Initial perf Continue POOH w/ SBHP gauges after well stabilized and flowing into test separator. Good Data from gauges. Pump corrosion inhibitor and blow down coil in prep for pipe swap. RDMO to SLB yard. 12/27/2017 ***Job Complete*** North America - ALASKA - BP Prudhoe Bay PB S Pad S-200 S -200A 500292284601 Design: S -200A Final Survey Re rt 30 November, 2017 0 I(E`.,.„, UGHES a GE company E • BP 0 by Final Survey Report UGHES 14"fl, Company: North America - ALASKA - BP Project: Prudhoe Bay Site: PB S Pad Well: S-200 Wellbore: S -200A Design: S -200A Project Prudhoe Bay, PBU, PRUDHOE Map System: Alaska NAD27 State Plane Zones System Datum: Geo Datum: NAD27 OGP-Usa AK [4267*15864) Map Zone: NAD27 OGP-Usa AK Alaska zone 4 [26734*1586, Using geodetic scale factor Site PB S Pad, TR -12-12 5,980,654.540 usft Latitude: Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 usft Slot Radius: Well S-200, SB -01 Longitude: 149' 2'2,971 W Well Position +N/ -S 0.00 usft Northing: +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore S -200A Magnetics Model Name Sample Date Declination BGGM2017 10/9/2017 17.61 Design S -200A Audit Notes: 305.55 Version: Phase: ACTUAL Tie 0 Vertical Section: Depth From (TVD) +N/ -S +E/ -W (usft) (usft) (usft) 45.69 0.00 0.00 1113012017 11:49:35AM Page 2 COMPASS 5000.1 Build 81D Local Co-ordinate Reference: Well S-200 TVD Reference: S -200A Actual @ 82.32usft (P272 Actual RKB) MID Reference: S -200A Actual @ 82.32usft (P272 Actual RKB) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM R5K - Alaska PROD - ANCP1 System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,980,654.540 usft Latitude: 70o 21'23.002 N 617,919.920 usft Longitude: 1490 2'32.343 W 0.000 in Grid Convergence: 0.90 5,980,504.880 usft Latitude: 70' 21' 19.407 N 618,930.260 usft Longitude: 149' 2'2,971 W 36.63 usft Ground Level: 36.10 usft Dip Angle Field Strength (nT) 80.99 57,496 n Depth: 2,702.61 Direction 305.55 1113012017 11:49:35AM Page 2 COMPASS 5000.1 Build 81D BP 40 by Final Survey Report HPIGHES 0 "GI Pa i; Company: North America - ALASKA - BP Local Co-ordinate Reference: Well S-200 Project: Prudhoe Bay TVD Reference: S -200A Actual @ 82.32usft (P272 Actual RKB) Site: PB S Pad MD Reference: S -200A Actual @ 82.32usft (P272 Actual RKB) Well: S-200 North Reference: True Wellbore: S -200A Survey Calculation Method: Minimum Curvature Design: S -200A Database: EDM R5K - Alaska PROD - ANCP1 Survey Program Date 11/30/2017 From TO (usft) (usft) Survey (Wellbore) Tool Name Description 132.80 2,702.61 Survey #1 MWD (S-200PB1) MWD MWD - Standard • 2,734.00 3,158.69 Gyrodata GWD 8-1/2" (S -200A) GYRO -WD -SS Gyro while drilling single shots 3,253.13 14,108.45 BHGE OTK MWD 8-1/5 x 9-7/8" (S -200A) MWD+lFR+MS-WOCA MWD + IFR + Multi Station W10 Crustal 14,172.13 15,658.36 BHGE OTK MWD 6-1/8" (S -200A) MWD+lFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal Survey MD Inc Azi (azimuth) TVD TVDSS N/S E/W Northing Easting DLeg V. Sec (usft) V) (I (usft) (usft) (usft) (usft) (usft) (usft) (*/100usft) (usft) 45.69 0.00 0.00 45.69 -36.63 0.00 0.00 5,980,504.880 618,930.260 0.00 0.00 132.80 0.18 105.08 132.80 50.48 -0.04 0.13 5,980,504.847 618,930.393 0.21 -0.13 266.74 0.22 105.08 266.74 184.42 -0.16 0.58 5,980,504.732 618,930.846 0.03 -0.57 354.93 0.28 125.59 354.93 272.61 -0.33 0.92 5,980,504.568 618,931.187 0.12 -0.94 446.77 0.14 326.02 446.77 364.45 -0.36 1.04 5,980,504.532 618,931.308 0.45 -1.06 535.82 0.62 308.78 535.82 453.50 0.03 0.61 5,980,504.917 618,930.865 0.55 -0.48 626.72 1.28 320.73 626.70 544.38 1.12 -0.42 5,980,505.995 618,929.822 0.75 0.99 716.48 2.30 316.85 716.42 634.10 3.21 -2.29 5,980,508.055 618,927.923 1.14 3.73 805.86 3.33 314.71 805.69 72337 6.35 -5.36 5,980,511.140 618,924.802 1.16 8.0510 898.95 3.34 314.25 898.62 816.30 10.14 -9.22 5,980,514.873 618.920.879 0.03 13.40 994.25 3.21 312.16 993.77 911.45 13.87 -13.19 5,980,518.537 618.916.854 0.19 18.79 1,089.60 3.24 314.39 1,088.96 1,006.64 17.55 -17.09 5,980,522.151 618,912.892 0.14 24.11 1,183.39 3.19 314.65 1,182.61 1.100.29 21.23 -20.84 5,980,525.779 618,909.084 0.06 29.30 1,277.35 3.09 318.61 1,276.43 1,194.11 24.97 -24.38 5,980,529.459 618,905.491 0.25 34.35 1,372.72 3.03 322.15 1,371.66 1,289.34 28.89 -27.62 5,980,533.325 618.902.183 0.21 39.27 1,467.52 3.13 322.60 1,466.32 1,384.00 32.92 -30.73 5,980,537.310 618,899.011 0.11 44.15 1,563.96 2.68 322.39 1,562.64 1,480.32 36.80 -33.71 5,980,541.139 618,895.975 0.47 48.82 1,660.11 3.31 323.45 1,658.66 1,576.34 40.81 -36.73 5,980,545.101 618,892,887 0.66 53.62 1,755.35 3.32 326.20 1,753.74 1,671.42 45.31 -39.90 5,980,549.550 618,889.644 0.17 58.81 1,850.59 3.23 327.79 1,848.82 1,766.50 49.88 -42.87 5,980.554.064 618,886,608 0.13 63.88 1113012017 11:49:35AM Page 3 COMPASS 5000.1 Build 81D BPBA ER 0by Final Survey Report BAT a GE company Company: North America - ALASKA - BP Local Coordinate Reference: Well S-200 Project: Prudhoe Bay TVD Reference: S-200AActual @ 82.32usft (P272 Actual RKB) Site: PB S Pad MD Reference: S-200AActual @ 82.32usft (P272 Actual RKB) Well: S-200 North Reference: True Wellbore: S -200A Survey Calculation Method: Minimum Curvature Design: S -200A Database: EDM R5K - Alaska PROD - ANCP1 Survey MD Inc Azi (azimuth) TVD TVDSS N/S E/W Northing Easting DLeg V. Sec (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (°/100usft) (usft) 1,945.48 3.30 317.62 1,943.56 1,861.24 54.15 -46.13 5,980,558.291 618,883.275 0.61 69.0* 2,035.51 5.05 310.18 2,033.35 1,951.03 58.63 -50.91'` 5,980,562.685 618,878.431 2.03 75.51 2,128.56 6.88 309.58 2,125.89 2,043.57 64.82 -58.33 5,980,568.760 618,870.909 1.97 85.15 2,224.68 9.36 311.56 2,221.04 2,138.72 73.67 -68.62 5,980,577.449 618,860.483 2.60 98.67 2,319.11 11.66 309.14 2,313.88 2,231.56 84.79 -81.77 5,980,588.357 618,847.160 2.48 115.83 2,414.98 11.50 311.35 2,407.80 2,325.48 87.22 -96.46 5,980,600.551 618,832.278 0.49 135.01 2,511.19 14.38 311.75 2,501.55 2,419.23 111.52 -112.57 5,980,614.586 618,815.938 2.99 156.43 2,606.10 18.41 311.50 2,592.59 2,510.27 129.34 -132.60 5,980,632.050 618,795.635 4.25 183.06 2,702.61 21.77 311.79 2,683.21 2,600.89 151.33 -157.37 5,980,653.683 618,770.526 3.48 216.02 2,734.00 22.49 311.69 2,712.29 2,629.97 159.21 -166.19 5,980,661.414 618,761.579 2.30 227.78 2,734.03 22.49 311.69 2,712.32 2,630.00 159.21 -166.20 5,980,661.421 618,761.570 0.00 227.79 9 5/8" Surface Casing 2,748.00 22.11 316.00 2,725.24 2,642.92 162.88 -170.02 5,980,665.029 618,757.691 12.02 233.03 2,777.56 21.40 318.52 2,752 2,670.38 170.92 -177.46 5,980,672.951 618,750.129 3.97 243.76 2,840.84 23.10 320.27 2, 26 2,728.94 189.12 -193.04 5,980,690.898 618,734.261 2.88 267.01 2,873.08 24.25 320.98 2,84 2,758.47 199.13 -201.25 5,980,700.773 618,725.892 3.67 279.51 2,967.79 28.11 324.84 2,925.7 2,843.45 232.50 -226.35 5,980,733.735 618,700.263 4.45 319.34 3,061.14 31.98 325.20, 3,006.57 2,924.25 270.79 -253.14 5,980,771.594 618,672.878 4.15 363.39 3,158.69 35.17 324.84 3,087.83 3,005.51 314.98 -284.07 5,980,815.287 618,641.253 3.28 414.25 3,253.13 35.39 326.43 3s4 4.93 3,082.61 360.01 -314.85 5,980,859.812 618,609.760 1.00 465.48 3,265.60 35.89 326.48 3,175.06 3,092.74 366.06 -318.87 5,980,865.803 618,605.649 4.02 472.27 3,359.29 39.67 328.`06 3,249.10 3,166.78 414.35 -349.86 5,980,913.591 618,573.892 4.16 525.56 3,454.17 43.06 328.76 3,320.30 3,237.98 467.76 -382.69 5,980,966.467 618,540.222 3.61 583.32 3,548.80 46.68 329.49 3,387.35 3,305.03 525.06 -416.94 5,981,023.209 618,505.077 3.86 644.50 3,643.62 49.93 *~329.48 3,450.42 3,368.10 586.04 -452.88 5,981,083.613 618,468.171 3.43 709.20 3,738.03 52.78 330.34 3,509.37 3,427.05 649.84 -489.84 5,981,146.811 618,430.211 3.10 776.36 3,832.62 56.02 330.66 3,564.42 3,482.10 716.78 -527.70 5,981,213.129 618,391.292 3.44 846.08 1113012017 11:49:35AM Page 4 COMPASS 5000.1 Build 81D BP by � Final Survey Report UGHES aG IPary Company: North America - ALASKA - BP Local Coordinate Reference: Well S-200 Project: Prudhoe Bay TVD Reference: S-200AActual @ 82.32usft (P272 Actual RKB) Site: PB S Pad MD Reference: S-200AActual @ 82.32usft (P272 Actual RKB) Well: S-200 North Reference: True Wellbore: S -200A Survey Calculation Method: Minimum Curvature Design: S -200A Database: EDM R5K - Alaska PROD - ANCP1 Survey MD Inc Azi (azimuth) TVD TVDSS N/S E/W Northing Easting DLeg V. Sec (usft) V) V) (usft) (usft) (usft) (usft) (usft) (usft) (°l100usft) (usft) 3,925.72 57.55 330.65 3,615.42 3,533.10 784.67 -565.87 5,981,280.401 618,352.053 1.64 916.6 4,021.67 56.36 331.34 3,667.74 3,585.42 855.01 -604.87 5,981,350.106 618,311.943 1.38 989.24 4,116.19 56.88 332.40 3,719.75 3,637.43 924.61 -642.08 5,981,419.105 618,273.637 1.09 1,059.98 4,210.95 58.38 332.23 3,770.48 3,688.16 995.483- 1-679.27 5,981,489.369 618,235.335 1.59 1,131.44 4,305.92 61.90 330.70 3,817.76 3,735.44 1,067.81 -718.62 5,981,561.063 618,194.841 3.96 1,205.52 4,338.94 63.62 330.10 3,832.87 3,750.55 1,093.34 -733.12 5,981,586.352 618,179.938 5.45 1,232.15 4,369.55 64.94 329.57 3,846.15 3,763.83 1,117.18 -746.98 5,981,609.969 618,165.705 4.59 1,257.29 4,400.76 66.45 329.00 3,859.00 3,776.68 1,141.83 -761.51 5,981,634.186 618,150.791 5.12 1,283.33 4,495.44 69.42 327.48 3,894.56 3,812.24 1,216.22 -807.70 5,981,708.026 618,103.427 3.47 1,364.28 4,590.18 71.99 327.84 3,925.87 3,843.55 1,291.77 -855.52 5,981,782.794 618,054.410 2.74 1,447.11 4,685.24 74.06 326.73 3,953.62 3,871.30 1,368.25 -904.66 5,981,858.486 618,004.068 2.45 1,531.56 4,780.14 75.36 324.13 3,978.65 3,896.33 1,443.62 -956.60 5,981,933.010 617,950.942 2.98 1,617.64 4,876.46 75.29 320.94 4,003.06 3,920.74 1,517.57 -1,013.27 5,982,006.042 617,893.111 3.20 1,706.74 4,969.62 75.38 317.58 4,026.65 3,944.33 1,585.84 -1,072.08 5,982,073.369 617,833.230 3.49 1,794.28 5,064.42 75.43 313.78 4,050.54 3,968.22 1,651.46 -1,136.16 5,982,137.960 617,768.119 3.88 1,884.57 5,159.01 75.39 310.18 4,074.38 3,992.06 1,712.68 -1,204.20 5,982,198.084 617,699.125 3.68 1,975.52 5,253.71 75.52 308.60 4,098.16 4,015.84 1,770.85 -1,275.04 5,982,255.115 617,627.377 1.62 2,066.98 5,348.24 75.39 307.10 4,121.90 4,039.58 1,826.99 -1,347.29 5,982,310.099 617,554.253 1.54 2,158.40 5,443.19 75.42 307.70 4,145.83 4,063.51 1,882.80 -1,420.28 5,982,364.738 617,480.387 0.61 2,250.24 5,538.00 75.48 307.16 4,169.65 4,087.33 1,938.58 -1,493.16 5,982,419.346 617,406.643 0.55 2,341.96 5,632.89 75.38 306.82 4,193.52 4,111.20 1,993.83 -1,566.51 5,982,473.427 617,332.426 0.36 2,433.77 5,727.43 75.33 .4 306.44 4,217.42 4,135.10 2,048.41 -1,639.92 5,982,526.824 617,258.172 0.39 2,525.22 5,821.85 75.39 305.71 4,241.29 4,158.97 2,102.20 -1,713.75 5,982,579.434 617,183.497 0.75 2,616.57 5,916.40 75.29 305.13 4,265.22 4,182.90 2,155.21 -1,788.29 5,982,631.253 617,108.129 0.60 2,708.04 6,010.99 75.39 305.39 4,289.16 4,206.84 2,208.04 -1,863.02 5,982,682.884 617,032.584 0.29 2,799.55 6,105.82 75.32 305.90 4,313.13 4,230.81 2,261.51 -1,937.58 5,982,735.156 616,957.192 0.53 2,891.30 6,200.44 75.42 304.88 4,337.03 4,254.71 2,314.53 -2,012.21 5,982,786.981 616,881.731 1.05 2,982.85 11/30/2017 11:49:35AM Page 5 COMPASS 5000.1 Build 81D 40*1116 BP i by .� Final Survey Report t�UGHES GE,-p�„y Company: North America - ALASKA - BP Project: Prudhoe Bay Site: PB S Pad Well: S-200 Wellbore: S -200A Design: S -200A Survey Local Coordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well S-200 S-200AActual @ 82.32usft (P272 Actual RKB) S-200AActual @ 82.32usft (P272 Actual RKB) True Minimum Curvature EDM R5K - Alaska PROD - ANCP1 MD Inc Azi (azimuth) ND TVDSS NIS E/W Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) 6,294.96 75.35 304.99 4,360.88 4,278.56 2,366.90 -2,087.19 5,982,838.155 616,805.934 6,389.56 75.57 304.69 4,384.63 4,302.31 2,419.22 -2,162.35 5,982,889.264 616,729.964 6,484.27 75.30 305.74 4,408.45 4,326.13 2,472.08 -2,237.24 5,982,940.921 616,654.250 6,579.13 75.47 307.00 4,432.38 4,350.06 2,526.51 -2,311.14 5,982,994.167 616,579.494 6,673.53 75.46 308.24 4,456.08 4,373.76 2,582.28 -2,383.52 5,983,048.785 616,506.246 6,766.98 75.35 309.18 4,479.63 4,397.31 2,838.84 -2,454.09 5,983,104.208 616,434.796 6,862.48 75.51 308.85 4,503.65 4,421.33 2,697.03 -2,525.90 5,983,161.242 616,362.072 6,956.93 75.26 308.24 4,527.48 4,445.16 2,753.98 -2,597.39 5,983,217.045 616,289.703 7,051.26 74.53 308.11 4,552.06 4,469.74 2,810.26 -2,668.98 5,983,272.184 616,217.231 7,145.86 74.62 308.94 4,577.23 4,494.91 2,867.06 -2,740.32 5,983,327.839 616,145.002 7,240.59 74.57 309.39 4,602.39 4,520.07 2,924.74 -2,811.13 5,983,384.380 616,073.294 7,334.97 74.60 309.14 4,627.48 4,545.16 2,982.32 -2,881.57 5,983,440.835 616,001.951 7,429.38 74.50 308.28 4,652.63 ' 4,570.31 3,039.23 -2,952.58 5,983,496.604 615,930.056 7,524.67 74.57 308.15 4,678.04 4,595.72 3,096.05 -3,024.74 5,983,552.260 615,857.011 7,619.68 74.70 308.20 4,703.21 4,620.89 3,152.67 -3,096.76 5,983,607.728 615,784.107 7,714.34 74.63 307.95 4,728.24 4,645.92 3,208.97 -3,168.62 5,983,662.873 615,711.365 7,810.01 74.66 307.59 4,753.58 4,671.26 3,265.47 -3,241.55 5,983,718.209 615,637.558 7,903.34 74.59 306.76 4,778.32 4,696.00 3,319.85 -3,313.25 5,983,771.436 615,565.007 7,998.50 74.53 306.25 4,803.66 4,721.34 3,374.42 -3,386.98 5,983,824.820 615,490.427 8,093.18 74.69 305.97 4,828.79 4,746.47 3,428.21 -3,460.72 5,983,877.436 615,415.841 8,187.77 74.63 306.13 4,853.81 4,771.49 3,481.89 -3,534.48 5,983,929.936 615,341.253 8,282.34 74.67 306.27 4,878.84 4,796.52 3,535.76 -3,608.07 5,983,982.618 615,266.821 8,377.71 74.68 306:49 4,904.05 4,821.73 3,590.31 -3,682.12 5,984,035.987 615,191.918 8,472.04 74.59 306.54 4,929.04 4,846.72 3,644.44 -3,755.22 5,984,088.938 615,117.971 8,566.73 74.64 306.52 4,954.16 4,871.84 3,698.78 -3,828.58 5,984,142.106 615,043.763 8,661.62 74.63 307.00 4,979.31 4,896.99 3,753.54 -3,901.89 5,984,195.689 614,969.605 8,756.45 74.46 307.44 5,004.58 4,922.26 3,808.82 -3,974.67 5,984,249.808 614,895.959 DLeg V. Sec (°/100usft) (usft) 0.13 3,074.3 0.39 3,165.87 1.11 3,257.53 1.30 3,349.31 1.27 3,440.63 0.98 3,530.92 0.37 3,623.18 0.68 3,714.45 0.79 3,805.43 0.85 3,896.50 0.46 3,987.64 0.26 4,078.43 0.88 4,169.29 0.15 4,261.03 0.15 4,352.55 0.27 4,443.7 0.36 4,535.94 0.86 4,625.89 0.52 4,717.60 0.33 4,808.88 0.18 4,900.10 0.15 4,991.29 0.22 5,083.26 0.11 5,174.20 0.06 5,265.49 0.49 5,356.97 0.48 5,448.33 11/30/2017 11:49:35AM Page 6 COMPASS 5000.1 Build 81D b BP10. Final Survey Report FAUGHES 0GE company Company: North America - ALASKA - BP Local Coordinate Reference: Well S-200 Project: Prudhoe Bay ND Reference: S-200AActual @ 82.32usft (P272 Actual RKB) Site: PB S Pad MD Reference: S-200AActual @ 82.32usft (P272 Actual RKB) Well: S-200 North Reference: True Wellbore: S -200A Survey Calculation Method: Minimum Curvature Design: S -200A Database: EDM R5K - Alaska PROD - ANCP1 Survey MD Inc Azi (azimuth) TVD TVDSS NIS E/W Northing Easting DLeg V. Sec (usft) V) V) (usft) (usft) (usft) (usft) (usft) (usft) (°/100usft) (usft) 8,851.11 74.47 308.42 5,029.93 4,947.61 3,864.88 -4,046.61 5,984,304.715 614,823.149 1.00 5,539.4 8,945.01 74.44 308.06 5,055.10 4,972.78 3,920.88 -4,117.68 5,984,359.570 614,751.221 0.37 5,629.81 9,039.83 74.45 307.80 5,080.52 4,998.20 3,977.03 -4,189.71 5,984,414.565 614,678.294 0.26 5,721.08 9,134.95 74.48 308.11 5,106.00 5,023.68 4,033.39 -4,261.97 5,984,469.771 614,605.153 0.32 5,812.65 9,229.55 74.47 307.87 5,131.32 5,049.00 4,089.50 -4,333.81 5,984,524.723 614,532.442 0.24 5,903.71 9,324.47 74.51 307.82 5,156.70 5,074.38 4,W.61 -4,406.04 5,984,579.680 614,459.340 0.07 5,995.10 9,419.18 74.49 307.54 5,182.01 5,099.69 4,201.40 -4,478.27 5,984,634.308 614,386.239 0.29 6,086.30 9,514.83 74.44 307.42 5,207.63 5,125.31 4,257.48 -4,551.40 5,984,689.210 614,312.232 0.13 6,178.41 9,609.40 74.43 307.11 5,233.01 5,150.69 4,312.64 -4,623.90 5,984,743.210 614,238.869 0.32 6,269.47 9,704.37 74.53 307.44 5,258.42 5,176.10 4,368.06 -4,696.72 5,984,797.463 614,165.189 0.35 6,360.93 9,799.86 74.43 307.03 5,283.97 5,201.65 4,423.73 -4,769.97 5,984,851.961 614,091.068 0.43 6,452.90 9,894.55 74.47 306.24 5,309.35 5,227.03 4,478.16 -4,843.17 5,984,905.222 614,017.017 0.80 6,544.11 9,987.66 74.51 305.32 5,334.25 5,251.93 4,530.62 -4,915.96 5,984,956.512 613,943.414 0.95 6,633.83 10,082.48 74.50 304.60 5,359,58 5,277.26 4,582.98 -4,990.84 5,985,007.669 613,867.713 0.73 6,725.20 10,177.34 74.52 304.28 5,384.92 5,302.60 4,634.68 -5,066.23 5,985,058.160 613,791.517 0.33 6,816.59 10,272.28 74.48 305.02 541029 5,327.97 4,686.69 -5,141.49 5,985,108.970 613,715.447 0.75 6,908.0 10,366.82 74.49 305.65 5,435.58' 5,353.26 4,739.38 -5,215.81 5,985,160.464 613,640.313 0.64 6,999.16 10,460.94 74.46 305.63 5,460.77 5,378.45 4,792.22 -5,289.51 5,985,212.125 613,565.790 0.04 7,089.85 10,555.97 74.43 305.72 5,486.25 5,403.93 4,845.61 -5,363.88 5,985,264.324 613,490.589 0.10 7,181.40 10,650.75 74.46 306.09 5,511.67 5,429.35 4,899.16 -5,437.84 5,985,316.685 613,415.795 0.38 7,272.70 10,745.59 74.52 3(16.68 5,537.03 5,454.71 4,953.37 -5,511.41 5,985,369.717 613,341.380 0.60 7,364.08 10,840.02 74.47 ? 307.04 5,562.28 5,479.96 5,007.95 -5,584.21 5,985,423.133 613,267.725 0.37 7,455.05 10,934.35 74.48 307.19 5,587.52 5,505.20 5,062.79 -5,656.69 5,985,476.815 613,194.393 0.15 7,545.90 11,029.08 74.47 307.56 5,612.88 5,530.56 5,118.20 -5,729.22 5,985,531.057 613,120.995 0.38 7,637.13 11,123.52 74.59 307.48 5,638.07 5,555.75 5,173.63 -5,801.41 5,985,585.333 613,047.940 0.15 7,728.09 11,217.79 74.63 307.26 5,663.09 5,580.77 5,228.80 -5,873.64 5,985,639.341 612,974.847 0.23 7,818.94 11,313.04 74.59 307.46 5,688.37 5,606.05 5,284.53 -5,946.64 5,985,693.898 612,900.984 0.21 7,910.73 11/30/2017 11:49:35AM Page 7 COMPASS 5000.1 Build 81D by BP sAFinal Survey Report UGHES0vGEmpany Company: Project: Site: Well: Wellbore: Design: Suryey MD (usft) 11, 407.4 11, 502.4 11, 600.2 11,692.9 11,788.0 11,882.9 11,977.8 12, 072.5 12,167.2 12, 261.8 12,356.3 12,451.2 12, 545.7 12,640.5 12,735.1 12,828.9 12,923.65 13, 018.7 13,113.3 13,208.2 13, 301.9 13, 396.8 13, 491.8 13,586.0 13, 680.8 13, 775.7 13, 870.5 North America - ALASKA - BP 5 3 1 6 7 2 5 5 4 7 6 5 7 Local Coordinate Reference: Well S-200 Prudhoe Bay TVD Reference: S-200AActual @ 82.32usft (P272 Actual RKB) PB S Pad MD Reference: S-200AActual @ 82.32usft (P272 Actual RKB) S-200 North Reference: True S -200A Survey Calculation Method: Minimum Curvature S -200A Database: EDM R5K - Alaska PROD - ANCP1 Inc Azi (azimuth) TVD TVDSS N/S ENV Northing Easting DLeg V. Sec V) V) (usft) (usft) (usft) (usft) (usft) (usft) (°/100usft) (usft) 1 74.59 307.30 5,713.44 5,631.12 5,339.76 -6,018.93 5,985,747.971 612,827.829 0.16 8,001.630 3 74.64 307.46 5,738.65 5,656.33 5,395.38 -6,091.73 5,985,802.423 612,754.162 0.17 8,093.23 3 74.37 308.36 5,764.78 5,682.46 5,453.28 -6,166.09 5,985,859.136 612,678.902 0.93 8,187.39 5 74.40 308.68 5,789.74 5,707.42 5,508.90 -6,235.95 5,985,913.629 612,608.168 0.33 8,276.57 3 74.40 308.96 5,815.31 5,732.99 5,566.30 .6,307.30 5,985,969.892 612,535.922 0.28 8,368.00 2 74.28 307.65 5,840.92 5,758.60 5,622.94 -6,379.00 5,986,025.374 612,463.341 1.34 8,459.26 9 74.50 308.39 5,866.48 5,784.16 5,679.28 -6,451.05 5,986,080.556 612,390.406 0.79 8,550.64 3 74.56 308.58 5,891.72 5,809.40 5,736.04 -6,522.45 5,986,136.173 612,318.122 0.20 8,641.73 2 74.50 307.94 5,916.98 5,834.66 5,792.55 -6,594.11 5,986,191.534 612,245.583 0.65 8,732.89 2 74.57 308.03 5,942.20 5,859.86 5,848.66 -6,665.97 5,986,246.495 612,172.846 0.12 8,823.98 8 74.53 307.34 5,967.39 5,885.07 5,904.38 -6,738.10 5,986,301.056 612,099.848 0.70 8,915.06 0 74.53 307.38 5,992.68 5,910.36 5,959.83 -6,810.73 5,986,355.345 612,026.347 0.04 9,006.40 5 74.50 306.79 6,017.93 5,635.61 6,014.78 -6,883.42 5,986,409.123 611,952.802 0.60 9,097.48 74.56 306.70 6,04a.3'1 5,960.89 6,069.44 -6,956.63 5,986,462.610 611,878.738 0.11 9,188.83 74.56 306.84 6,068,39 5,986.07 6,124.01 -7,029.66 5,986,516.012 611,804.858 0.14 9,279 97 74.56 306.73 6,093.36 6,011.04 6,178.14 -7,102.06 5,986,568.981 611,731.618 0.11 9,370.3 74.53 305.60 6,118.61 6,036.29 6,232.02 -7,175.78 5,986,621.684 611,657.059 1.15 9,461.6 74.53 304.97 6,143.98 6,061.66 6,284.97 -7,250.60 5,986,673.434 611,581.410 0.64 9,553.32 74.59 305.58 6,169.17 6,086.85 6,337.64 -7,325.05 5,986,724.907 611,506.139 0.62 9,644.51 74.65 305.40 6,194.32 6,112.00 6,390.73 -7,399.52 5,986,776.808 611,430.849 0.19 9,735.96 74.66 ` 305.32 6,219.13 6,136.81 6,443.04 -7,473.23 5,986,827.935 611,356.320 0.08 9,826.35 72.56 303p7 6,245.91 6,163.59 6,494.21 -7,548.52 5,986,877.898 611,280.234 3.17 9,917.36 70.07 301'1 6,276.34 6,194.02 6,542.42 -7,624.49 5,986,924.892 611,203.517 2.95 10,007.20 67.37 .49 6,310.53 6,228.21 6,587.78 -7,699.65 5,986,969.053 611,127.645 3.11 10,094.73 65.02 299.01 6,348.79 6,266.47 6,630.82 -7,774.94 5,987,010.887 611,051.696 2.86 10,181.00 62.82 296.79 6,390.51 6,308.19 6,670.71 -7,850.24 5,987,049.572 610,975.775 3.13 10,265.46 60.76 294.12 6,435.34 6,353.02 6,706.63 -7,925.66 5,987,084.291 610,899.796 3.30 10,347.71 1113012017 11:49:35AM Page 8 COMPASS 5000.1 Build 81D BP 0by L. ,L, Final Survey Report gUGHES a GF. company Company: North America - ALASKA - BP Local Co-ordinate Reference: Well S-200 Project: Prudhoe Bay ND Reference: S-200AActual @ 82.32usft (P272 Actual RKB) Site: PB S Pad MD Reference: S-200AActual @ 82.32usft (P272 Actual RKB) Well: S-200 North Reference: True Wellbore: 5-200A Survey Calculation Method: Minimum Curvature Design: S -200A Database: EDM R5K - Alaska PROD - ANCP1 Survey MD Inc Azi (azimuth) TVD TVDSS N/S ENV Northing Easting DLeg V. Sec (usft) V) V) (usft) (usft) (usft) (usft) (usft) (usft) (°/100usft) (usft) 13,965.20 59.30 290.93 6,482.62 6,400.30 6,738.05 -8,001.36 5,987,114.495 610,823.614 3.30 10,427.5 14,059.80 57.18 287.23 6,532.42 6,450.10 6,764.36 -8,077.34 '. 5,987,139.596 610,747.231 4.01 10,504.68 14,108.45 55.75 286.29 6,559.29 6,476.97 6,776.06 -8,116.17 5,987,150.674 610,708.226 3.35 10,543.07 14,148.00 55.22 285.99 6,581.71 6,499.39 6,785.11 -8,147.47 5,987,159.233 610,676.786 1.49 10,573.81 7" Production Casing 14,172.13 54.89 285.80 6,595.53 6,513.21 6,790.53 -8,166.50 5,987,164.346 610,657.681 1.49 10,592.44 14,206.34 53.33 282.30 6,615.59 6,533.27 6,797.26 -8,193.37 5,987,170.653 610,630.704 9.46 10,618.22 14,237.30 53.22 279.62 6,634.10 6,551.78 6,801.98 -8,217.73 5,987,174.983 610,606.276 6.95 10,640.78 14,268.25 53.02 278.05 6,652.68 6,570.36 6,805.78 -8,242.19 5,987,178.396 610,581.759 4.11 10,662.89 14,301.11 51.49 275.47 6,672.79 6,590.47 6,808.85 -8,267.99 5,987,181.050 610,555.918 7.76 10,685.66 14,332.14 51.03 274.29 6,692.21 6,609.89 6,810.91 -8,292.11 5,987,182.726 610,531.776 3.32 10,706.48 14,360.55 50.83 273.01 6,710.12 6,627.80 6,812.31 -8,314.12 5,987,183.781 610,509.747 3.57 10,725.20 14,395.29 50.38 270.71 6,732.17-- 6,649.85 6,813.19 -8,340.95 5,987,184.228 610,482.909 5.28 10,747.54 14,426.56 50.39 270.55 6,752.11 6,6613.79 6,813.45 -8,365.03 5,987,184.110 610,458.823 0.40 10,767.29 14,455.13 50.36 270.24 6,770.33 6,688.01 6,813.60 -8,387.04 5,987,183.913 610,436.820 0.84 10,785.28 14,492.25 50.35 270.55 6,794.01 6,711.69 6,813.80 -8,415.62 5,987,183.656 610,408.241 0.64 10,808.6 14,521.05 51.35 269.90 6,812.19 6,729.87 6,813.89 -8,437.95 5,987,183.388 610,385.911 3.89 10,826.8 14,550.35 54.76 269.96;= 6,829.80 6,747.48 6,813.86 -8,461.37 5,987,182.993 610,362.502 11.64 10,845.91 14,584.25 59.14 270.08 6,848.29 6,765.97 6,813.88 -8,489.78 5,987,182.557 610,334.100 12.92 10,869.03 14,614.48 60.54 269.02 6,863.47 6,781.15 6,813.67 -8,515.91 5,987,181.935 610,307.973 5.54 10,890.18 14,644.96 62.34 268.37 6,878.05 6,795.73 6,813.06 -8,542.67 5,987,180.900 610,281.226 6.20 10,91159 14,679.12 65.51 268.00 6,893.06 6,810.74 6,812.09 -8,573.34 5,987,179.440 610,250.584 9.33 10,935.98 14,710.69 69.10 267.64 6,905.24 6,822.92 6,810.98 -8,602.44 5,987,177.869 610,221.508 11.42 10,959.01 14,739.71 72.67 267.31 6,914.74 6,832.42 6,809.77 -8,629.83 5,987,176.226 610,194.144 12.35 10,980.59 14,773.64 77.87 267.53 6,923.36 6,841.04 6,808.29 -8,662.60 5,987,174.230 610,161.404 15.34 11,006.39 14,808.70 81.20 267.81 6,929.73 6,847.41 6,806.89 -8,697.04 5,987,172.283 610,126.990 9.53 11,033.60 14,834.11 84.04 268.02 6,932.99 6,850.67 6,805.98 -8,722.22 5,987,170.967 610,101.830 11.21 11,053.56 11/30/2017 11:49:35AM Page 9 COMPASS 5000.1 Build 81D BP 0 by Final Survey Report UGHES a6 -1,11-,Y Company: North America - ALASKA - BP Local Co-ordinate Reference: Well 5-200 Project: Prudhoe Bay TVD Reference: S-200AActual @ 82.32usft (P272 Actual RKB) Site: PB S Pad MD Reference: S-200AActual @ 82.32usft (P272 Actual RKB) Well: S-200 North Reference: True Wellbore: S -200A Survey Calculation Method: Minimum Curvature Design: S -200A Database: EDM R5K - Alaska PROD - ANCP1 Survey MD Inc Azi (azimuth) TVD TVDSS N/S E/W Northing Easting DLeg V. Sec (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (°1100usft) (usft) 14,868.38 88.53 268.71 6,935.21 6,852.89 6,805.00 -8,756.40 5,987,169.450 610,067.677 13.25 11,080.7 14,899.97 93.59 269.23 6,934.63 6,852.31 6,804.43 -8,787.96 5,987,168.381 610,036.124 16.10 11,106.15 14,928.72 97.40 269.98 6,931.88 6,849.56 6,804.24 -8,816.58 5,987,167.729 610,007.521 13.50 11,129.31 14,963.31 100.96 271.29 6,926.36 6,844.04 6,804.61 -8,850.72 5,987,167.563 609,973.384 10.95 11,157.31 14,994.31 103.66 272.29 6,919.75 6,837.43 6,805.56 -8,880.98 5,987,168.027 609,943.106 9.26 11,182.48 15,023.27 104.00 273.06 6,912.83 6,830.51 6,806.87 -8,909.07 5,987,168.893 609,915.001 2.84 11,206.10 15,117.80 104.00 272.83 6,889.96 6,807.64 6,811.58 -9,000.67 5,987,172.151 609,823.345 0.24 11,283.37 15,152.04 104.03 273.07 6,881.67 6,799.35 6,813.29 -9,033.85 5,987,173.333 609,790.148 0.69 11,311.35 15,183.49 103.78 272.42 6,874.11 6,791.79 6,814.75 -9,064.34 5,987,174.311 609,759.638 2.16 11,337.01 15,213.08 102.14 272.24 6,867.47 6,785.15 ` 6,815.92 -9,093.16 5,987,175.025 609,730.814 5.57 11,361.14 15,246.46 98.07 272.03 6,861.62 6,779.30 •. 6,817.15 -9,125.99 5,987,175.727 609,697.969 12.21 11,388.56 15,277.72 93.84 272.25 6,858.38 5,776.06 6,818.31 -9,157.05 5,987,176.395 609,666.895 13.55 11,414.51 15,307.01 90.61 271.90 6,857.24 6,774.92 6,819.37 -9,186.30 5,987,176.990 609,637.639 11.09 11,438.92 15,340.32 88.67 270.16 6,857.45 6,775.13 6,819.97 -9,219.60 5,987,177.060 609,604.336 7.82 11,466.36 15,372.89 88.52 271.57 6,858.25 6,775.93 6,820.46 -9,252.15 5,987,177.035 609,571.779 4.35 11,493.13 15,401.51 88.61 274.70 6,85896 6,776.64 6,822.02 -9,280.72 5,987,178.145 609,543.196 10.94 11,517.20 15,433.42 90.73 279.63 6,85915 6,776.83 6,826.00 -9,312.37 5,987,181.621 609,511.490 16.82 11,545.3 15,464.73 93.89 281.24 6,857.88 6,775.56 6,831.67 -9,343.13 5,987,186.796 609,480.645 11.32 11,573.67 15,494.89 94.20 281.77 6,855.76 6,773.44 6,837.67 -9,372.61 5,987,192.327 609,451.075 2.03 11,601.14 15,589.75 97.71 279.54 6,845.92 6,763.60 6,855.11 -9,465.31 5,987,208.299 609,358.118 4.38 11,686.71 15,658.36 98.03 279.75 6,836.52 6,754.20 6,866.50 -9,532.31 5,987,218.619 609,290.948 0.56 11,747.84 15,691.00 98.03 279.75 6,831.96 6,749.64 6,871.97 -9,564.16 5,987,223.586 609,259.015 0.00 11,776.94 41/2' Production Liner 15,693.00 98.03 279.75 6,831.68 6,749.36 6,872.31 -9,566.12 5,987,223.890 609,257.058 0.00 11,778.72 Projection to TD 1113012017 11:49:35AM Page 10 COMPASS 5000.1 Build 81D 0 by Well S-200 ND Reference: Company: North America - ALASKA - BP Project: Prudhoe Bay True Site: PB S Pad Database: Well: S-200 Wellbore: S -200A Name (in) (in) Design: S -200A Casing Points 4.500 6.1251 Measured Vertical Depth Depth (usft) (usft) 2,734.03 2,712.32 9 5/8" Surface Casing 14,148.00 6,581.71 7" Production Casing 15,691.00 6,831.96 4 1/2" Production Liner BP Final Survey Report BAIUG ES a GEmmpany Local Coordinate Reference: Well S-200 ND Reference: S-200AActual @ 82.32usft (P272 Actual RKB) MD Reference: S-200AActual @ 82.32usft (P272 Actual RKB) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM R5K - Alaska PROD - ANCP1 Casing Hole Diameter Diameter Name (in) (in) 9.625 12.250 7.000 8.500 4.500 6.1251 0 11/30/2017 11:49:35AM Page 11 COMPASS 5000.1 Build 81D BP 0 by a#: Final Survey Report HUGHES Company: North America - ALASKA - BP Local Coordinate Reference: Well S-200 Project: Prudhoe Bay TVD Reference: 5-200AActual @ 82.32usft (P272 Actual RKB) Site: PB S Pad MD Reference: S-200AActual @ 82.32usft (P272 Actual RKB) Well: S-200 North Reference: True Wellbore: S -200A Survey Calculation Method: Minimum Curvature Design: S -200A Database: EDM R5K - Alaska PROD - ANCP1 Design Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment . 15,693.00 6,831.68 6,872.31 -9,566.12 Projection to TD Prepared By: Yosha Ragbirsingh Survey Manager Baker Hughes a GE Company 11/30/2017 11:49:35AM Page 12 COMPASS 5000.1 Build 81D WELLBORE DETAILS: S -200A REFERENCE INFORMATION S -200A C—direle (WE) Reference: Well &200, Trace Nath VW-I(ND)Relereroe. S-200AAdt.1@8232ue8(P272AclusIRKB) �/\�jlCp Parent Wellbore: Sednn(VS)Relerence'. Slat -(00014 OOOE) /M1�`G11[[ S-200PB1 Menured Depth Reference: Ac1.Wu..32usR IP272AauaIRKB) D UGHES Tie On MD: 2702.61 Method'. Minimum Calcuhtron Minimum Curvature aGE company Project: Prudhoe Bay Site: PBS Pad Well: 5-200 kz udsbTme Nath Mapretc Nmlh: 1761 ".6c Fey &.,gh-%ao �p 0Mont Wellbore: S -200A D4AoAo eo v3 Design: S-200A(S-200IS-200A) D. 10201 BGGMM1 Post Drilling Easting (400 usft/in) AOGCC Post Drilling rn 0 W O rn rn rn rn 0 0 0 0 rn rn t0 ra rn m rn rn O O O � m � m m rn N N N Easting (400 usftrn) rn m rn m rn rn rn rn rn rn rn rn rn rn m W W A A A rn N rn rn rn V V rn rn rn m rn rn rn rn m N O O O O N rn rn rn rn N N N N O A rn N rn O O O O O -O SO 0O_ -1S- O A rn N rn O O O O O O O --O O O10 O A rn O O O OOO N rn O A rn N rn O A rn N rn O A W 0 O OO OO OO OO OO OO OO - OO S5 O�PB1 S_122/S-122598000 N rn O A W N OO OO OO OO OO OO rn O A rn OO OO OO ' 0 59876001 19S19 00 02-2 861/S-111 P6 102/S102L1P81 S-122/S-122PB3 S -121/S-121 Plan S-136/Plan S-136 5599887860000 .,O 5987200' 52 B 5987200 S -200/S -200A S -200A ACTUAL 5986800��'5986800 O • �o O 60 *Nl/S-121PB1 5986400- O $986400 54903/S-103 59860OG OO SR- 14/S -114A 0000 5000 6pp0 5986000 5985600 S- 4/S-11400 00 0p O AO Sc�27S 102PB1 5985600 598.5200 -100/S-100 00 y000 y000 15985200 5984800.'.. 0S y00 y0 O o -10 - 4 - 6000 -5984800 z 5984400' b O h0 y0400 A00 S -43/S-431-1 p 15984400 7 c S-4 o 05g S201 70�g� S-105 5980.000 po h000S-20 5 SA 1 /S 4 AL1 598400000 0 500 S -41/S -41A- pfj5963600, oo 00 000 S-41/S-41PBY 00 S -113/S-113 o _ a h 0 PB1 S -41/S-4 C 5983200, - 0 0B1 /S-4 A S- O/S-110 5983200.�.� z 00 /S- 0 O 5962800+ _ 8/S-10801PB ®� 598280c S--11 d6 5982400,'' -113/S-11 00 S-44/ §4 400 O �5982400 - 000 O S-1 1 te 0 598200 0 S -101/S- 00 _ oo 5982000 S_ 0 0 PB S-43 • 5981600 00 -120 - o `5981600 5981200!, 0113/S -113B OI o 0 0 0 1 112L o S-11,2i5S-112 5981200 o O 1 OCD 5980800; 1 o o 'co 5980800 ' -101/S-101P81 00 oo�p.m O ''.,.. 5980400 113/S-113BL1 _ 5980400 S -125/S-125 o S -109/S -109P61 59800001 S-125/S-125PO1 - �-11� o 005-213/S- S-118 O o O - S -109/S-109 5980000 5979600 - 0 0 000 0 o 0 0 0 o S 213/S-213 400 421S-42PB1 o ; 5979600 rn m .. O -rn rn m rn rn rn r0 O A rn N rn O rn rn m rn j O O O O A rn N rn rn rn rn N N O A rn o o .} rn rn rn rn rn rn rn m rn rn rn rn rn rn rn W W A A A to N rn rn rn J J rn W rn N rn O A rn N rn O A rn N rn O A rn St-4P/.'&P rn rn rn rn rn rn O O O O O N N rn O A rn N O m rn rn rn N N N OO OOA OOrn OO '. Easting (400 usft/in) AOGCC Ap ...,Post DrIfia-f North America - ALASKA - BP Prudhoe Bay PB S Pad S-200 S -200A S -200A AOGCC Post Drilling Offset Report 30 November, 2017 _ lGHES a GE company ti10o C�� • 0 by Company: North America - ALASKA - BP Project: Prudhoe Bay Reference Site: PB S Pad Site Error: 0.00usft Reference Well: S-200 Well Error: 0.00usft Reference Wellbore S -200A Reference Design: S -200A BP Anticollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: BAER F�UGHES a GE company Well S-200 S-200AActual @ 82.32usft (P272 Actual RKB) S-200AActual @ 82.32usft (P272 Actual RKB) True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference S -200A Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria WARNING: There is hidden tight data in this project Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 500.00usft Error Surface: Elliptical Conic Survey Program Date 11/30/2017 From To (usft) (usft) Survey (Wellbore) Tool Name Description 132.80 2,702.61 Survey #1 MWD (S-200PB1) MWD MWD - Standard 2,734.00 3,158.69 Gyrodata GWD 8-1/2" (S -200A) GYRO -WD -SS Gyro while drilling single shots 3,253.13 14,108.45 BHGE OTK MWD 8-1/5 x 9-7/8" (S -200A) MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 14,172.13 15,658.36 BHGE OTK MWD 6-1/8" (S -200A) MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 11/30/2017 12:03:21PM A ge 2 of5(C (C COMPASS 5000.1 Build 81D 0 by Company: North America - ALASKA - BP Project: Prudhoe Bay Reference Site: PB S Pad Site Error: 0.00usft Reference Well: S-200 Well Error: 0.00usft Reference Wellbore 5-200A Reference Design: S -200A BP BAER Anticollision Report F�UGHES a GE company Local Co-ordinate Reference: Well S-200 ND Reference: S-200AActual @ 82.32usft (P272 Actual RKB) MD Reference: S -200A Actual @ 82.32usft (P272 Actual RKB) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: EDM R5K - Alaska PROD - ANCP1 Offset ND Reference: Offset Datum Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) PB S Pad Plan 5-136 - Plan S-136 - Plan #7 S-136 15,263.41 14,300.00 7.74 374.50 -351.67 FAIL - Major Risk S-100 - S-100 - S-100 342.31 325.00 136.88 4.94 131.94 Pass - Major Risk S-101 - S-101 - S-101 1,044.79 1,025.00 91.10 16.05 75.24 Pass - Major Risk S-101 - S-101 PB1 - S-101 PB1 1,044.79 1,025.00 91.10 16.05 75.24 Pass - Major Risk S-102 - 5-102 - S-102 242.97 225.00 151.72 4.57 147.15 Pass - Major Risk 5-102 - S-1021-1 - S-1021-1 242.97 225.00 151.72 4.57 147.15 Pass - Major Risk S-102 - S-1021-1 PB1 - S-1021-1 PB1 242.97 225.00 151.72 4.57 147.15 Pass - Major Risk S-102 - S-102PB1 - S-102PB1 242.97 225.00 151.72 4.57 147.15 Pass - Major Risk S-103 - 5-103 - 5-103 1,403.63 1,375.00 263.93 18.10 246.21 Pass - Major Risk S-104 - S-104 - S-104 341.95 325.00 345.85 6.63 339.23 Pass - Major Risk S-105 - 5-105 - S-105 1,229.03 1,200.00 320.14 15.73 304.63 Pass - Major Risk S-106 - S-106 - 5-106 286.71 275.00 301.70 5.67 296.03 Pass - Major Risk S-106 - S-106PB1 - S-106PB1 286.71 275.00 301.70 5.78 295.92 Pass - Major Risk S-107 - 5-107 - S-107 10,609.78 9,550.00 92.51 317.16 -223.95 FAIL - Major Risk 5-108 - S-108 - S-108 2,236.87 2,225.00 180.99 29.04 151.98 Pass - Major Risk S-108 - 5-108A` - S -108A 46.02 46.02 210.41 1.02 209.38 Pass - Major Risk S-109 - S-109 - S-109 818.78 800.00 161.55 12.08 149.48 Pass - Major Risk S-109 - S-109PB1 - S-109PB1 818.78 800.00 161.55 12.08 149.48 Pass - Major Risk S-110 - S-110 - S-110 512.99 500.00 176.30 8.86 167.44 Pass - Major Risk S-110 - S-1 10A - S -110A 512.34 500.00 176.30 8.86 167.44 Pass - Major Risk S-110 - S-1108 - S-1106 524.38 525.00 176.39 8.84 167.56 Pass - Major Risk S-111 - S-111 - S-111 267.68 250.00 227.67 5.02 222.65 Pass - Major Risk S-111 - 5-111 PB1 - S-111 P131 267.68 250.00 227.67 5.02 222.65 Pass - Major Risk S-111 - S-111 PB2 - S-111 PB2 267.68 250.00 227.67 5.02 222.65 Pass - Major Risk S-112 - S-112 - S-112 462.67 450.00 27.73 7.86 19.88 Pass - Major Risk S-112 - S-1121-1 - S-11211 462.67 450.00 27.73 7.86 19.88 Pass - Major Risk S-112 - S-1121-1 PB1 - S-1121-1 P81 462.67 450.00 27.73 7.86 19.88 Pass - Major Risk 5-112 - S-1121-1 PB2 - 5-1121-1 PB2 462.67 450.00 27.73 7.86 19.88 Pass - Major Risk S-113 - S-113 - 5-113 869.17 850.00 238.65 14.54 224.19 Pass - Major Risk S-113 - S -113A - S -113A 869.17 850.00 238.65 14.54 224.19 Pass - Major Risk S-113 - S -113B - S -113B 869.17 850.00 238.65 14.54 224.19 Pass - Major Risk 5-113 - S-113131-1 - S-113BL1 869.17 850.00 238.65 14.54 224.19 Pass - Major Risk S-114 - S-114 - S-114 564.79 550.00 319.53 9.52 310.02 Pass - Major Risk S-114 - S -114A - S -114A 564.79 550.00 319.53 9.52 310.02 Pass - Major Risk 5-115 - S-115 - S-115 945.75 925.00 85.97 12.29 73.81 Pass - Major Risk S-116 - S-116 - 5-116 442.85 425.00 30.80 6.93 23.87 Pass - Major Risk S-116 - S -116A - 5-116A 442.85 425.00 30.80 6.93 23.87 Pass - Major Risk S-116 - S-116APB1 - S-116APB1 442.85 425.00 30.80 6.93 23.87 Pass - Major Risk S-116 - S-116APB2 - S-116APB2 442.85 425.00 30.80 6.93 23.87 Pass - Major Risk S-117 - S-117 - S-117 1,368.48 1,350.00 36.21 20.59 16.47 Pass - Major Risk S-118 - S-118 - 5-118 418.49 400.00 15.17 6.68 8.50 Pass - Major Risk S-119 - 5-119 - S-119 369.93 350.00 197.08 6.24 190.84 Pass - Major Risk S-120 - 5-120 - S-120 593.61 575.00 59.53 9.35 50.18 Pass - Major Risk 5-121 - S-121 - S-121 467.51 450.00 44.10 7.17 36.93 Pass - Major Risk S-121 - S-121 PB1 - S-121 PB1 467.51 450.00 44.10 7.17 36.93 Pass - Major Risk S-122 - S-122 - S-122 1,615.77 1,600.00 50.44 20.70 30.15 Pass - Major Risk S-122 - S-122PB1 - 5-122PB1 1,615.77 1,600.00 50.44 20.70 30.15 Pass - Major Risk S-122 - S-122PB2 - S-122PB2 1,615.77 1,600.00 50.44 20.70 30.15 Pass - Major Risk S-122 - S-122PB3 - 5-122PB3 1,615.77 1,600.00 50.44 20.70 30.15 Pass - Major Risk S-125 - 5-125 - S-125 665.77 650.00 65.81 11.02 54.79 Pass - Major Risk S-125 - S-125PB1 - S-125PB1 665.77 650.00 65.81 11.02 54.79 Pass - Major Risk 5-200 - S-200 - 5-200 3,014.41 3,000.00 25.18 11.07 14.96 Pass - Major Risk S-200 - 5-200PB1 - S-200PB1 3,014.41 3,000.00 25.18 11.07 14.96 Pass - Major Risk 11/30/2017 12:03:21 PM A rO) ge 3 of 5COMPASS CC 5000.1 Build 81D 0 BP • BAER 0 by Anticollision Report F�UGHES a GE company Company: North America - ALASKA - BP Local Co-ordinate Reference: Well S-200 Project: Prudhoe Bay ND Reference: S-200AActual @ 82.32usft (P272 Actual RKB) Reference Site: PB S Pad MD Reference: S-200AActual @ 82.32usft (P272 Actual RKB) Site Error: 0.00usft North Reference: True Reference Well: S-200 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore S -200A Database: EDM R5K - Alaska PROD - ANCP1 Reference Design: S -200A Offset ND Reference: Offset Datum Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) PB S Pad S-201 - S-201 - S-201 1,680.00 1,650.00 293.07 20.78 272.73 Pass - Major Risk S-201 - S-201 PB1 - S-201 PB1 1,680.00 1,650.00 293.07 20.78 272.73 Pass - Major Risk S-213 - S-213 - S-213 1,167.06 1,150.00 32.24 14.65 17.60 Pass - Major Risk S-213 - S -213A - S -213A 1,171.13 1,150.00 32.29 14.70 17.60 Pass - Major Risk S-213 - S-213ALl - S-213ALl 1,171.13 1,150.00 32.29 14.70 17.60 Pass - Major Risk S-213 - S-213ALl -01 - S-213ALl -01 1,171.13 1,150.00 32.29 14.70 17.60 Pass - Major Risk S-213 - S-213AL2 - S-213AL2 1,171.13 1,150.00 32.29 14.70 17.60 Pass - Major Risk S-213 - S-213AL3 - S-213AL3 1,171.13 1,150.00 32.29 14.70 17.60 Pass - Major Risk S-216 - S-216 - S-216 342.62 325.00 16.71 6.50 10.21 Pass - Major Risk S-400 - S-400 - S-400 442.31 425.00 178.02 6.68 171.34 Pass - Major Risk S-400 - S -400A - S -400A 442.51 425.00 178.02 6.68 171.34 Pass - Major Risk S-401 - S-401 - S-401 663.77 650.00 134.97 9.31 125.68 Pass - Major Risk S-401 - S-401 PB1 - S-401 PB1 663.77 650.00 134.97 9.31 125.68 Pass - Major Risk S-41 - S-41 - S-41 1,026.46 1,025.00 151.19 14.49 136.73 Pass - Major Risk S-41 - S-41 A - S-41 A 1,032.58 1,025.00 151.28 14.62 136.70 Pass - Major Risk S-41 - S-41 AL1 - S-41 AL1 1,032.58 1,025.00 151.28 14.62 136.70 Pass - Major Risk S-41 - S-41 L1 - S-41 1-1 1,026.46 1,025.00 151.19 14.49 136.73 Pass - Major Risk S-41 - S-41 PB1 - S-41 P61 1,026.46 1,025.00 151.19 14.49 136.73 Pass - Major Risk S-42 - S-42 - S-42 534.64 525.00 121.13 7.69 113.44 Pass - Major Risk S-42 - S -42A - S -42A 523.84 525.00 121.02 7.57 113.45 Pass - Major Risk S-42 - S-42PB1 - S-42PB1 534.64 525.00 121.13 7.69 113.44 Pass - Major Risk S-43 - S-43 - S-43 761.15 750.00 86.50 9.98 76.57 Pass - Major Risk S-43 - S-431-1 - S-431-1 761.15 750.00 86.50 9.98 76.57 Pass - Major Risk S-44 - S-44 - S-44 664.03 650.00 59.20 8.17 51.05 Pass - Major Risk S-44 - S -44A - S -44A 674.51 675.00 59.34 8.31 51.05 Pass - Major Risk S-44 - S-441-1 - S -44L1 664.03 650.00 59.20 8.17 51.05 Pass - Major Risk S-44 - S-441-1 PB1 - S-441-1 PB1 664.03 650.00 59.20 8.17 51.05 Pass - Major Risk S-504 - S-504 - S-504 133.48 125.00 209.63 3.62 206.01 Pass - Major Risk 11/30/2017 12:03:21PM A ge 4 of 5(C (C COMPASS 5000.1 Build 81D (0) BP 0 BA(ER by Anticollision Report F UGHES Nora GE company Company: North America - ALASKA - BP Project: Prudhoe Bay Reference Site: PB S Pad Site Error: &00usft Reference Well: S-200 Well Error: 0.00usft Reference Wellbore S -200A Reference Design: 5-200A Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well S-200 S-200AActual @ 82.32usft (P272 Actual RKB) 5-200AActual @ 82.32usft (P272 Actual RKB) True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference Depths are relative to S-200AActual @ 82.32usft (P272 Coordinates are relative to: S-200 Offset Depths are relative to Offset Datum Coordinate System is Alaska NAD27 State Plane Zones, NAD27 * OGP-Usa AK central Meridian is 150° 0'0.000 W ° Grid Convergence at Surface is: 0.91 ° 11/30/2017 12:03:21PM a ge9-f5(C COMPASS 5000.1 Build 81D Printed 1/10/2018 5:04:20PM North America - ALASKA - $P Page 1 of 3 Cementing Report Common Well Name: S-200 / 02 Report no.: 1 Report date: 11/15/2017 Project: Prudhoe Bay Site: PB S Pad Sud Date/time: 12/15/1997 Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 AFE No.: Rig Release: 11/27/2017 X3-017WO-C: (6,876,211.00) Contractor: PARKER DRILLING CO. Rig Name/No.: PARKER 272 --- BPUOI: USS 00000172 Active datum: _S -200A Actual @82.32usft (above Mean Sea Level) General Information Job type: Primary Cement job start date/time: 11/15/2017 8:30AM Job end date/time: 11/15/2017 1:OOPM Cement Company: SCHLUMBERGER Cementer: DYLAN WAUGH Cemented String: INTERMEDIATE CASING 1 String Size: 7.000 (in) String Set TMD: 14,189.00 (usft) Hole Size: 9.875 (in) Pipe Movement Pipe Movement: RECIPROCATING Rotating Time (Start -End): RPM: Rotating Torque (init/avg/max): (ft-Ibf) Reciprocating Time (Start -End): Recip Drag Up/Down: - (kip) SPM: Stroke Length: Fluid Name: SPACER Fluids (1 of 3) Slurry Type: SPACER Purpose: SPACER Class: Description: MUD PUSH 11 Density: 12.00 (ppg) Yield: Mix Water Ratio: Excess: Mix Method: ON -THE -FLY 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: Mud Type: Density: 10.45 (ppg) PV: 13.00 (cp) YP: 21.000 (Ibf/100W) Viscosity: 44.00 (s/qt) Gels 10 Sec: 8.000 (Ibf/100ft2) Gels 10 Min: 12.000 (Ibf/100ft2) Fluid Name: CEMENT Fluids (2 of 3) Slurry Type: CEMENT Purpose: PRIMARY Class: ARCTIC SL Description: LEAD SLURRY Density: 13.00 (ppg) Yield: 1.5000 (ft'/sk) Mix Water Ratio: 5.410 (gal/sk94) Excess: 40.00(%) Mix Method: ON -THE -FLY Sacks Used: 1,543.50 (941b sacks) Water Volume: 198.8 (bbl) Excess Slurry Volume: 117.8 (bbl) Density Measured by: DENSOMETER Other Volume: Total Vol in Well: Slurry Volume: 412.4 (bbl) Excess Measured From: Mud Type: Density: 10.45 (ppg) PV: 13.00 (cp) YP: 21.000 (Ibf/100W) Viscosity: 44.00 (s/qt) Gels 10 Sec: 8.000 (Ibf/100W) Gels 10 Min: 12.000 (Ibf/100ft2) Printed 1/10/2018 5:04:20PM Printed 1/10/2018 5:04:20PM 0 0 Page 2 of 3 North America - ALASKA - BP Cementing Report Common Well Name: S-200 / 02 Report no.: 1 TReport date: 11/15/2017 Project: Prudhoe Bay Site: PB S Pad Spud Date/Time: 12/15/1997 Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 AFE No.: Contractor: PARKER DRILLING CO. Rig Name/No.: PARKER 272 Rig Release: 11/27/2017 X3-017W0-C: (6,876,211.00) BPUOI: USA00000172 Active datum: S-200A Actual @82.32usft (above Mean Sea Level) Additives Name Type Amount Units Concentration Unit D047 ANTIFOAMAGENT 0.100 GAUSX D206 ANTIFOAMAGENT 0.100 GAUSX D080A DISPERSANT 0.130 GAUSX D600 G GAS-BLOCK 0.400 GAUSX D167 FLUID LOSS 0.100 % BWOC D177 RETARDER 0.010 GAUSX Fluid Tests Thick time Thick Free water Free water Fluid loss Fluid loss Fluid loss Comp Comp Comp 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) 5.28 0.00 80.00 68.0 121.00 1,000.00 Fluid Name: CEMENT Fluids (3 of 3) Slurry Type: CEMENT Purpose: PRIMARY Class: G-CLASS Description: TAIL SLURRY Density: 15.80 (ppg) Yield: 1.1700 (W/sk) Mix Water Ratio: 5.204 (gai/sk94) Excess: 40.00(%) Mix Method: ON-THE-FLY Sacks Used: 160.00 (941b sacks) Water Volume: 19.8 (bbl) Excess Slurry Volume: 9.5 (bbl) Density Measured by: DENSOMETER Other Volume: Total Vol in Well: Slurry Volume: 33.3 (bbl) Excess Measured From: Mud Type: Density: 10.45 (ppg) PV: 13.00 (cp) YP: 21.000 (Ibf/100ft2) Viscosity: 44.00 (s/qt) Gels 10 Sec: 8.000 (Ibf/100ft2) Gels 10 Min: 12.000 (Ibf/100ft-) Addlitives Name Type Amount Units Concentration Unit D206 ANTIFOAM AGENT 0.100 GAUSX D065 DISPERSANT 0.400 % BWOC D600 G GAS-BLOCK 2.000 GAUSX D167 FLUID LOSS 0.100 % BWOC D047 ANTIFOAM AGENT 0.100 GAUSX D177 RETARDER 0.020 GAUSX Printed 1/10/2018 5:04:20PM 0 0 Printed 1/10/2018 5:04:20PM I North America - ALASKA - BP Page 3 of 3 Cementing Report Common Well Name: S-206-/ 02 - - Report no 1 Report date: 11 /15/2017 P— Project: Prudhoe Bay Site: PB S Pad Spud Date/Time: 12/15/1997 Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/24/2017 End Date: 11/24/2017 AFE No.. Contractor: PARKER DRILLING CO. Rig Name/No.: PARKER 272 Rig Release: 11/27/2017 X3 -017W0 -C: (6,876,211.00) BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Fluid Tests Thick time Thick Free water Free water Fluid loss Fluid loss Fluid loss Comp Comp Comp 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) 5.87 0.00 80.00 24.0 121.00 1,000.00 Stages Stage Stage Type Est. Top Est. Bottom Mud Circ. Mud Circ. Top Bottom Plug Pressure Float Pressure Returns Circulate Cmt Vol to Total Annular no. (usft) (usft) Rate Press. Plug Plug Bumped Bumped Held Held Prior Surface Mud Lost Flow (gpm) (psi) (psi) (min) (hr) (bbl) (bbl) After 1 PRIMARY CEMENT 7,911.00 14,148.00 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 Disp. Rate TMD TMD Pmp date/time job Used temp. temp. (bbl) Rate (bbl/min) (usft) (usft) (scf) (bbl/min) Tests Casing Test Shoe Test Liner Top Test Test Pressure: 3,500.00 (psi) FIT/LOT: (ppg) Liner Overlap: (usft) Time: 30 (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) Cmt Found on Tool: N Log/Survey Evaluation Interpretation Summary CBL Run: N Cement Top: 7,911.00 (usft) Under Pressure: (psi) How Determined: CEMENT BOND LOG Bond Quality: TOC Sufficient: Y CET Run: N Job Rating: Bond Quality: If Unsuccessful, Detection Indicator: Temp Survey: N Remedial Cement Required: N Hrs Prior to Log: (hr) How Determined: Printed 1/10/2018 5:04:20PM I Printed 1/10/2018 5:05:19PM North America - ALASKA - BP Page 1 of 3 Cementing Report Common Well Name: 5-200 / 02 - -- _P rud -oe - _ Report no.: 1 Report date: 11/25/2017 Project: h Bay Site: PB S Pad Spud DatelTime: 12/15/1997 Event Type: COM- ONSHORE (CON) Start Date: 11/24/2017 End Date: 11/27/2017 AFE No.: Rig Release: 11/27/2017 X3-017W0-C: (3,220,789.00) Contractor: PARKER DRILLING CO. Rig Name/No.: PARKER 272 BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) General Information Job type: Primary Cement job start date/time: 11/25/2017 2:30PM Job end date/time: 11/25/2017 4:30PM Cement Company: SCHLUMBERGER Cementer: KEITH PIERCE Cemented String: --None-- String Size: String Set TMD: Hole Size: Pipe Movement Pipe Movement: NO MOVEMENT Rotating Time (Start-End): RPM: Rotating Torque (init/avg/max): (ft-Ibf) Reciprocating Time (Start-End): Recip Drag Up/Doom: - (kip) SPM: Stroke Length: Fluid Name: SPACER Fluids (1 of 2) Slurry Type: SPACER Purpose: SPACER Class: Description: MUD PUSH 11 Density: 13.00 (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: 25.0 (bbl) Excess Measured From: Mud Type: Density: 9.80 (ppg) PV: 0.00 (cp) YP: 0.000 (Ibf/100ft2) Viscosity: 0.00 (s/qt) Gels 10 Sec: 0.000 (Ibf/100W) Gels 10 Min: 0.000 (Ibf/100ft') Fluid Name: CEMENT Fluids (2 of 2) Slurry Type: CEMENT Purpose: PRIMARY Class: G-CLASS Description: TAIL SLURRY Density: 15.80 (ppg) Yield: 1.1700 (ft'/sk) Mix Water Ratio: 5.206 (gal/sk94) Excess: 95.00(%) Mix Method: ON-THE-FLY Sacks Used: 312.00 (941b sacks) Water Volume: 38.7 (bbl) Excess Slurry Volume: 31.7 (bbl) Density Measured by: DENSOMETER Other Volume: Total Vol in Well: Slurry Volume: 65.0 (bbl) Excess Measured From: EST. GAUGE HOLE Mud Type: Density: 9.80 (ppg) PV: 0.00 (cp) YP: 0.000 (Ibf/100ft2) Viscosity: 0.00 (s/qt) Gels 10 Sec: 0.000 (Ibf/100W) Gels 10 Min: 0.000 (Ibf/100ft2) Printed 1/10/2018 5:05:19PM Printed 1/10/2018 5:05:19PM J Page 2 of 3 North America - ALASKA - BP Cementing Report Common Well Name: S-200 / 02 Report no.: 1 Report date: 11/25/2017 Project: Prudhoe ay Sfte: PB S Pad __ _ _ _ __ Spud Date/Time: 12/15/1997 Event Type: COM- ONSHORE (CON) _ Start Date: 11/24/2017 End Date: 11/27/2017 Rig Release: 11/27/2017 AFE No.: X3 -017W0 -C: (3,220,789.00) Contractor: PARKER DRILLING CO. Rig Name/No.: PARKER 272 BPUOI: USA00000172 Active datum: S-200AActual @82.32usft (above Mean Sea Level) Additives Name Type Amount Units Concentration Unit D206 ANTIFOAM AGENT 0.100 GAUSX D065 WEIGHTING AGENT 0.400 % BWOC D600 G GAS -BLOCK 2.000 GAUSX D167 FLUID LOSS 0.100 % BWOC D047 ANTIFOAM AGENT 0.100 GAUSX D177 RETARDER 0.040 GAUSX Fluid Tests Thick time Thick Free water Free water Fluid loss Fluid loss Fluid loss Comp Comp Comp 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) 6.12 90.00 0.00 80.00 52.0 137.00 1,000.00 Stages Stage Stage Type Est, Top Est. Bottom Mud Circ. Mud Circ. Top Bottom Piug Pressure Fbat Pressure Returns Circulate Cmt Vol to Total Annular no. (usft) (usft) Rate Press. Plug Plug Bumped Bumped Held Held Prior Surface Mud Lost Flow (gpm) (psi) (psi) (min) (hr) (bbl) (bbl) After 1 PRIMARY CEMENT 13,966.44 15,691.00 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 Disp. Rate TMD TMD Pmp date/time job Used temp. temp. (bbl) Rate (bbl/min) (usft) (usft) (sem (bbl/min) Printed 1/10/2018 5:05:19PM J Printed 1/10/2018 5:05:19PM 0 North America - ALASKA - BP Page 3 of 3 Cementing Report Common Well Name: 5-200 / 02 Report no.: 1 1 Report date: 11/25/2017 Project: Prudhoe Bay Site: PB S Pad Spud Date/Time: 12/15/1997 Event Type: COM- ONSHORE (CON) Start Date: 11/24/2017 End Date: 11/27/2017 AFE No.: X3 -017W0 -C: (3,220,7B9.00) Contractor: PARKER DRILLING CO. Rig Name/No.: PARKER 272 Rig Release: 11/27/2017 BPUOI: USA00000172 Active datum: S-200AActual @B2.32usft (above Mean Sea Level) Tests Casing Test Shoe Test Liner Top Test Test Pressure: 3,500.00 (psi) FIT/LOT: (ppg) Liner Overlap: (usft) Time: 45 (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) Cmt Found on Tool: N Log/Survey Evaluation Interpretation Summary CBL Run: N Cement Top: (usft) Under Pressure: (psi) How Determined: Bond Quality: TOC Sufficient: Y CET Run: N Job Rating: Bond Quality: If Unsuccessful, Detection Indicator: Temp Survey: N Remedial Cement Required: N Hrs Prior to Log: (hr) How Determined: Printed 1/10/2018 5:05:19PM 0 Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Friday, December 22, 2017 10:32 AM To: AK, OPS EOC Specialists; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O&M TL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS WELL PAD S; AK, OPS Well Pad SW; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Frankenburg, Amy; Youngmun, Alex; Regg, James B (DOA) Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity, AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; Wallace, Chris D (DOA) Subject: OPERABLE: Producer S -200A (PTD* 2171250) New Rotary Sidetrack All, Producer S -200A (PTD# 2171250) is a newly completed rotary sidertrack. Fullbore performed a passing CMIT-TxIA to 3880psi and MIT -T to 3862psi on 12/20/17 proving two competent well barriers. At this time the well is reclassified as Operable. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 w .+.sr ..«.. «gr.N1.a+ REC'VE r DEC 2 2 2017 B PRINT DISTRIBUTION LIST a GE company COMPANY BP Exploration Alaska Inc. WELL NAME S -200A FIELD Prudhoe Bay Unit 21 71 25 28 900 Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. DATA LOGGED /XG/201% Petrotechnical Data Center, LR2-1 a K BENDER 900 E. Benson Blvd. Anchorage, Alaska 99508 or AKGDMINTERNAL@bp.com to acknowledge receipt of this data. COUNTY PRUDHOE BAY LOG TYPE GR - RES BHI DISTRICT Alaska --- LOG DATE November 24, 2017 AUTHORIZED BY Paul Canizares EMAIL Paul. Can izaresAbhge.com TODAYS DATE December 20, 2017 Revision STATUS Final Replacement: No Details: Rev. Requested by: --- COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V 1 BP North Slope. EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aides Attn: Benda Glassmaker & Peggy O'Neil 900 E. Benson Blvd. Anchorage, Alaska 99508 FIELD / FINAL---[ CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES J# OF COPIES J# OF COPIES 4 4 4 A 4 4 01 11 1 111 0 2 ConocoPhillips Alaska Inc. 0 0 1 1 0 Attn: Ricky Elgarico ATO 3-344 700 G Street Anchorage, AK 99510 3 ExxonMobii, Alaska 0 0 1 1 0 Attn: Lynda M. Yaskell and/or Lisa Boggs 3201 C Street, Suite 505 Anchorage, AK 99503 State of Alaska - AOGCC 0 1 1 1 1 0 Attn: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 DNR - Division of Oil & Gas *** 0 0 1 1 0 Ann: Garret Brown 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 Fritamp "confidential" on all material deliver to DNR 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Attn: Gerardo Cedillo TOTALS FOR THIS PAGE: 0 2 3 I* 0 by REI. DEC 2 2 2017 " 9-3C North America - ALASKA - BP Prudhoe Bay PB S Pad S-200 S -200A 500292284601 Design: S -200A Final Survey Report 30 November, 2017 21 7125 28 900 BER BA 0 GE company • i V of Company: North America -ALASKA - BP Project: Prudhoe Bay Site: PB S Pad Well: S-200 Wellbore: S -200A Design: S -200A North Reference: Project Prudhoe Bay, PBU, PRUDHOE Minimum Curvature Map System: Alaska NAD27 State Plane Zones System Datum: Geo Datum: NAD27 * OGP-Usa AK [4267*158641 Using Well Reference Point Map Zone: NAD27 * OGP-Usa AK / Alaska zone 4 [26734*1586, Site PB S Pad, TR -12-12 Site Position: From: Map Position Uncertainty: 0.00 usft BP BA. �(ER Final Survey Report IGHES Well Position +N/ -S 0.00 usft GE company Local Co-ordinate Reference: Well S-200 TVD Reference: S-200AActual @ 82.32usft (P272 Actual RKB) MD Reference: S-200AActual @ 82.32usft (P272 Actual RKB) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM R5K-Alaska PROD -ANCP1 System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor Northing: Easting: Slot Radius: 5,980,854.540 usft 617,919.920 usft 0.000 in Latitude: Longitude: Grid Convergence: 70° 21'23.002 N 149° 2'32.343 W 0.90 ° Well Position +N/ -S 0.00 usft Northing: 5,980,504.880 usft Latitude: 70° 21' 19.407 N Well S-200, SB -01 ACTUAL Tie On Depth: 2,702.61 Depth From (TVD) Well Position +N/ -S 0.00 usft Northing: 5,980,504.880 usft Latitude: 70° 21' 19.407 N +E/ -W 0.00 usft Easting: 618,930.260 usft Longitude: 149° 2'2.971 W Position Uncertainty 0.00 usft Wellhead Elevation: ` 36.63 usft Ground Level: 36.10 usft (bore S -200A netics Model Name Sample Date Declination Dip Angle Field Strength (1) V) (nT) BGGM2017 10/9/2017 17.61 80.99 57,496 • Design Audit Notes: Version: Vertical Section: 5-200A Phase: < ACTUAL Tie On Depth: 2,702.61 Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) V) 45.69 0.00 0.00 305.55 11/30/2017 11:49:35AM Page 2 COMPASS 5000.1 Build 81D E E BP Final Survey Report BA ER F�UGHES a GE company Company: North America - ALASKA- BP Local Co-ordinate Reference: Well S-200 Project: Prudhoe Bay TVD Reference: S-200AActual @ 82.32usft (P272 Actual RKB) Site: PB S Pad MD Reference: 5-200AActual @ 82.32usft (P272 Actual RKB) Well: S-200 North Reference: True Wellbore: S -200A Survey Calculation Method: Minimum Curvature Design: S -200A Database: EDM R5K-Alaska PROD -ANCP1 Survey Program From (usft) 132.80 2,734.00 3,253.13 14,172.13 Date 11/30/2017 To (usft) Survey (Wellbore) 2,702.61 Survey #1 MWD (S-200PB1) 3,158.69 Gyrodata GWD 8-1/2" (S -200A) 14,108.45 BHGE OTK MWD 8-1/5 x 9-7/8" (S -200A) 15,658.36 BHGE OTK MWD 6-1/8" (S -200A) Tool Name MWD GYRO -WD -SS MWD+IFR+MS-WOCA MWD+IFR+MS-WOCA Description MWD - Standard Gyro while drilling single shots MWD + IFR + Multi Station W/O Crustal MWD +IFR + Multi Station W/O Crustal Survey MD Inc Azi (azimuth) TVD TVDSS N/S E/W Northing Easting DLeg V. Sec (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (°/100usft) (usft) 45.69 0.00 0.00 45.69 -36.63 0.00 0.00 5,980,504.880 618,930.260 0.00 0.00 132.80 0.18 105.08 132.80 50.48 -0.04 0.13 5,980,504.847 618,930.393 0.21 -0.13 266.74 0.22 105.08 266.74 184.42 -0.16 0.58 5,980,504.732 618,930.846 0.03 -0.57 354.93 0.28 125.59 354.93 272.61 -0.33 0.92 5,980,504.568 618,931.187 0.12 -0.94 446.77 0.14 326.02 446.77 364.45 -0.36 1.04 5,980,504.532 618,931.308 0.45 -1.06 535.82 0.62 308.78 535.82 453.50 0.03 0.61 5,980,504.917 618,930.865 0.55 -0.48 626.72 1.28 320.73 626.70 544.38 1.12 -0.42 5,980,505.995 618,929.822 0.75 0.99 716.48 2.30 316.85 716.42 634.10 3.21 -2.29 5,980,508.055 618,927.923 1.14 3.73 805.86 3.33 314.71 805.69 723.37 6.35 -5.36 5,980,511.140 618,924.802 1.16 8.0 898.95 3.34 314.25 898.62 816.30 10.14 -9.22 5,980,514.873 618,920.879 0.03 13.40 994.25 3.21 312.16 993.77 911.45 13.87 -13.19 5,980,518.537 618,916.854 0.19 18.79 1,089.60 3.24 314.39 1,088.96 1,006.64 17.55 -17.09 5,980,522.151 618,912.892 0.14 24.11 1,183.39 3.19 314.65 1,182.61 1,100.29 21.23 -20.84 5,980,525.779 618,909.084 0.06 29.30 1,277.35 k 3.09 318.61`__;".; 1,276.43 1,194.11 24.97 -24.38 5,980,529.459 618,905.491 0.25 34.35 1,372.72 3.03 322.15 1,371.66 1,289.34 28.89 -27.62 5,980,533.325 618,902.183 0.21 39.27 1,467.52 3.13 322.60 1,466.32 1,384.00 32.92 -30.73 5,980,537.310 618,899.011 0.11 44.15 1,563.96 2.68 322.39 1,562.64 1,480.32 36.80 -33.71 5,980,541.139 618,895.975 0.47 48.82 1,660.11 3.31 323.45 1,658.66 1,576.34 40.81 -36.73 5,980,545.101 618,892.887 0.66 53.62 1,755.35 3.32 326.20 1,753.74 1,671.42 45.31 -39.90 5,980,549.550 618,889.644 0.17 58.81 1,850.59 3.23 327.79 1,848.82 1,766.50 49.88 -42.87 5,980,554.064 618,886.608 0.13 63.88 11/30/2017 11:49:35AM Page 3 COMPASS 5000.1 Build 81D • BP Final Survey Report BAKER JUGHES a GE company Company: North America - ALASKA- BP Local Co-ordinate Reference: Well S-200 Project: Prudhoe Bay TVD Reference: S-200AActual @ 82.32usft (P272 Actual RKB) Site: PB S Pad MD Reference: S-200AActual @ 82.32usft (P272 Actual RKB) Well: S-200 North Reference: True Wellbore: 5-200A Survey Calculation Method: Minimum Curvature Design: 5-200A Database: EDM RSK- Alaska PROD -ANCP1 Survey MD Inc Azi (azimuth) TVD TVDSS N/S ENV Northing Easting DLeg V. Sec (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (°/100usft) (usft) 1,945.48 3.30 317.62 1,943.56 1,861.24 54.15 46ct3 5,980,558.291 618,883.275 0.61 69.02 2,035.51 5.05 310.18 2,033.35 1,951.03 58.63 -50.91 5,980,562.685 618,878.431 2.03 75.5 2,128.56 6.88 309.58 2,125.89 2,043.57 64.82 -58.33 5,980,568.760 618,870.909 1.97 85.15 2,224.68 9.36 311.56 2,221.04 2,138.72 73.67 -68.62 5,980,577.449 618,860.483 2.60 98.67 2,319.11 11.66 309.14 2,313.88 2,231.56 84.79 -81.77 5,980,588.357 618,847.160 2.48 115.83 2,414.98 11.50 311.35 2,407.80 2,325.48 97.22 -96.46 5,980,600.551 618,832.278 0.49 135.01 2,511.19 14.38 311.75 2,501.55 2,419.23 111.52 -112.57 5,980,614.586 618,815.938 2.99 156.43 2,606.10 18.41 311.50 2,592.59 2,510.27 129.30 -132.60 5,980,632.050 618,795.635 4.25 183.06 2,702.61 21.77 311.79 2,683.21 2,600.89 151.33 -157.37 5,980,653.683 618,770.526 3.48 216.02 2,734.00 22.49 311.69 2,712.29 2,629.97 159.21 -166.19 5,980,661.414 618,761.579 2.30 227.78 2,734.03 22.49 311.69 2,712.32 2,630.00 159.21 -166.20 5,980,661.421 618,761.570 0.00 227.79 9 5/8" Surface Casing 2,748.00 22.11 316.00 2,725.24 2,642.92 162.88 -170.02 5,980,665.029 618,757.691 12.02 233.03 2,777.56 21.40 318.52 2,752.70 2,670.38 170.92 -177.46 5,980,672.951 618,750.129 3.97 243.76 2,840.84 23.10 320.27 2,811.26 2,728.94 189.12 -193.04 5,980,690.898 618,734.261 2.88 267.01 2,873.08 24.25 320.98 2,840.79 2,758.47 199.13 -201.25 5,980,700.773 618,725.892 3.67 279.51 2,967.79 28.11 324.84 2,925.77 2,843.45 232.50 -226.35 5,980,733.735 618,700.263 4.45 319.3 3,061.14 31.98 325.20 ,AV` 3,006.57 2,924.25 270.79 -253.14 5,980,771.594 618,672.878 4.15 363.39 3,158.69 35.17 324.84 ,g; ` 3,087.83 3,005.51 314.98 -284.07 5,980,815.287 618,641.253 3.28 414.25 3,253.13 35.39 326.43"" ' 3,164.93 3,082.61 360.01 -314.85 5,980,859.812 618,609.760 1.00 465.48 3,265.60 35.89 326.48 4, 3,175.06 3,092.74 366.06 -318.87 5,980,865.803 618,605.649 4.02 472.27 3,359.29 39.67 328.06 3,249.10 3,166.78 414.35 -349.86 5,980,913.591 618,573.892 4.16 525.56 3,454.17 43.06 328.76 3,320.30 3,237.98 467.76 -382.69 5,980,966.467 618,540.222 3.61 583.32 3,548.80 46.68 329.49 3,387.35 3,305.03 525.06 -416.94 5,981,023.209 618,505.077 3.86 644.50 3,643.62 49.93 329.48 3,450.42 3,368.10 586.04 -452.88 5,981,083.613 618,468.171 3.43 709.20 3,738.03 52.78 330.34 3,509.37 3,427.05 649.84 -489.84 5,981,146.811 618,430.211 3.10 776.36 3,832.62 56.02 330.66 3,564.42 3,482.10 716.78 -527.70 5,981,213.129 618,391.292 3.44 846.08 11/30/2017 11:49:35AM Page 4 COMPASS 5000.1 Build 81D • 0 BP Final Survey Report BAKER JUGHES GEcompany Company: North America - ALASKA- BP Local Co-ordinate Reference: Well S-200 Project: Prudhoe Bay TVD Reference: S-200AActual @ 82.32usft (P272 Actual RKB) Site: PB S Pad MD Reference: S-200AActual @ 82.32usft (P272 Actual RKB) Well: S-200 North Reference: True Wellbore: S -200A Survey Calculation Method: Minimum Curvature Design: S -200A Database: EDM R5K-Alaska PROD -ANCP1 Survey MD Inc Azi (azimuth) ND TVDSS NIS E/W Northing Easting DLeg V. Sec (usft) N V) (usft) (usft) (usft) (usft) (usft) (usft) (°/100usft) (usft) 3,925.72 57.55 330.65 3,615.42 3,533.10 784.67 -565.87 5,981,280.401 618,352.053 1.64 916.6 4,021.67 56.36 331.34 3,667.74 3,585.42 855.01 -604.87 5,981,350.106 618,311.943 1.38 989.24 4,116.19 56.88 332.40 3,719.75 3,637.43 924.61 -642.08 5,981,419.105 618,273.637 1.09 1,059.98 4,210.95 58.38 332.23 3,770.48 3,688.16 995.48 -679.27 5,981,489.369 618,235.335 1.59 1,131.44 4,305.92 61.90 330.70 3,817.76 3,735.44 1,067.81 -718.62 5,981,561.063 618,194.841 3.96 1,205.52 4,338.94 63.62 330.10 3,832.87 3,750.55 1,093.34 -733.12 5,981,586.352 618,179.938 5.45 1,232.15 4,369.55 64.94 329.57 3,846.15 3,763.83 1,117.18 -746.98 5,981,609.969 618,165.705 4.59 1,257.29 4,400.76 66.45 329.00 3,859.00 3,776.68 1,141.63 -761.51 5,981,634.186 618,150.791 5.12 1,283.33 4,495.44 69.42 327.48 3,894.56 3,812.24 1,216.22 -807.70 5,981,708.026 618,103.427 3.47 1,364.28 4,590.18 71.99 327.84 3,925.87 3,843.55 1,291.77 -855.52 5,981,782.794 618,054.410 2.74 1,447.11 4,685.24 74.06 326.73 3,953.62 3,871.30 1,368.25 -904.66 5,981,858.486 618,004.068 2.45 1,531.56 4,780.14 75.36 324.13 3,978.65 3,896.33 1,443.62 -956.60 5,981,933.010 617,950.942 2.98 1,617.64 4,876.46 75.29 320.94 4,003.06 3,920.74 1,517.57 -1,013.27 5,982,006.042 617,893.111 3.20 1,706.74 4,969.62 75.38 317.58 4,026.65 3,944.33 1,585.84 -1,072.08 5,982,073.369 617,833.230 3.49 1,794.28 5,064.42 75.43 313.78 4,050.54 3,968.22 1,651.46 -1,136.16 5,982,137.960 617,768.119 3.88 1,884.57 5,159.01 75.39 310.18 4,074.38 3,992.06 1,712.68 -1,204.20 5,982,198.084 617,699.125 3.68 1,975.5 5,253.71 75.52 308.60 4,098.16 4,015.84 1,770.85 -1,275.04 5,982,255.115 617,627.377 1.62 2,066.9 5,348.24 75.39 307.10 4,121.90 4,039.58 1,826.99 -1,347.29 5,982,310.099 617,554.253 1.54 2,158.40 5,443.19 75.42 307.70 4,145.83 4,063.51 1,882.80 -1,420.28 5,982,364.738 617,480.387 0.61 2,250.24 5,538.00 75.48 307.16 41169.65 4,087.33 1,938.58 -1,493.16 5,982,419.346 617,406.643 0.55 2,341.96 5,632.89 75.38 306.82 4,193.52 4,111.20 1,993.83 -1,566.51 5,982,473.427 617,332.426 0.36 2,433.77 5,727.43 75.33 306.44 4,217.42 4,135.10 2,048.41 -1,639.92 5,982,526.824 617,258.172 0.39 2,525.22 5,821.85 75.39 305.71 4,241.29 4,158.97 2,102.20 -1,713.75 5,982,579.434 617,183.497 0.75 2,616.57 5,916.40 75.29 305.13 4,265.22 4,182.90 2,155.21 -1,788.29 5,982,631.253 617,108.129 0.60 2,708.04 6,010.99 75.39 305.39 4,289.16 4,206.84 2,208.04 -1,863.02 5,982,682.884 617,032.584 0.29 2,799.55 6,105.82 75.32 305.90 4,313.13 4,230.81 2,261.51 -1,937.58 5,982,735.156 616,957.192 0.53 2,891.30 6,200.44 75.42 304.88 4,337.03 4,254.71 2,314.53 -2,012.21 5,982,786.981 616,881.731 1.05 2,982.85 1113012017 11:49:35AM Page 5 COMPASS 5000.1 Build 81D • • BP Final Survey Report BAKER JUGHES a GE company Company: NorthAmerica- ALASKA - BP Local Co-ordinate Reference: Well S-200 Project: Prudhoe Bay TVD Reference: S-200AActual @ 82.32usft (P272 Actual RKB) Site: PB S Pad MD Reference: 5-200AActual @ 82.32usft (P272 Actual RKB) Well: S-200 North Reference: True Wellbore: 5-200A Survey Calculation Method: Minimum Curvature Design: 5-200A Database: EDM RSK- Alaska PROD -ANCP1 Survey MD Inc Azi (azimuth) TVD TVDSS NIS ENV Northing Easting DLeg V. Sec (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (°/100usft) (usft) 6,294.96 75.35 304.99 4,360.88 4,278.56 2,366.90 -2,08f�,Aq 5,982,838.155 616,805.934 0.13 3,074.31 6,389.56 75.57 304.69 4,384.63 4,302.31 2,419.22 -2,162.39xg, 5,982,889.264 616,729.964 0.39 3,165.8 6,484.27 75.30 305.74 4,408.45 4,326.13 2,472.08 -2,237.24 5,982,940.921 616,654.250 1.11 3,257.53 6,579.13 75.47 307.00 4,432.38 4,350.06 2,526.51 -2,311.14 5,982,994.167 616,579.494 1.30 3,349.31 6,673.53 75.46 308.24 4,456.08 4,373.76 2,582.28 -2,383.52 5,983,048.785 616,506.246 1.27 3,440.63 6,766.98 75.35 309.18 4,479.63 4,397.31 2,638.84 -2,454.09 5,983,104.208 616,434.796 0.98 3,530.92 6,862.48 75.51 308.85 4,503.65 4,421.33 2,697.03 -2,525.90 5,983,161.242 616,362.072 0.37 3,623.18 6,956.93 75.26 308.24 4,527.48 4,445.16 2,753.98 -2,597.39 5,983,217.045 616,289.703 0.68 3,714.45 7,051.26 74.53 308.11 4,552.06 4,469.74 2,810.26 -2,668.98 5,983,272.184 616,217.231 0.79 3,805.43 7,145.86 74.62 308.94 4,577.23 4,494.91 2,867.06 -2,740.32 5,983,327.839 616,145.002 0.85 3,896.50 7,240.59 74.57 309.39 4,602.39 4,520.07 2,924.74 -2,811.13 5,983,384.380 616,073.294 0.46 3,987.64 7,334.97 74.60 309.14 4,627.48 4,545.16 2,982.32 -2,881.57 5,983,440.835 616,001.951 0.26 4,078.43 7,429.38 74.50 308.28 4,652.63 4,570.31 3,039.23 -2,952.58 5,983,496.604 615,930.056 0.88 4,169.29 7,524.67 74.57 308.15 4,678.04 4,595.72 3,096.05 -3,024.74 5,983,552.260 615,857.011 0.15 4,261.03 7,619.68 74.70 308.20 4,703.21 4,620.89 3,152.67 -3,096.76 5,983,607.728 615,784.107 0.15 4,352.55 7,714.34 74.63 307.95 4,728.24 4,645.92 3,208.97 -3,168.62 5,983,662.873 615,711.365 0.27 4,443.75 7,810.01 74.66 307.59 4,753.58 4,671.26 3,265.47 -3,241.55 5,983,718.209 615,637.558 0.36 4,535.9 7,903.34 74.59 306.76 4,778.32 4,696.00 3,319.85 -3,313.25 5,983,771.436 615,565.007 0.86 4,625.89 7,998.50 74.53 306.25 4,803.66 4,721.34 3,374.42 -3,386.98 5,983,824.820 615,490.427 0.52 4,717.60 8,093.18 74.69 305.97 4,828.79 4,746.47 3,428.21 -3,460.72 5,983,877.436 615,415.841 0.33 4,808.88 8,187.77 74.63 306.13 4,853.81 4,771.49 3,481.89 -3,534.48 5,983,929.936 615,341.253 0.18 4,900.10 8,282.34 74.67 306.27 4,878.84 4,796.52 3,535.76 -3,608.07 5,983,982.618 615,266.821 0.15 4,991.29 8,377.71 74.68 306.49 4,904.05 4,821.73 3,590.31 -3,682.12 5,984,035.987 615,191.918 0.22 5,083.26 8,472.04 74.59 306.54 4,929.04 4,846.72 3,644.44 -3,755.22 5,984,088.938 615,117.971 0.11 5,174.20 8,566.73 74.64 306.52 4,954.16 4,871.84 3,698.78 -3,828.58 5,984,142.106 615,043.763 0.06 5,265.49 8,661.62 74.63 307.00 4,979.31 4,896.99 3,753.54 -3,901.89 5,984,195.689 614,969.605 0.49 5,356.97 8,756.45 74.46 307.44 5,004.58 4,922.26 3,808.82 -3,974.67 5,984,249.808 614,895.959 0.48 5,448.33 11/30/2017 11:49:35AM Page 6 COMPASS 5000.1 Build 81D • BP Final Survey Report BAKER JUGHES a GE company Company: North America - ALASKA- BP Local Co-ordinate Reference: Well S-200 Project: Prudhoe Bay TVD Reference: S -200A Actual @ 82.32usft (P272 Actual RKB) Site: PB S Pad MD Reference: S-200AActual @ 82.32usft (P272 Actual RKB) Well: S-200 North Reference: True Wellbore: S -200A Survey Calculation Method: Minimum Curvature Design: S -200A Database: EDM R5K- Alaska PROD -ANCP1 Survey MD Inc Azi (azimuth) TVD TVDSS NIS EM/ Northing Easting DLeg V. Sec (usft) (") V) (usft) (usft) (usft) (usft) (usft) (usft) (°/100usft) (usft) 8,851.11 74.47 308.42 5,029.93 4,947.61 3,864.88 -4,046.61 5,984,304.715 614,823.149 1.00 5,539.4 8,945.01 74.44 308.06 5,055.10 4,972.78 3,920.88 -4,117.66 5,984,359.570 614,751.221 0.37 5,629.81 9,039.83 74.45 307.80 5,080.52 4,998.20 3,977.03 -4,189.71 5,984,414.565 614,678.294 0.26 5,721.08 9,134.95 74.48 308.11 5,106.00 5,023.68 4,033.39 -4,261.97 5,984,469.771 614,605.153 0.32 5,812.65 9,229.55 74.47 307.87 5,131.32 5,049.00 4,089.50 -4,333.81 5,984,524.723 614,532.442 0.24 5,903.71 9,324.47 74.51 307.82 5,156.70 5,074.38 4,145.61 -4,406.04 5,984,579.680 614,459.340 0.07 5,995.10 9,419.18 74.49 307.54 5,182.01 5,099.69 4,201.40 -4,478.27 5,984,634.308 614,386.239 0.29 6,086.30 9,514.83 74.44 307.42 5,207.63 5,125.31 4,257.48 -4,551.40 5,984,689.210 614,312.232 0.13 6,178.41 9,609.40 74.43 307.11 5,233.01 5,150.69 4,312.64 -4,623.90 5,984,743.210 614,238.869 0.32 6,269.47 9,704.37 74.53 307.44 5,258.42 5,176.10 4,368.06 -4,696.72 5,984,797.463 614,165.189 0.35 6,360.93 9,799.86 74.43 307.03 5,283.97 5,201.65 4,423.73 -4,769.97 5,984,851.961 614,091.068 0.43 6,452.90 9,894.55 74.47 306.24 5,309.35 5,227.03 4,478.16 -4,843.17 5,984,905.222 614,017.017 0.80 6,544.11 9,987.66 74.51 305.32 5,334.25 5,251.93 4,530.62 -4,915.96 5,984,956.512 613,943.414 0.95 6,633.83 10,082.48 74.50 304.60 5,359.58 5,277.26 4,582.98 -4,990.84 5,985,007.669 613,867.713 0.73 6,725.20 10,177.34 74.52 304.28 5,384.92 5,302.60 4,634.68 -5,066.23 5,985,058.160 613,791.517 0.33 6,816.59 10,272.28 74.48 305.02 5,410.29 5,327.97 4,686.69 -5,141.49 5,985,108.970 613,715.447 0.75 6,908.0 10,366.82 74.49 305.65 5,435.58 5,353.26 4,739.38 -5,215.81 5,985,160.464 613,640.313 0.64 6,999.16 10,460.94 74.46 305.63, t 5,460.77 5,378.45 4,792.22 -5,289.51 5,985,212.125 613,565.790 0.04 7,089.85 10,555.97 74.43 305.72 e + 5,486.25 5,403.93 4,845.61 -5,363.88 5,985,264.324 613,490.589 0.10 7,181.40 x� 10,650.75 74.46 306.09 5,511.67 5,429.35 4,899.16 5,437.84 5,985,316.685 613,415.795 0.38 7,272.70 10,745.59 74.52 306.6 F 5,537.03 5,454.71 4,953.37 -5,511.41 5,985,369.717 613,341.380 0.60 7,364.08 10,840.02 74.47 307.04 5,562.28 5,479.96 5,007.95 -5,584.21 5,985,423.133 613,267.725 0.37 7,455.05 10,934.35 74.48 307.19 5,587.52 5,505.20 5,062.79 -5,656.69 5,985,476.815 613,194.393 0.15 7,545.90 11,029.08 74.47 307.56 5,612.88 5,530.56 5,118.20 -5,729.22 5,985,531.057 613,120.995 0.38 7,637.13 11,123.52 74.59 307.48 5,638.07 5,555.75 5,173.63 -5,801.41 5,985,585.333 613,047.940 0.15 7,728.09 11,217.79 74.63 307.26 5,663.09 5,580.77 5,228.80 -5,873.64 5,985,639.341 612,974.847 0.23 7,818.94 11,313.04 74.59 307.46 5,688.37 5,606.05 5,284.53 -5,946.64 5,985,693.898 612,900.984 0.21 7,910.73 11/30/2017 11:49:35AM Page 7 COMPASS 5000.1 Build 81D BP Final Survey Report BA, ICER UGHES a GE company Company: North America - ALASKA- BP Local Co-ordinate Reference: Well S-200 Project: Prudhoe Bay TVD Reference: S-200AActual @ 82.32usft (P272 Actual RKB) Site: PB S Pad MD Reference: 5-200AActual @ 82.32usft (P272 Actual RKB) Well: S-200 North Reference: True Wellbore: S -200A Survey Calculation Method: Minimum Curvature Design: S -200A Database: EDM RSK- Alaska PROD -ANCP1 Survey MD Inc Azi (azimuth) TVD TVDSS N/S E/W Northing Easting DLeg V. Sec (usft) V) V) (usft) (usft) (usft) (usft) (usft) (usft) (°/100usft) (usft) 11,407.41 74.59 307.30 5,713.44 5,631.12 5,339.76 -6,018.93 5,985,747.971 612,827.829 0.16 8,001.66 11,502.43 74.64 307.46 5,738.65 5,656.33 5,395.38 -6,091.73 5,985,802.423 612,754.162 0.17 8,093.2 11,600.23 74.37 308.36 5,764.78 5,682.46 5,453.28 -6,166.09 5,985,859.136 612,678.902 0.93 8,187.39 11,692.95 74.40 308.68 5,789.74 5,707.42 5,508.90 -6,235.95 5,985,913.629 612,608.168 0.33 8,276.57 11,788.03 74.40 308.96 5,815.31 5,732.99 5,566.30 -6,307.30 5,985,969.892 612,535.922 0.28 8,368.00 11,882.92 74.28 307.65 5,840.92 5,758.60 5,622.94 -6,379.00 5,986,025.374 612,463.341 1.34 8,459.26 11,977.89 74.50 308.39 5,866.48 5,784.16 5,679.28 -6,451.05 5,986,080.556 612,390.406 0.79 8,550.64 12,072.53 74.56 308.58 5,891.72 5,809.40 5,736.04 -6,522.45 5,986,136.173 612,318.122 0.20 8,641.73 12,167.22 74.50 307.94 5,916.98 5,834.66 5,792.55 -6,594.11 5,986,191.534 612,245.583 0.65 8,732.89 12,261.82 74.57 308.03 5,942.20 5,859.88 5,848.66 -6,665.97 5,986,246.495 612,172.846 0.12 8,823.98 12,356.38 74.53 307.34 5,967.39 5,885.07 5,904.38 -6,738.10 5,986,301.056 612,099.848 0.70 8,915.06 12,451.20 74.53 307.38 5,992.68 5,910.36 5,959.83 -6,810.73 5,986,355.345 612,026.347 0.04 9,006.40 12,545.75 74.50 306.79 6,017.93 5,935.61 6,014.78 -6,883.42 5,986,409.123 611,952.802 0.60 9,097.48 12,640.55 74.56 306.70 6,043.21 5,960,89 6,069.44 -6,956.63 5,986,462.610 611,878.738 0.11 9,188.83 12,735.13 74.56 306.84 6,068.39 5,986.07 6,124.01 -7,029.66 5,986,516.012 611,804.858 0.14 9,279.97 12,828.91 74.56 306.73 6,093.36 6,011.04 6,178.14 -7,102.06 5,986,568.981 611,731.618 0.11 9,370.35 12,923.65 74.53 305.60 6,118.61 6,036.29 6,232.02 -7,175.78 5,986,621.684 611,657.059 1.15 9,461.6 13,018.76 74.53 304.97 6,143.98 6,061.66 6,284.97 -7,250.60 5,986,673.434 611,581.410 0.64 9,553.32 13,113.37 74.59 305.58 6,169.17 6,086.85 6,337.64 -7,325.05 5,986,724.907 611,506.139 0.62 9,644.51 13,208.22 74.65 305.40 6,194.32 6,112.00 6,390.73 -7,399.52 5,986,776.808 611,430.849 0.19 9,735.96 13,301.95 74.66 305.32 6,219.13 6,136.81 6,443.04 -7,473.23 5,986,827.935 611,356.320 0.08 9,826.35 13,396.85 72.56 303.07 6,245.91 6,163.59 6,494.21 -7,548.52 5,986,877.898 611,280.234 3.17 9,917.36 13,491.84 70.07 301.72 6,276.34 6,194.02 6,542.42 -7,624.49 5,986,924.892 611,203.517 2.95 10,007.20 13,586.07 67.37 300.49 6,310.53 6,228.21 6,587.78 -7,699.65 5,986,969.053 611,127.645 3.11 10,094.73 13,680.86 65.02 299.01 6,348.79 6,266.47 6,630.82 -7,774.94 5,987,010.887 611,051.696 2.86 10,181.00 13,775.75 62.82 296.79 6,390.51 6,308.19 6,670.71 -7,850.24 5,987,049.572 610,975.775 3.13 10,265.46 13,870.57 60.76 294.12 6,435.34 6,353.02 6,706.63 -7,925.66 5,987,084.291 610,899.796 3.30 10,347.71 11/30/2017 11:49:35AM Page 8 COMPASS 5000.1 Build 81D • • BP Final Survey Report BAKER JUGHES a GE company Company: North America -ALASKA - BP Local Co-ordinate Reference: Well S-200 Project: Prudhoe Bay TVD Reference: S-200AActual @ 82.32usft (P272 Actual RKB) Site: PB S Pad MD Reference: 5-200AActual @ 82.32usft (P272 Actual RKB) Well: S-200 North Reference: True Wellbore: S -200A Survey Calculation Method: Minimum Curvature Design: S -200A Database: EDM R5K-Alaska PROD -ANCP1 Survey MD Inc Azi (azimuth) TVD TVDSS NIS E/W Northing Easting DLeg V. Sec (usft) V) (I (usft) (usft) (usft) (usft) (usft) (usft) (°/100usft) (usft) 13,965.20 59.30 290.93 6,482.62 6,400.30 6,738.05 -8,OOi.z36 5,987,114.495 610,823.614 3.30 10,427.5 14,059.80 57.18 287.23 6,532.42 6,450.10 6,764.36 -8,077.34 5,987,139.596 610,747.231 4.01 10,504.68 14,108.45 55.75 286.29 6,559.29 6,476.97 6,776.06 -8,116.17 `- 5,987,150.674 610,708.226 3.35 10,543.07 14,148.00 55.22 285.99 6,581.71 6,499.39 6,785.11 -8,147.47 5,987,159.233 610,676.786 1.49 10,573.81 7' Production Casing 14,172.13 54.89 285.80 6,595.53 6,513.21 6,790.53 -8,166.50 5,987,164.346 610,657.681 1.49 10,592.44 14,206.34 53.33 282.30 6,615.59 6,533.27 6,797.26 -8,193.37 5,987,170.653 610,630.704 9.46 10,618.22 14,237.30 53.22 279.62 6,634.10 6,551.78 6,801.98 -8,217.73 5,987,174.983 610,606.276 6.95 10,640.78 14,268.25 53.02 278.05 6,652.68 6,570.36 6,805.78 -8,242.19 5,987,178.396 610,581.759 4.11 10,662.89 14,301.11 51.49 275.47 6,672.79 6,590.47 6,808.85 -8,267.99 5,987,181.050 610,555.918 7.76 10,685.66 14,332.14 51.03 274.29 6,692.21 6,609.89 6,810.91 -8,292.11 5,987,182.726 610,531.776 3.32 10,706.48 14,360.55 50.83 273.01 6,710.12 6,627.80 6,812.31 -8,314.12 5,987,183.781 610,509.747 3.57 10,725.20 14,395.29 50.38 270.71 6,732.17 6.649.85 6,813.19 -8,340.95 5,987,184.228 610,482.909 5.28 10,747.54 14,426.56 50.39 270.55 6,752.11 6,669.79 6,813.45 -8,365.03 5,987,184.110 610,458.823 0.40 10,767.29 14,455.13 50.36 270.24 6,770.33 6,688.01 6,813.60 -8,387.04 5,987,183.913 610,436.820 0.84 10,785.28 14,492.25 50.35 270.55 6,794.01 6,711.69 6,813.80 -8,415.62 5,987,183.656 610,408.241 0.64 10,808.6 14,521.05 51.35 269.90 6,812.19 6,729.87 6,813.89 -8,437.95 5,987,183.388 610,385.911 3.89 10,826.8 14,550.35 54.76 269.98 6,829.80 6,747.48 6,813.86 -8,461.37 5,987,182.993 610,362.502 11.64 10,845.91 14,584.25 59.14 270.08 6,848.29 6,765.97 6,813.88 -8,489.78 5,987,182.557 610,334.100 12.92 10,869.03 14,614.48 60.54 269.02 6,863.47 6,781.15 6,813.67 -8,515.91 5,987,181.935 610,307.973 5.54 10,890.18 14,644.96 62.34 268.37 6,878.05 6,795.73 6,813.06 -8,542.67 5,987,180.900 610,281.226 6.20 10,911.59 14,679.12 65.51 268.00 6,893.06 6,810.74 6,812.09 -8,573.34 5,987,179.440 610,250.584 9.33 10,935.98 14,710.69 69.10 267.64 6,905.24 6,822.92 6,810.98 -8,602.44 5,987,177.869 610,221.508 11.42 10,959.01 14,739.71 72.67 267.31 6,914.74 6,832.42 6,809.77 -8,629.83 5,987,176.226 610,194.144 12.35 10,980.59 14,773.64 77.87 267.53 6,923.36 6,841.04 6,808.29 -8,662.60 5,987,174.230 610,161.404 15.34 11,006.39 14,808.70 81.20 267.81 6,929.73 6,847.41 6,806.89 -8,697.04 5,987,172.283 610,126.990 9.53 11,033.60 14,834.11 84.04 268.02 6,932.99 6,850.67 6,805.98 -8,722.22 5,987,170.967 610,101.830 11.21 11,053.56 11/30/2017 11:49:35AM Page 9 COMPASS 5000.1 Build 81D • 0 BP Final Survey Report BAKER JUGHES a GE company Company: North America - ALASKA- BP Local Co-ordinate Reference: Well S-200 Project: Prudhoe Bay TVD Reference: S-200AActual @ 82.32usft (P272 Actual RKB) Site: PB S Pad MD Reference: S-200AActual @ 82.32usft (P272 Actual RKB) Well: S-200 North Reference: True Wellbore: 5-200A Survey Calculation Method: Minimum Curvature Design: 5-200A Database: EDM RSK- Alaska PROD -ANCP1 Survey MD Inc Azi (azimuth) TVD TVDSS NIS E/W Northing Easting DLeg V. Sec (usft) V) V) (usft) (usft) (usft) (usft) (usft) (usft) (°/100usft) (usft) 14,868.38 88.53 268.71 6,935.21 6,852.89 6,805.00 -8,756.40 5,987,169.450 610,067.677 13.25 11,080.79 14,899.97 93.59 269.23 6,934.63 6,852.31 6,804.43 -8,787.96 5,987,168.381 610,036.124 16.10 11,106.1 14,928.72 97.40 269.98 6,931.88 6,849.56 6,804.24 -8,816.58 5,987,167.729 610,007.521 13.50 11,129.31 14,963.31 100.96 271.29 6,926.36 6,844.04 6,804.61 -8,850.72 5,987,167.563 609,973.384 10.95 11,157.31 14,994.31 103.66 272.29 6,919.75 6,837.43 6,805.56 -8,880.98 5,987,168.027 609,943.106 9.26 11,182.48 15,023.27 104.00 273.06 6,912.83 6,830.51 6,806.87 -8,909.07 5,987,168.893 609,915.001 2.84 11,206.10 15,117.80 104.00 272.83 6,889.96 6,807.64 6,811.58 -9,000.67 5,987,172.151 609,823.345 0.24 11,283.37 15,152.04 104.03 273.07 6,881.67 6,799.35 6,813.29 -9,033.85 5,987,173.333 609,790.148 0.69 11,311.35 15,183.49 103.78 272.42 6,874.11 6,791.79 6,814.75 -9,064.34 5,987,174.311 609,759.638 2.16 11,337.01 15,213.08 102.14 272.24 6,867.47 6,785.15 6,815.92 -9,093.16 5,987,175.025 609,730.814 5.57 11,361.14 15,246.46 98.07 272.03 6,861.62 6,779.30 6,817.15 -9,125.99 5,987,175.727 609,697.969 12.21 11,388.56 15,277.72 93.84 272.25 6,858.38 6,776.06 6,818.31 -9,157.05 5,987,176.395 609,666.895 13.55 11,414.51 15,307.01 90.61 271.90 6,857.24 6,774.92 6,819.37 -9,186.30 5,987,176.990 609,637.639 11.09 11,438.92 15,340.32 88.67 270.16 6,857.45 6,775.13 6,819.97 -9,219.60 5,987,177.060 609,604.336 7.82 11,466.36 15,372.89 88.52 271.57 6,858.25 6,775.93 6,820.46 -9,252.15 5,987,177.035 609,571.779 4.35 11,493.13 15,401.51 88.61 274.70 6,858.96 6,776.64 6,822.02 -9,280.72 5,987,178.145 609,543.196 10.94 11,517.28 15,433.42 90.73 279.63 6,859.15 6,776.83 6,826.00 -9,312.37 5,987,181.621 609,511.490 16.82 11,545.3 15,464.73 93.89 281.24 6,857.88 6,775.56 6,831.67 -9,343.13 5,987,186.796 609,480.645 11.32 11,573.67 15,494.89 94.20 281.77 6,855.76 6,773.44 6,837.67 -9,372.61 5,987,192.327 609,451.075 2.03 11,601.14 15,589.75 97.71 279.54 6,845.92 6,763.60 6,855.11 -9,465.31 5,987,208.299 609,358.118 4.38 11,686.71 15,658.36 98.03 X8,.75 6,836.52 6,754.20 6,866.50 -9,532.31 5,987,218.619 609,290.948 0.56 11,747.84 15,691.00 98.03 274,5 6,831.96 6,749.64 6,871.97 -9,564.16 5,987,223.586 609,259.015 0.00 11,776.94 41/2' Production Liner 15,693.00 98.03 5 6,831.68 6,749.36 6,872.31 -9,566.12 5,987,223.890 609,257.058 0.00 11,778.72 Projection to TD� 11/30/2017 11:49:35AM Page 10 COMPASS 5000.1 Build 81D 10 10 0 by BP Final Survey Report Company: North America - ALASKA- BP Local Co-ordinate Reference: Project: Prudhoe Bay Is ND Reference: Site: PB S Pad is$,sS MD Reference: Well: S-200 North Reference: Wellbore: S -200A Survey Calculation Method: Design: 5-200A Database: Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 2,734.03 2,712.32 9 5/8" Surface Casing 9.625 12.250 14,148.00 6,581.71 7" Production Casing 7.000 8.500 15,691.00 6,831.96 4 1/2" Production Liner 4.500 6.1251 1113012017 11: 49: 35AM Page 11 BAER F�UGHES a GE company Well S-200 S-200AActual @ 82.32usft (P272 Actual RKB) S-200AActual @ 82.32usft (P272 Actual RKB) True Minimum Curvature EDM R5K - Alaska PROD - ANCP1 COMPASS 5000.1 Build 81D Is r`a is$,sS Page 11 BAER F�UGHES a GE company Well S-200 S-200AActual @ 82.32usft (P272 Actual RKB) S-200AActual @ 82.32usft (P272 Actual RKB) True Minimum Curvature EDM R5K - Alaska PROD - ANCP1 COMPASS 5000.1 Build 81D E 0 Company: North America - ALASKA- BP Project: Prudhoe Bay Site: PB S Pad Well: S-200 Wellbore: S -200A Design: S -200A Design Annotations Measured Vertical Depth Depth (usft) (usft) 15,693.00 6,831.68 BP Final Survey Report Local Coordinates +N/ -S +E/ -W (usft) (usft) Comment 6,872.31 -9,566.12 Projection to TD Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: BAKER JUGHES GE company Well S-200 S-200AActual @ 82.32usft (P272 Actual RKB) S-200AActual @ 82.32usft (P272 Actual RKB) True Minimum Curvature EDM R5K-Alaska PROD -ANCP1 I Prepared By: Yosha Ragbirsingh Survey Manager Baker Hughes a GE Company 11/30/2017 11:49:35AM Page 12 0 COMPASS 5000.1 Build 81D �4F i .5»A �§ a Page 12 0 COMPASS 5000.1 Build 81D • Davies, Stephen F (DOA) From: Wages, David <David.Wages@bp.com> Sent: Thursday, December 14, 2017 10:44 AM To: Davies, Stephen F (DOA) Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) Did you get the log data for S -200a? the drillers should have sent it. If you haven't, I can track it down for you. David wage P I AK I Completion Fngineer 900 E. Benson Blvd 1744c I Anchorage, AK 99515 Direct: F1.907,564,5669 I mobile: +-1,713.380'.9836 From: Davies, Stephen F (DOA)[ma i Ito: steve. davies@alaska. gov] Sent: Tuesday, November 28, 2017 12:56 PM To: Wages, David Cc: Loepp, Victoria T (DOA) Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) David, Could BP please also provide digital open -hole well log and directional survey data for the PBU S -200A well? (Field -run well log data in LAS or ASCII format are fine. The most recent directional survey data in spreadsheet or ASCII format are appreciated.) Regards, Steve Davies Alaska Oil and Gas Conservation Commission (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.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Tuesday, November 28, 2017 11:46 AM To:'Wages, David' <David.Wages@bp.com> Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.Rov> Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) David, That's great to hear. In addition to my requests, below, could BP also please provide an updated wellbore schematic drawing that includes perfs, packer(s), frac sleeves, and BP's determination for the top of cement? Also, this morning while again reading through BP's Sundry Application for fracturing operations in PBU S -200A, I realized that I had overlooked the fact that the Area of Review for PBU S -200A encompasses all of PBU S-200A—from TD to ground surface—and not just the portion of the well that is open to the Kuparuk formation as shown on BP's plat that accompanies the application. (See my email to you regarding BP's Sundry Application to fracture the PBU S-11361_1 lateral wellbore, dated Tue 10/18/2016 9:12 AM.) So, please accept my apologies for this oversight and please submit i n L_.J the following information that is required under 20 AAC 25.283 but was not provided in BP's Sundry Application for fracturing operations within PBU S-20OA: Regulation Deficient Information 20 AAC 25.283(a)(2)(C) Since PBU S -200A is open to the ground surface, the one-half mile radius Area of Review 20 AAC 25.283(a)(10) (AOR) encompasses PBU S -200A from TD to ground surface. For that AOR: 20 AAC 25.283(a)(11) 20 AAC 25.283(a)(2)(C) — identify each well penetration within one-half mile of any portion of PBU S -200A from TD to the ground surface; 20 AAC 25.283(a)(10) - provide the location, the orientation, and a report on the mechanical condition of each well within that AOR that transects the confining zones, and information sufficient to support a determination that the well will not interfere with containment of the hydraulic fracturing fluid; and 20 AAC 25.283(a)(11) — provide the location of, orientation of, and geological data for each known or suspected fault or fracture that may transect the confining zones within that AOR, and information sufficient to support a determination that the known or suspected fault or fracture will not interfere with containment of the hydraulic fracturing fluid. Regards, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITYNOTICE: 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.davies@alaska.gov. From: Wages, David [mailto:David.Wages@bp.com] Sent: Tuesday, November 28, 2017 11:19 AM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) Steve, Got our logs back, our original plans will be modified, will submit supplemental information as soon as final decisions are made. We have made a couple changes but for the most part, things are going as planned. David wages BP I AK I Completion Enamcor 900 E. Benson Blvd 1744c I An(horage, AK 99515 Direct: +1.907,564.5669 I Mobile: +1.713.330.9836 From: Davies, Stephen F (DOA)[mailto:steve.daviesOdalaska.gov] Sent: Tuesday, November 28, 2017 10:30 AM To: Wages, David Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) David, I'm finishing my review of the Sundry Application for fracturing operations in PBU S -200A. I don't believe that I received answers from BP regarding my requests and questions that are highlighted with yellow in the emails below. Thanks, 2 Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Friday, October 27, 2017 9:05 AM To:'Wages, David' <David.Wages@bp.com> Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) David, Thanks for your help. For clarity of the public record and to ensure that a standardized review process is followed for every application, each application must stand alone, which is the reason behind_ any repetitive questions. If that information isn't provided in each application, I'll keep requesting it. Thanks again, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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.davies@alaska.gov. From: Wages, David [mailto:David.Wages@bp.com] Sent: Wednesday, October 25, 2017 11:48 AM To: Davies, Stephen F (DOA) <steve.davies alaska.gov> Cc: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov>; Wallace, Chris D (DOA) <chris.waIlace@alas ka_ ov>; Sidoti, Todd <Todd.Sidoti@bp.com> . Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) Steve, To answer your initial question: with top of Kuparuk at -6738' TVDss, our geologist estimates, based on offsets, that the - top of the Miluveach is 430' below this at 7168'. Having said that, our frac modelling software does not predict height growth to get to even half that distance. I can immediately address some of the questions below and will forward to appropriate channels for further clarification: 1. S -200a is an openhole completion, thus the location of the fracture initiation point is very much an estimate. We do know that the top sandstone layers of Kuparuk, based on neighboring sonic data by which closure stress can be obtained, typically have the lowest closure stress. In conjunction with this, there is a certain degree of jetting action that takes place when pumping through a frac sleeve at frac rates. This, I believe, help to initiate the frac near the frac sleeve. Therefore, when we place a sleeve on the cross-section/WBD, it is placed at a point 3 0 0 that 1) optimizes reserve recovery and 2) at a place where we think the frac will initiate. The exact position is to be modified upon drilling of the well and the logs are obtained. Our driller are looking into the ellipse for us. To my knowledge, we have not done active measuring of the induced fracture length. I myself have done plenty of post job pressure matching to the extent that I can say that 250' if very likely the max half length of the induced frac if it were a planer frac. The more I work in the Kuparuk, the more I am coming to the conclusion that the induced fracture are more complex than what a planer fracture model would estimate. A more complex induced structure also (probably) means and even shorter induced frac half-length. 3. Question forwarded on to our seismic people 4. 1 believe I've addressed this question before but I will happily address it again. When drilling, we occasionally get at an X -Y caliper which can highlight borehole breakout. Depending on the azimuth of the wellbore upon drilling, there is a predominate trend for when borehole breakout occurs. For us, in the Kuparuk, this happens when we drill —30 deg south of west, which is indicative of the maximum stress direction. The min stress direction would then be 90 degrees (perpendicular) to the max. HAVING SAID THAT: in order to create complex fractures or non -planer fractures, you must physically change the local minimum stress direction. When you are fracing you are indeed moving rocks, compacting them which can indeed alter the local stress field. This can be compounded by the fact that, I believe, the max and minimum stress magnitudes are close together so it is relatively easy to alter the local field. Take Eaton's equation which predicts closure pressure: Pc=K(Pob- Pres)+Pres +tectonics where: a. Pc is closure pressure b. K, an effective stress ration, usually close to 1/3 c. Pob is overburden pressure, usually 1 psi/ft d. Pres is reservoir pressure e. And tectonics thrown in there at the last The tectonics of the region are what determines the direction of the max/min stress in that equation. When I look at the slope from a USGS earthquake history perspective, it really isn't all that geologically active. It's not near a large subduction or divergent plate boundary to my knowledge, while the sub -structure looks like shattered glass, those faulting events happened during a period of high regional plate stress/movements. in the end, 30 deg west of north is the ultimate answer... Will try and get a prompt answer back to you for your remaining inquiries. Thanks, David wages BP I AK I Completion Engineer 960 E. Benson Blvd 1744c I Anchorage, AK 99515 Direct: +1.907.561.5569 1 Mobile: +1313.380.9836 From: Davies, Stephen F (DOA)[mailto:steve.davies@alaska.gov] Sent: Wednesday, October 25, 2017 10:14 AM To: Wages, David Cc: Schwartz, Guy L (DOA); Wallace, Chris D (DOA) Subject: FW: PBU S -200A (PTD 217-125; Sundry 317-491) David, I have a couple of additional questions due to the very close proximity of the eastern -most proposed fracturing perforations in PBU 5-200A to fault #1. These perforations are expected to be only about 150' away from the maximum fracture length predicted by computer modeling. 1. How confident is BP in the location of the proposed fracturing perforations? What are the dimensions of the 2D ellipse of uncertainty in the directional survey data at this depth? 2. How confident is BP that the maximum length of the induced fracture will be 250'? Has BP ever conducted a post -audit or monitoring survey to see if modeled fracture lengths are close to the actual length of induced fractures? If so, how closely .do modeled fracture lengths agree with actual fracture lengths? • i 3. How confident is BP in the location of fault #1? Was it mapped using 3D seismic data? What is the spacing of the lines (bin size) in this area? Can you provide an estimate of possible position error for this fault (uncertainty ellipse dimensions)? 4. 1 see two predominant trends in the faults on BP's map for PBU S -200A, north and northwest. What is the basis for BP's belief that the induced fractures will trend about 30 degrees west of north in this area? Thanks, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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.davies2alaska.gov. From: Davies, Stephen F (DOA) Sent: Tuesday, October 24, 2017 5:44 PM To: david.wages@bp.com Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) David, The Miluveach Shale will serve as lower confinement for the Kuparuk Formation. Could BP please provide the estimated frac gradient value for the Miluveach Shale that was used for computer simulation of the proposed fracturing operations? Thanks, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Tuesday, October 24, 2017 3:28 PM To:'Wages, David' <David.Wages@bp.com> Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) David, No, we need the well log and final directional survey data to confirm locations, depths, hydrocarbon -bearing intervals, confining intervals, and the absence of faults. But with most of the other review done up front, we can get this application before the Commissioners shortly after receiving the well log data. I'll let you know if I have any questions or need any other additional information. Thanks, Steve Davies 0 • Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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.davies@alaska.gov. From: Wages, David [maiito:David.Wages@bp.com] Sent: Tuesday, October 24, 2017 1:40 PM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: RE: PBU S -200A (PTD 217-125; Sundry 317-491) Steve, Thanks for the note, we are presently getting ready to move over to S -200a. In regards to this, we would like to get on the well as soon as the rig leaves, I know you've been in this position before, is there any chance we can get approval before you guys get the logs? David mages BP I AK I Completion Engem-er 900 E. Benson Blvd 17441 I Anchorage, AK 99515 Direct: +1..907.564.5669 1 Mobile: +1.713.3800 9836 From: Davies, Stephen F (DOA)[mailto:steve.davies(dalaska.gov] Sent: Tuesday, October 24, 2017 11:22 AM To: Wages, David Subject: PBU S -200A (PTD 217-125; Sundry 317-491) David, I'm reviewing the Sundry Application to fracture stimulate PBU S -200A. Could you please tell me the current status of the well? Has it been drilled? If so, could you please provide digital well log data for the field logging runs (gamma ray, resistivity, porosity) for this well? If not, when do you anticipate digital well log data will be available for the well? Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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.davies@alaska.gov. 0 Loepp, Victoria T (DOA) From: Gorham, Bradley M <Bradley.Gorham@bp.com> Sent: Monday, November 27, 2017 10:47 AM To: Loepp, Victoria T (DOA) Cc: Lastufka, Joseph N; Oshiro, Joleen Subject: S -200A Update - (PTD# 217-125) Attachments: S -200A ST PROPOSAL REV 12017-XX-XX.PDF Follow Up Flag: Follow up Flag Status: Flagged Victoria, �p7-D 21-7 -12-5 Please see the attached document for the updated wellbore schematic. Also, the FIT conducted after drilling out the 7" shoe was a 12.7 ppg EMW. This value provided adequate kick tolerance as well as exceeded our planned drilling ECD's for the production hole section. The production liner was cemented, cement was circulated off the top of the liner and the liner and liner top packer achieved a passing pressure test. The rig ran the planned completion and is expecting to release later today. Please let me know if you need any other information or have any questions. Thanks, Brad Brad Gorham BP Exploration (Alaska), Inc. Drilling Engineer W: (907)564-4649 C: (907)223-9529 Bradley.Gorham@bp.com Ll S -200A: IBC Cement Analysis Objective: Evaluate Intermediate lin Cement Job 0 0 S-20OA: lin Intermediate Cement Evaluation: Objective is Cl In order of importance #1 Determine top of full circumferential cement coverage of the lin casing for BP10-60 and AOGCC isolation requirements above the following estimated DPZ locations (as drilled and prognosed depths) • GP10-60: Cumulative 98.4ftMD (30mMD) of >6.5ftMD (2mMD) individual intervals above Schrader Bluff Na Sand and between DPZ1 and DPZ2 • AOGCC: TOC 500ftMD above and between significant hydrocarbon zones Planned TOC is 7400ftMD. S -200A has a mud loss zone at 7832ftMD. Determine requirement for remediation or down squeeze post rig operations. Zone Interval Depth Depth LitholoFluid (ftTVD gy Comments Type Name (ftMD) Type SS) Type Seal T Schrader Actual formation DPZ 1 8802 4934 Sand Water Bluff Na top Actual formation OBF Base 10150 5295 Sand Water top I Seal 2 k I Prognosed DPZ 2 TKUP 14439 6738 Sand light Oil k formation top i Bottom of DPZ 2 is j not penetrated i i is Cl 16 I* STEM 0 SAV -- ------------ ----------- --- CL? —Ion Am AWAY AIAV OF 79 AZE6 N W� ;E 2 mr X7930' 79SO by • Depth Referenced to P-272 RTE TOC above Schrader Bluff and Kuparuk Reservoir zones: 7884ftMD • • 3 • • S-200: lin Cement Job Timing and Details (15-Nov-2017) Pump Pressure T-14-1 Pump Rates Cement Job Details .330. 1300 450 INTI CRILL CMT P iES CEMENT 7' INTERMEDIATE CASING AS FOLLOW` HOLD PJSM WITH ALL PARTIES INJOL.'ED IN CEME',- JOB REVIEW PRESSURE CROSSCHECK - FILL LINES WITH 12 PPG MUDPUSH 11 SPACER AND PRESSURE TEST TO 4500 PSI FOR 5 MINUTES. GOOD TEST - PUMP 50 BELS OF 12 PPG MUDPUSH II SPACER AT 6 BPM, 500 PSI UNSTING VOLANT TOOL AND RELEASE BOTTOM PLUG -PUMP 412 BBLS OF 13 PPG ARCTIC SET LEAD CEMENT AT 68PM. EXCESSVOLUME 40% (YIELD '� CU.FTI;K7. ICP 850 PSI. FCP 400 PSI - PUMP 33 BBLS OF 15 8 PPG CLASS G TAIL CEMENT AT 6 BPM, EACESS VOLUME 401 MELD 1.17 CU.FT/SKI. ICP 800P 00PSIFCP 850 PSI S' - UNSTING `,'OLANT TOOL AND DROP TOP PLUG - SCHLUMBERGER CEMENTERS KICK OUT WITH 10 BBLS WATER . PERFORM DISPLACEMENT WITH RIG PUMPS AND 10 `. PPG LSND MUD PER SLB CEMENTICS MODEL - 91 BBLS DISPLACED AT 7 BPM. ICP 180 PSI. FCP 180 PSI /DID NOT CATCH. PRESSURE) - OBSERVE BOTTOM PLUG LANDING AND CEMENT EXITING SHOE - OBSERVE 500 PSI SHEAR OF BOTTOM PLUG AT 91 BBLS DISPLACED .316 BBLS DISPLACED AT 70PM :CP 180 PSI FC = _9 61 P51, -8S% RETURN FLOW DECREASE FLOW RATE DUE TO INCREASING PUMP PRESSURE - 19 BBLS DISPLACED AT 5 BPM ICP 1677 PSI FCP 3170 PSI _65% FLOW DECREASE FLO'h' RATE DUE TO INCREASING PUMP PRESSURE. STOP RECIPROCATING PIPE STRETCH AT THIS POINT - 59 BBLS DISPLACED AT 4 BPM ICP 3222 SI FC= 4116 PSI. -45% RETURN FLOW'. DECREASE FLO'.% RATE DUE TO INCREASING PUMP PRESSURE - 17 SOLS DISPLACED AT 3 BPM'. ICP 4098 PSI FC= 4782 PSI. UNABLE TO CONTINUE PUMPING - SHUT DOWN PUMPS AND CLOSE ANNULAR TO PRE`. ENT WELL FROM BREATHING BACK - BLEED OFF PUMP PRESSURE AND CHECK FLOATS GOOD - CEMENT 84 PLACE AT 1 T 10 TOTAL VOLUME 10.5 PPG LSND PUM- � C = 507 BBLS, -21.5 BBLS LEFT INSIDE THE 7' C:'- '. Volumetric TOC estimate: 7830ftMD • • S -200A: UCA Data 9N.uaMP1 .8.$fi25+ CNIwKCampnNYv.51m,p.� IWO Schlumberger Drwr+p P«N9- 30 wcs.a: .ri comP,wswc au x. ,00a pu m 36.5/ cm . �„�� „� o �ww servlcl. Laporeloly cama+rNa>vmgm ptt A xa. ;nay „ oea e PDO,N: 19D]6596155 s/aaMN •190)6599]it Field Blend Lead Cement:13ppg: 3.62MRayls at 37hrs LOND9a. 8-A011 Ceebney up wps� 8.28.00 f6a Nerve pnYllmNpla-UCAB v yNC - 500 pp 12 T1.m 160p psi 11 ram eN SNKw +1,112011 1.as 06 PM 0—." "— 116— 2000 pP WA 1Ym.+LNCNErew +gNUW r.o.+ppep3aaw.+]Dp808N•o+ppDSWOw +M+a]12 o+p feel 8loppw 11/1b201] 3l)II AM 500 Oat 02600 1000 pM- WA m - ]s ~r w Pnme6 ti/16201)839m AM WsT Qd"F Jae Type N1nn•Nw Lew FNM iRer19 Rb— P-271 Dp Pa,pr+ inW+menl.]-/252AISR Cumnt Compresvw spenpm ]pf5pv Schlumberger cOsNwevs -,g. rypelmae mas t<IIYS.x' Fmdl ('., �..I.:f•.;..�Vl�a y+ X11': cx-at 18:400 Pnbioe Day We19N.[as Laawafby Te1p1vN: •t 90]8596155 F9UxmN- •1 907 659 9221 Tail Cement: 15.Sppg : 5 MRayls at 13:29hrs TNN (KN:W) lOtaevu s-2WA SOpR: k51:m CeNoeMr: K l000N: BMJD fseoa crw. iozrm 9yabm: 6.0 IpP00W>•O.t9gD$o6wA%0085.2.OpDSO600f3.0,1%p161w.03ppeD1>]� 6.3Tm BNCT: 121 aepF f211r 139T pv =;P:" al9hMwmeOULF TW FNM DNN N M. WA Rqf : Pw V2 Schlumberger BanpNq Peva. m Fnat C9mprNm Slrenpt6 Wa al P Conpeswe —�M I— type A A (Nu taan 11 rv.,.� � •uMwDay We0 8emtta LM1aYaY aDaPns. + 90] 65p 6155 •190] Gip D221 Field Blend 10% Contaminated 13 ppg Cement'--'* j D Oap 5:00 lOpO 15:00 20:00 ISaD Fse W , PKI]BR8016-UGAT T-- 11/11201) SD]28 Ptl L- SQA •+D PY: 11'1830 TaY Bb{paU: 11f1K2p1] 9'51:10 AY BJh Or 500 Oat 02600 1000 pM- WA PrNM: ttrt/201)If X611 AM 0.." 13we0Y: 1.0 D1+U9a1 8y W m: 1M�MtlMe i 3.•SDR'M• N W 2000 D8+WA pagl DN.0 21rNr mWpAp 124 '21 =7T YM.5=--F-0— 0aFNDM Ra Rams. : TIyN (H+:RR) FM N.tn1s: 90Np981>nN0145Y8pxerd%W�bU(:Ai T -SI—' 11/11201] A, WPM Te118fopye.. PTNO'. 11/15!201) 12:5]:tl PM P8981 • .]12a2mxe ,ap comp,«,„• sl.«,pa+: 5pz w • • 5-200A: Predrill Wellbore Schematic (actual depths may differ) € VALOCiAD- tY MI SAfEiY NOTES: CHROME TBG& LNR Af.'RMTOR• PROPOSED S -200A GzW aF. Eta = --ar KOP- 2MW 4 trr 1� x w. D- a.atal OMrnAD• . OL.aaalVn`""_.. soon ss Minimum ID TOPaFCBABO J at? TIKi, 72aa, IaCR•aa VAM TOP. asae- a, L -a0 V AM o- 6 276• 4 -Ur 8YM1 PACKM NO OMM D 4 3 2 t 4-1R'L171a." tat/4aF M1111521. .0150. D. a.saa M 11r LNL 16.56, MR -0 MY o 521. T873Y 1 GAS LFTkNRIAn S I'��QOm��iLl�� Oar NCS HYD 521 FRAC &LEWES POLARS UNT —.._.. V41i1. SS200A PERXVT w _ ARW 50.02972816-ot SEC 35, T12K TM 430' NSL 6 45W VWI "ram MORE COMPLETION BDEMMX M!!o _ _ _ 02112Jta AID BItT""USAL 8PL3p1ora11on1ALwka) RONNE Oar NCS HYD 521 FRAC &LEWES CA F&V W COMA94M D4TE REV BY 0o160JtC POLARS UNT —.._.. V41i1. SS200A PERXVT w _ ARW 50.02972816-ot SEC 35, T12K TM 430' NSL 6 45W VWI "ram MORE COMPLETION BDEMMX M!!o _ _ _ 02112Jta AID BItT""USAL 8PL3p1ora11on1ALwka) RONNE CA F&V W COMA94M D4TE REV BY 0o160JtC POLARS UNT —.._.. V41i1. SS200A PERXVT w _ ARW 50.02972816-ot SEC 35, T12K TM 430' NSL 6 45W VWI "ram MORE COMPLETION BDEMMX M!!o _ _ _ 02112Jta AID BItT""USAL 8PL3p1ora11on1ALwka) • • 10 0 5-200A: IBC Toolstring •• Equip na—Length XIJUH 73.17 XTRA-A 705 AH -330 56.06 AH -107[ 55.35 a1 GAL-YA 53.35 • EDTC-8 49.85 AH -1071 43.35 3] DSLT-H 41.35 MP name Offset 52-56 46.3S 44.48 43.35 _�-COIL 3ft 28.88 • Upper -N 26.88 ear .--VDL 5ft 27.88 ar Delia -T 26.5 Lower -F 25.13 ar Lower -N 24.13 ear SLS -E 20.71 AH -107[ 10.71. 2] AH -107( 18.71 11 USTT-E 16.71 R .-USI Sen 0.87 *or TOOL ZERO Lercths are in R Maximum Outer Diameter - 6.250 m L,M::ens+ Location, Value: Gating Offset Alt nxasrnements are relative to TOOL ZERO 7 0 Loepp, Victoria T (DOA) From: Raese, J. Kyle <john.raese@bp.com> Sent: Friday, November 03, 2017 4:02 PM To: Loepp, Victoria T (DOA) Subject: RE: S-200A(PTD 217-125) Follow Up Flag: Follow up Flag Status: Flagged Victoria, 0 PTO a/ 7-- —/ z 5" We are still drilling the 8-1/2" x 9-7/8" intermediate section at 9100' MD. Estimated TD is 14,500' MD. Kyle -----Original Message ----- From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday, November 3, 2017 2:05 PM To: Raese, J. Kyle <john.raese@bp.com> Subject: Re: S-200A(PTD 217-125) I don't have the program with me. Have you drilled and cemented the intermediate? What step? Sent from my iPhone > On Nov 3, 2017, at 12:39 PM, Raese, J. Kyle <john.raese@bp.com> wrote: 1 THE STATE 9 0 A 1 44115klywaml k Kenneth Allen GOVERNOR BILL WALKER Engineering Team Leader BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Conservation Commission Re: Prudhoe Bay Field, Aurora Oil Pool, PBU S -200A BP Exploration (Alaska), Inc. Permit to Drill Number: 217-125 Surface Location: 4301' FSL, 4500' FEL, Sec. 35, T12N, R12E, UM Bottomhole Location: 604' FSL, 3545' FEL, Sec. 21, T12N, R12E, UM Dear Mr. Allen: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for permit to re -drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Hollis S. French L Chair r DATED this day of October, 2017. STATE OF ALASKA OLASKA OIL AND GAS CONSERVATION COMMI* SEP 0 5 2017 PERMIT TO DRILL 20 AAC 25.005 A r% r% r tom 1 a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1c. Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development - Oil E • Service - Winj ❑ Single Zone 1Z • Coalbed Gas ❑ Gas Hydrates ❑ Redrill E • Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond Blanket E. Single Well ❑ 11. Well Name and Number: BP Exploration (Alaska), Inc Bond No. 29S105380 PBU S -200A 3 Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 196612 Anchorage, AK 99519-6612 MD: 15739' • TVD: 6823' ' PRUDHOE BAY, AURORA OIL .-. 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): ADL 028257, 028258 & 028256 Surface: 4301' FSL, 4500' FEL, Sec. 35, T12N, R12E, UM g DNR Approval Number: 13, Approximate spud date: Top of Productive Horizon: 551' FSL, 2385' FEL, Sec. 21, T12N, R12E, UM 83-47 October 23, 2017 9. Acres in Property: 2560 14. Distance to Nearest Property: Total Depth: 604' FSL, 3545' FEL, Sec. 21, T12N, R12E, UM 6900 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 83.05' feet 15. Distance to Nearest Well Open Surface: x- 618930 • y- 5980505 • Zone - ASP 4 GL Elevation above MSL: 36.10 • feet to Same Pool: 1340 16. Deviated wells: Kickoff Depth: 2734 ' feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 107 degrees Downhole: V 3279 Surface: 2594 , 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casin Weiqht Grade Cowling Len th MD TVD MD TVD(including stage data 9-7/8" 7" 26# L-80 VamTop HC 14529' Surface Surface 14529' 6821' 1434 sx LiteCrete. 152 sx Class 'G' 6-1/8" 4-1/2" 12.6# 13Cr85 H dri1 521 1360' 14379' 6624T'_ 15652' 6821' Uncemented Slidinq Sleeves w/ Swell Packers 19, PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): 1 Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 1 6310 5466 5625,5726,5756 5625 4 None Casing Length Size Cement Volume MD TVD Conductor/Structural 76 20" 260 sx Arctic Set (Ar mrox.) 33-109 33-109 Surface 3127 9-5/8" 2508 sx Cold Set, 234 sx Class 'G' 32-3159 32-3081 Intermediate 4446 7" 235 sx Class 'G' 30-4476 30-3927 Production Liner 1983 3-1/2" 330 sx Class 'G' 4327-6310 3845-5466 Perforation Depth MD (ft): 5660-5680 Perforation Depth TVD (ft): 4851 -4870 Hydraulic Fracture planned? Yes E No ❑ 20. Attachments Property Plat ❑ BOP Sketch E Drilling Program E Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program E 20 AAC 25.050 requirements E 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated Contact Name Gorham. Bradlev M from without prior written approval. Authorized Name Allen, Kenneth W Contact Email Bradley. Gorham(o)_bp.com Authorized Title Engineering Team Lead Contact Phone 907-564-4649 Authorized Signature Com---. Date ,S Commission Use Only Permit to Drill�/ Number: ` r I - I � _5 API : 50- 029-22846-01-00 Permit Approv Date: v See cover letter for other requirements: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed met ane, gas hydrates, or gas contained in shales: Other: !0Q /f7 tomos f fO Jr� G �' ` Sa��l s'd: Yes ❑ No l� Mud log req'd: Yes ❑1 No .00P �J1� v4gv /.7 /"-C vr� fiT� fl_5 r 6 ZSM2S ureas es Yes No ❑ Directional svy req'd: Yes ® No ❑/ j e F—,O j i`i — Q C� 3 Spacing exception req'd: Yes ❑ No Inclination -only svy req'd: Yes ❑ No Er v) CJ Cct7 t7 % i C}i Gi /G�+ rjL' �) YirC� fG t' -FrCA-C Post initial injection MIT req'd: Yes11❑ No CQLo� eC� iraylYrht 0- eva,i-cval�al1.ern sj-il3�t �cctlovl SccCOY1Ci1'f1o05o apPrOYa! log rf�t.`ft-Cci �✓%ntCrrreCdr'ce-c Ca 51 ng.' _ _—_APPROVED _--'Cat)Achccl)ti UStT(Sonic)�5rvcn t`ntty CeIur %n Approved by: COMMISSIONER THE OMMISSIONfor ��bit'vvc Date: 10 � V' /Pooh 10-401 Revised 5/2017if 4rnonths from the date of approval (20 AAC 25.005(g)) Ilee �'�<�`7 ubmit Form and ccc�� Attachments in Dyp`0te J PBU S-200A(PTD 217-125) Conditions of Approval: Approval is granted to run the (USIT)Sonic on upcoming well PBU 5-200A with the following provisions: 1. BP will provide a written log evaluation/interpretation to the AOGCC along with the log as soon as they become available. The evaluation is to include/highlight the intervals of competent cement (and lengths) that BP is using to meet the objective requirements for annular isolation, reservoir isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation is not acceptable. 2. (USIT)Sonic logs must show free pipe and Top of Cement, just as the a -line log does. BP must start the log at a depth to insure the free pipe above the TOC is captured as well as the TOC. Starting the log below the actual TOC based on calculations predicting a different TOC will not be acceptable. 3. BP will provide a cement job summary report and evaluation along with the cement log and evaluation to the AOGCC when they become available 4. BP will provide the results of the FIT when available. 5. Depending on the cement job results indicated by the cement job report, the logs and the FIT, remedial measures or additional logging may be required. LM To: Alaska Oil & Gas Conservation Commission From: Brad Gorham, ODE Date: September 5, 2017 RE: S -200A Permit to Drill The S -200A well is scheduled to be drilled by Parker 272 in October 2017. This Sidetrack well is a horizontal producer targeting the Kuparuk C4 Sands. The planned well is a two string rotary sidetrack, utilizing a 7" intermediate casing and 4-1/2';production liner. The intermediate casing will be set at the - top of the Kuparuk, and the production interval will be completed with a cementless liner using sliding sleeves and swell packers. The maximum anticipated surface pressure from the Kuparuk with a full column of gas from TD to surface is 2,594, psi (assumes 9.2 ppg EMW most likely pore pressure and a 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 and annular will be tested to 3,500 psi. " A detailed operations summary is included with the permit application. Of note, this well will be accessing the same targets as S-136. The S-136 well already has an approved permit to drill, please consider that permit to drill no longer valid. If there are any questions concerning information on S -200A, please do not hesitate to use the contact information below. Brad Gorham Office: (907) 564-4649 Cell: (907) 223-9529 Email: Bradley. GorhamCaD_bp,com Attachments: Well Bore Schematic Proposed Pre -Rig Schematic Proposed Completion Directional Package BOPE Schematic As -Staked Survey Well Head Schematic Tree Schematic S -200A PTD 1 9/5/2017 • Planned Well Summary is Well S -200A • Wee Producer Target Objective Kuparuk . Current Status Rotary Sidetrack Estimated Start Date: I 10/23/2017 Time to Complete: 1 29.1 Days Planned KOP: 2,734' MD Planned TD: 15,739' MD / 6,740' TVDss Rig: I GL -RT: I I RTE (ref MSL): 1 83.05' Directional - Baker wp08A KOP: 2,734' MD - Northing Easting Offsets TRS Surface Tgt See Attached Directional Plan Nearest Property Line: 6,900' Location 5,980,505.0 618,930.00. 4301.23' FS / 4500.64' 12N 12E Sec 35 6,740' 4728.33' FNL / 12N 12E Sec 21 FEL Planned KOP: 2,734' MD Planned TD: 15,739' MD / 6,740' TVDss Rig: I GL -RT: I I RTE (ref MSL): 1 83.05' Directional - Baker wp08A KOP: 2,734' MD - Northing Easting TVDss Offsets TRS Tgt See Attached Directional Plan Nearest Property Line: 6,900' Nearest Well within Pool: 1,340' Casing 5,987,184.0 610,370.6 6,740' 4728.33' FNL / 12N 12E Sec 21 Point 2384.94' FEL Tgt 6 BHL 5,987,220.0 609,210.0 6,740' 4675.24' FNL / 3544.74' FEL 12N 12E Sec 21 Planned KOP: 2,734' MD Planned TD: 15,739' MD / 6,740' TVDss Rig: I GL -RT: I I RTE (ref MSL): 1 83.05' Directional - Baker wp08A KOP: 2,734' MD - Maximum Hole Angle: -740 in the intermediate section -1070 in the production section Close Approach Wells: S-107, a tubing plug will be set as well as having the well shut-in and LOTO Survey Program: See Attached Directional Plan Nearest Property Line: 6,900' Nearest Well within Pool: 1,340' S -200A PTD 2 9/5/2017 U Formation Tops and Pore Pressure Estimate (SOR) S -200A PTD • Formation Estimated Formation Top (TVDss) Most Likely Pore Pressure (EMW ppg) Fluid Type (for sands) BPRF 1,866 EOCU 8.40 Water/Hydrates SV5 8.40 Water/Hydrates SV4 -2402 8.60 Water/Hydrates KOP (in SV4) -2630 8.60 Water/Hydrates SV3 -2695 8.60 Water/Hydrates SV2 -2832 8.70 Water/ Gas cut mud SV1 -3160 9.00 Free Gas UG4 -3494 8.85 Water/ Heavy Oil UG4A -3540 8.85 Water/ Heavy Oil UG3 -3838 8.85 Water/ Heavy Oil UG1 -4331 8.70 Water/ Heavy Oil MA -4639 8.70 Water/ Heavy Oil MB -4776 8.70 Water/ Heavy Oil MC -4873 8.70 Water/ Heavy Oil NA -4930 8.70 Water NB -4943 8.70 Water NC -4963 8.70 Water NE -4969 8.70 Water NF -4996 8.70 Water OA -5020 8.60 Water OBA -5055 8.60 Water OBB -5087 8.60 Water OBC -5129 8.60 Water OBD -5171 8.60 Water OBE -5217 8.60 Water OBF -5251 8.60 Water OBF BASE -5293 8.60 Water CM2 -5683 9.20 Water/ Gas cut mud CM-1/TLBK -6153 10.00 Water/ Gas cut mud THRZ -6467 10.00 Water/ Gas cut mud TKLB -6759 10.00 Water/ Gas cut mud TKUD -6738 9.20 Light Oil TKC4 -6738 9.20 Light Oil 7" intermed casing -6740 9.20 Light Oil TKC3D -6759 9.20 Light Oil TKC3C -6779 9.20 Light Oil /�✓ lip, 4�1 (?, 5- /C-)• 5/ /°I (-1--//I / 3 9/5/2017 C Tli -6814 9.20 Water Tll -6853 9.20 Water TKC3A -6857 9.20 Water "I'll -6825 9.20 Water TKC3C -6792 9.20 Light Oil "I'll -6771 9.20 Light Oil TD -6741 9.20 Light Oil Casing/Tubing Program Hole Size Liner / WVFt Grade Conn Length Top Bottom AN FLHTHP FL Tbg O.D. KOP — 5,640' MD 9.3-9.6 <15 18-24 MD / TVDss MD / Ti 8-1/2" x 9- 7/8" 7" 26# L-80 VamTop HC 14,529' Surface 14,529'/ 6,740' 6-1/8" 4'/2" 13.5# and 13Cr-85 Hydril521 1,360' 14, 379' / 6,160' 15,652'/6,740' 12.6# (150' lap) Tubing 4 V 12.6# 13Cr-85 VamTop 14,384' Surface 14,384'/ 6,161' (-5' into liner TBS) Mud Program c>-1� , carredu��4r�s��"-o-c-/.s,�c�! � IL Al.1- . A 9 -7 Intermediate Mud Properties: LSND 8-1/2 x Hole Depth Interval Secctionoon Depth Interval Density PV (cp) YP Ib/1 Oft AN FLHTHP FL �� "" W TpH KOP — 5,640' MD 9.3-9.6 <15 18-24 <8 NA <15 9-10 5,640' — 14,529' MD 10.4-11.1 <18 18-22 <4 <10 <20 9-10 Production Mud Properties: Water Based Polymer Fluid (QuikDril-N) 6-1/8" Hole Section Depth Interval Density PV (cp) YP Ib/1 Oftz API FL HTHP FL MBT pH 14,24 ''MD - TD 9.5-9.7 <8 12-20 <10 NA <4 9.5 — 10.5 Logging Program 8-1/2" x 9-7/8" Sample Catchers - as required by Geology Intermediate Drilling: Dir/GR/GRAB/RES Open Hole: None Cased Hole: None 6-1/8" Production Sample Catchers - as required by Geology Drilling: Dir/GR/RES/NEU/DEN Oen Hole: None Cased Hole: None Cement Program S -200A PTD 4 9/5/2017 Lead Open hole volume + 40% excess Basis Lead TOC 1300' above top of SB Na $$u Tail Open hole volume + 40% excess + 80 ft shoe track S -200A PTD 4 9/5/2017 Surface and Anti -Collision Issues Surface Close Proximity: f, No wells will be affected by the Parker 272 rig shadow. Sub -Surface Pressure Management: Verify Cretaceous (Ugnu) pressure 1 month prior to spud (consult with PE responsible for the disposal wells). Verify the pressure environment for drilling the Kuparuk using the history matched dynamic model for the area and offset well data. SIBHP required in well S-114Ai within 6 months but greater than 3months ahead of S -200A spud date. Shut-in S -107i 2 weeks prior to well spud date. Shut-in S-1 14A 2 weeks prior to well spud date. If S-1 14A SIBHP is >3600psi then evaluate longer shut-in period based on MBAL, simulation or PFO data. Anti -Collision: S-1 07A fails major risk. However, it passes at 1:200 and has been minor risked as such. Also, S-1 07A will have a tubing tail plug set as well as having the wing and swab -v ' alve locked out and tagged out. Of note, this well was going to be shut-in for pressure management s well. Offset well ownership information: All offset wells identified within 200 ft of the proposed wellbore are operated by BP. S -200A PTD 5 9/5/2017 Tail TOC 500 ft MD above casing shoe Spacer -50 bbls of Viscosified Spacer weighted to -11.0 pp (Mud Push II) Total Cement Lead 445 bbls, 2496 cuft, 1434 sks of 11.5 ppg LiteCRETE, Yield: 1.74 cuft/sk Volume Tail 31.5 bbls, 176 cuft, 152 sks 15.8 lb/gal Class G - 1.16 cuft/sk Temp BHST 150° F Surface and Anti -Collision Issues Surface Close Proximity: f, No wells will be affected by the Parker 272 rig shadow. Sub -Surface Pressure Management: Verify Cretaceous (Ugnu) pressure 1 month prior to spud (consult with PE responsible for the disposal wells). Verify the pressure environment for drilling the Kuparuk using the history matched dynamic model for the area and offset well data. SIBHP required in well S-114Ai within 6 months but greater than 3months ahead of S -200A spud date. Shut-in S -107i 2 weeks prior to well spud date. Shut-in S-1 14A 2 weeks prior to well spud date. If S-1 14A SIBHP is >3600psi then evaluate longer shut-in period based on MBAL, simulation or PFO data. Anti -Collision: S-1 07A fails major risk. However, it passes at 1:200 and has been minor risked as such. Also, S-1 07A will have a tubing tail plug set as well as having the wing and swab -v ' alve locked out and tagged out. Of note, this well was going to be shut-in for pressure management s well. Offset well ownership information: All offset wells identified within 200 ft of the proposed wellbore are operated by BP. S -200A PTD 5 9/5/2017 Ol Hydrogen Sulfide S -Pad is not considered an H2S site. Recent H2S data from the pad is as follows: Faults Formation Where Encounter Fault Well Name 1-12S Level Date of Reading #1 Closest SHL Well 1-112S Level S-118 10 1/19/2013 #2 Closest SHL Well 1-12S Level S -213A 19 ✓ 1/3/2016 #1 Closest BHL Well 1-12S Level S-100 135 1/26/2016 #2 Closest BHL Well H2S Level S-106 50 3/20/2015 #3 Closest BHL Well H2S Level S-119 20 1/19/2016 #4 Closest BHL Well 1-12S Level S -1o2 16 1/20/2016 Max Recorded H2S on Pad/Facility S-201 180 3/9/2012 Faults Formation Where Encounter Fault MD Intersect TVDss Intersect Throw Direction and Magnitude Uncertainty Lost Circ Potential Fault #2 - UG1 6,800.0 4,420.0 West, 80 ft. +225'/-275' MD Low Fault #2A - MB 8,100.0 4,780.0 West, 130 ft. +225'/-275' MD Low Fault #4 - Kuparuk 14,900.0 6,850.0 West, 20-30 ft. +/-100' MD Moderate Fault #7 - possible fault (Kuparuk) 15,283.0 NA West, 40-50 ft. +/-125' MD moderate 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. S -200A PTD 6 9/5/2017 IIS • Well Control .7 The 8-1/2" x 9-7/8" 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 3,500 psi. BOP test frequency for S -200A will be 14 days with function test 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 14 day BOP test period should not be requested. 8-1/2" x 9-7/8" Intermediate Interval Maximum anticipated BHP 3,224 psi at the TKC4 at 6,740' TVDss (9.2 ppg EMW) Maximum surface pressure 2,550 psi at the TKLB (0.10 psi/ft gas gradient to surface) Kick tolerance 25 bbls with 13.40 ppg frac gradient. Assumes 9.2 ppore pressure in the TKC4 + 0.5 ppg kick intensity and 11.1 ppg MW. Planned BOP test pressure Rams test to 3,500 psi / 250 psi. Annular test to 3,500 psi / 250 psi Integrity Test — 9-7/8" hole LOT after drilling 20'-50' of new hole 6-1/8" Production Interval Maximum anticipated BHP 3,279 psi in the TKC3 at 6,856' TVDss (9.2 ppg EMW) Maximum surface pressure 2,594 psi (0.10 psi/ft gas gradient to surface) ,f Kick tolerance Infinite with >11.5 ppg frac gradient. Assumes an 9.2 ppg max pore pressure in the TKC3 + 0.5 ppg kick intensity and 9.6 ppg MW. Planned BOP test pressure Rams test to 3,500 psi / 250 psi. Annular test to 3,500 psi / 250 psi Integrity Test — 6-1/8" hole FIT after drilling 20'-50' of new hole 4-1/2" Liner Top Packer 3,500 psi surface pressure Planned completion fluids 10.1 ppg Brine S -200A PTD 7 9/5/2017 Drill and Complete Operations Summary Rig Operations 1. MIRU Parker 272. 2. Test BPV from below to 3,500 psi for 30 minutes. 3. Nipple down tree. Nipple up and test BOPE to 3,500 psi. 4. Pull BPV with lubricator. 5. RU hard lines to BOP. Circulate out diesel freeze protection through choke to tiger tank with clean 8.5 ppg seawater. 6. RU and pull the 3-1/2" tubing from the pre -rig jet cut. 7. RU E -line and run IBC log to confirm cut depth for the 7" casing 8. If USIT confirms, MU casing cutter and cut 7" casing at 2,850' MD. 9. RU and pull 7" casing from cut. 10. RIH with 9-5/8" clean out assembly down to the top of the 7" casing stub. i 11. RU E -line w/ GR/CCL log and set EZSV at 2,765' MD and pressure test to 250 psi for 5 min and 3,000 psi for 5 min. 12. PU 9-5/8" whipstock, bottom trip anchor and 8-1/2" window milling assembly (to include full gauge string mills). RIH to the top of the EZSV. Orient and set the whipstock. 13. Swap the well over to 9.3 ppg fresh water LSND milling fluid. ----------------------------------------End of Sundry: Start of Permit to Drill ---------------------------------- 14. Mill window in the 9-5/8" casing plus 20' of formation. 15. Perform LOT. POH for drilling BHA. -- 16. MU 8-1/2" drilling BHA, GR/RES, GWD, and RIH. Kick off and drill 8-1/2" intermediate interval. 17. Drill to the end of build section. 18. POOH and LD 8-1/2" motor BHA. 19. PU 8-1/2" RSS drilling BHA, GR/RES/PWD/GRAB, NOV Anderreamer, and RIH. 20. Drill 8-1/2" x 9-7/8" intermediate interval to section TD in TKUP. Weight up drilling fluid using spike fluid maintaining the following density ranges: • KOP - 5,640' TVDss: 9.3 - 9.6 ppg z -� 3r�r - // �/',10 ` eta • 5,640' TVDss - 6,232 TVDss: 9.5 - 10.4 /rt ' v ppg ✓ 9`.�� -- /.3, $`� c.7 �P`itS • 6,232 TVDss - TD: 10.4 - 11.1 ppg �3, ° i'gll s 21. At TKUP, CBU or until hole is clean (minimum 2x), then perform short trip to the window. g' 22. RIH to TD and circulate the well clean and POH on elevators. 23. Change upper VBR pipe rams to 7" casing rams and test to 250 psi low / 3,500 psi high. 24. Run and cement 7", 26#, L-80, VAM TOP casing to TD. Top of cement will be at 1,300' MD above the SB Na. 25. Pressure test the 7" casing to 250 psi low / 3,500 psi high for 5 minutes low / 30 minutes high. 26. Change upper 7" casing rams to 2-7/8" x 5" VBR pipe rams and test to 250 psi low / 3,500 psi minutes high when the plug bumps. 27. Install the 7" pack -off through the stack and test to 250 psi low/ 5,000 psi high for 30 minutes. 28. Freeze protect the 9-5/8" x 7" annulus, once the tail cement has reached compressive strength. S -200A PTD 8 9/5/2017 0 29. MU 6-'/" drilling RSS, with GR/RES/NEU/DEN. 30. Displace the well to 9.5 ppg Flo -Pro fluid prior to fully drilling out shoe track. 31. Drill 20' of new formation and perform a FIT. IV 32. Drill 6-1/8" hole to TD. 33. Circulate bottom ups and condition the hole as necessary. 34. Perform short trip to the 7" shoe. 35. RIH to TD and circulate / condition the hole as necessary until shakers clean up. POOH on elevators and LD 6-1/8" drilling BHA. 36. MU and run 4-1/" 12.6# 13CR HYD 521 sliding sleeve / packer liner to TD. 37. Set liner hanger and liner top packer. Prior to pulling the running tool, perform a pressure test on the liner top packer by testing the 7" casing x drill pipe annulus to 250 psi low / 3,500psi high for 5 min low / 30 min high. 38. Pull liner running tool above liner top. Displace well to clean seawater. 39. POH, L/D the liner running too . f e- ,-, �r� f cva 6 ✓ �' �'" �" CO �r � ✓a !th l Ii �CSVviiG� �S 40. RU E -line and run -log -to verify TOCPin the 7" annulus. �---- _r -VO scz Cov) 6'+T'nt15 1G �Gyat � t, o4irov'a{ a++,aCk.C. . 41. R/U and run a 4-Y2", 12.6#, 13CR, VT tubing completion witA GLM's. Space out a land the tubing with tubing tail inserted into the liner tieback sleeve. 42. Make up tubing hanger per Cameron Rep. Land the tubing hanger, and run in lock down screws. 43. Reverse circulate 9.8 ppg brine and corrosion inhibitor into the tubing x casing annulus. 44. Drop ball/rod and set packer and individually test the tubing and annulus to 250 psi low / 3,500 psi for 30 minutes. Record each test. 45. Hold pressure on the IA and bleed tubing pressure to zero, shearing the DCK shear valve. Pump both ways to confirm circulation ability. 46. With landing joint still rigged up, reverse circulate diesel freeze protect using rig injection pump. 47. Allow diesel to U-tube, drain stack, and rig down landing joint. Monitor well for 1 hour to confirm well is dead. 48. Install TWC and test from above and below to 250 psi low / 3,500 psi high for 5 minutes each. 49. Nipple down the BOPE. Nipple up the adaptor flange and double master valves and test to 5,000 psi with diesel. 50. Ensure Heet® is left on top of the TWC and only diesel (no water) is left in the tree. 51. Install all annulus valves and secure the well. Ensure T/IA/OA all have two barriers in place. 6ymV0]IT, IQ Planned Post -Rig Operations: 1. Pull BPV, pull ball and rod and RHC plug with slickline. 2. Install Evotrieve to MIT -T and MIT -IA. Retrieve Evotrieve. 3. Three Stage Frac Stimulation 4. Pull shear valve and dummies, install GLVs. 5. Post Frac FCO. 6. Perform ASRC flowback and well test 7. Install flow lines and well house S -200A PTD 9 9/5/2017 0 0 S -200A Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control / Reservoir Pressures A. Intermediate Hole: The SV1 is expected to be a 9.0 ppg EMW. The CM1 and HRZ are expected to be a 10.0 ppg EMW. Formation pressures will be controlled with a 9.3 — 9.6 ppg mud to drill to within 200' MD of the CM1. At this point, there will be a weight up to 10.4 — 10.7 ppg to drill the rest of the interval to TD. B. Production Hole: The Kuparuk is expected to be at a 9.2 ppg EMW. Reservoir pressures will be controlled by using 9.6 — 10.0 ppg water based mud. II. Lost Circulation/Breathing A. Intermediate Hole: There are two expected fault crossings in the intermediate hole, both with a low probability of losses. However, breathing has been known to occur in the Colville on other pads in Prudhoe Bay as a result of high ECD's. B. Production Hole: There is 1 expected fault crossing in the production hole with a moderate potential for lost circulation. III. Fault Locations Formation Where Encounter Fault MD Intersect TVDss Intersect and Magnitude Throw Direction Uncertainty Lost Circ Potential Fault #2 - UG1 6,800.0 4,420.0 West, 80 ft. +225'/-275' MD Low Fault #2A - MB 8,100.0 4,780.0 West, 130 ft. +225'/-275' MD Low Fault #4 - Kuparuk 14,900.0 6,850.0 West, 20-30 ft. +/-100' MD Moderate Fault #7 - possible fault (Kuparuk) 15,283.0 NA West, 40-50 ft. I moderate V. Integrity Testing Test Point Test Depth Test t pe EMW (lb/gal) 9-5/8" Window 20'-50' from the 9-5/8" window LOT 13.40 ppg 7" shoe 20'-50' from the 7" shoe FIT 11.5 pp S -200A PTD 10 9/5/2017 0 0 V. Hydrogen Sulfide S -Pad is considered an H2S site. Recent H2S data from the pad is as follows: VI. Anti -Collision Issues S-1 07A fails major risk. However, it passes at 1:200 and has been minor risked as such. Also, S-1 07A will have a tubing tail plug set as well as having the wing and swab valve locked out and tagged out. Of note, this well was going to be shut-in for pressure management as well. CONSULT THE S -PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. S -200A PTD 11 9/5/2017 Well Name H2S Level Date of Reading #1 Closest SHL Well H2S Level S-118 10 1/19/2013 #2 Closest SHL Well H2S Level S -213A 19 1/3/2016 #1 Closest BHL Well H2S Level S-100 135 1/26/2016 #2 Closest BHL Well H2S Level S-106 50 3/20/2015 #3 Closest BHL Well H2S Level S-119 20 1/19/2016 #4 Closest BHL Well H2S Level S-102 16 1/20/2016 Max Recorded H2S on Pad/Facility S-201 180 3/9/2012 VI. Anti -Collision Issues S-1 07A fails major risk. However, it passes at 1:200 and has been minor risked as such. Also, S-1 07A will have a tubing tail plug set as well as having the wing and swab valve locked out and tagged out. Of note, this well was going to be shut-in for pressure management as well. CONSULT THE S -PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. S -200A PTD 11 9/5/2017 TREE= 4-1/16" 5M CIW WELLHEAD = 11" 5M FMC ACTUATOR= BAKE KB. R EV = 62.18' BF. ELEV = 37 KOP = 2209' Max Angle = 57 @ 4385' Datum MD = 5889' Datum TVD = 5000' SS 0 S-200 9-5/8" CSG, 47#, L-80, ID =8.681" H 3159' Minimum ID = 2813°' @ 1466' 3-1/2" X NIPPLE TOP OF3-1/2" LNR I--1 4327' 3-1/2" TBG, 9.3#, L-80_0087 bpf, ID = 2.992" 1-1 4330' 7" CSG, 26#, L-80, ID = 6.276" H 4476' PERF(RATION SJMMARY REFLOG: PLATFORMD(PRESS ON01/16/98 ANGLE AT TOP PERF: 19 @ 5660' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 6 5660-5680 C 05/13/03 2-1/2" 4 5755-5765 S 03/18/03 2-1/2" 4 5835-5843 S 03/18/03 2-1/2" 2 5882-5886 S 03/18/03 2-1/2" 2 5886 - 5889 S 03/18/03 2" 4 5886-5889 S 03/18/03 2-1/2" 2 5889-5895 S 03/18/03 2-1/2" 4 5916-5926 S 03/18/03 2-1/2" 4 6012-6022 S 03/18/03 2-1/2" 4 6066-6072 S 03/18/03 PBTD - 6236' 3-1/2" LNR, 9.3#, L-80_0087 bpf, ID =2.992" 6310' SOY NOTES: 1466' 1--j3-1/2"X NIP, ID = 2.813" GAS LIFT MANDRELS ST MDjVD DEV TYPE VLV LATCH PORT)AT E 4 1582 1518 3C AMCO QMRK 0 09/25/03 32577 2502 18 CAMCO DPIYRK 0 09/25/03 2 3826 3493 53 CAMCO SO RK 24 09/25/03 1 4229 3727 55 DAMCO DMY RK 0 09/25/03 4259° -1 3-1/2"X NIP, ID = 2.813" 4284' 7" BKR S-3 PKR, ID = 3.875"-1 4310' 3 112" X NIP, ID = 2.813" 4321' 73 1/2" X NIP, ID = 2.813" 4327° BKR ZXP LNR HGR PKR W/TIEBAG< SLV, RS NIP &CMC WR HGR, ID = 4.25" 4330' 3 1/2" WLEG 4343° ELMD TT IOGG® 05/07/98 5300' -13-1/2"X NIP, ID = 2.813" 5625' 3-1/2"X NIP, ID = 2.813" TTP SET 09/26/03 5726'-1-43-1/2- BKRCIBP (D5/13/ 5756° 8181 —� CEMENTFOP (05/13/03) 5796' 3-1/2" X NIP, ID = 2.813" 5874' 3-1/2" X NIP, ID =2.813" 5972' 3-1/2" X NIP, ID = 2.813" 6040' F -13-1/2"X NIP.ID=2.813" DATE REV BY COMMENTS DATE REV BY COMMENTS 01/23/98 ORIGINAL COMPLETION 05/13/03 BJMcN/TL SETIBP/ADD PERFS 03/16/01 SIS -CS FINAL 07/22/03 JCM/KK LV C/O 09/24/01 RN/TP CORRECTIONS 09!25/03 LJ/TLH LV 1(M 05/21/02 GGKAK PERF CORRECTIONS 02/08/05 ATD/TLH TTPSET(09/26/03) 03/18/03 DAV/TLH SQZ PERFS 04/08/03 RS /TP I TVD/MD CORRErTIONS POLARIS UNIT WELL: S-200 PERMIT No:1972390 API NSii-029-22846-00 SEC35, T12N, T12E, 430' NSL & 4500' WEL BP Exploration (A laska) TREE= 4-1/16" 5M CIW WELLHEAD 11" 5M FM ACTUATOR= BAKE KB ELEV = 62.18' BF. ELEV = 37' KOP = 2209' Max Angle = 57 @ 4385' Datum MD = 5889' Datum TVD = 5000' SS 9-5/8" CSG, 47#, L-80, ID = 8.681" 3200' 3159' Minimum ID = 2813" @ 1466' 3-1/2" X NIPPLE TOP OF3-1/2" LNR H 4327- 3-1/2" TBG, 9.3#, L-80-0087 bpf, ID = 2.992" I--1 4330' 7" CSG, 26#, L-80, ID = 6.276" I 4476' Cement plugs 5600' S-200 P&A I S YNOTES: PERFORATION SJMVIARY REFLOG: PLATFORM EXPRESS ON01/16/98 ANGLE AT TOP PERF: 19 @ 5660' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 6 5660-5680 C 05/13/03 2-1/2" 4 5755-5765. S 03/18/03 2-1/2" 4 5835-5843 • S 03/18/03 2-1/2" 2 5882- 5886 S 03/18/03 2-1/2" 2 5886 - 5889 S 03/18/03 2" 4 5886-5889 S 03/18/03 2-1/2" 2 5889-5895 S 03/18/03 2-1/2" 4 5916-5926 S 03/18/03 2-1/2" 4 6012-6022 • S 03/18/03 2-1/2" 4 6066-6072 S 03/18/03 PBTD 6236' 3-1/2" LNR, 9.3#, L-80, .0087 bpf, ID =2.992" 6310' 1466' 1--13-1/2"X NIP, ID = 2.813" GAS LIFT MANDRR S ST MDjVD REV BY IDEV TYPE VLV LATCH PORT AT E 4 1582 1518 3C AMCOM )MRK 0 09/25/03 32577 2502 18 CAMCO D Y RK 0 09/25/03 2 3826 3493 53 CAMCO SO RK 24 09/25/03 1 4229 3727 55 AMCO MY RK 0 09/25/03 4259' -13-1/2" X NIP, ID = 2.813" 4284' 7" BKR S-3 PKR, ID = 3.875" 4310'1 4321' 3-112" X NIP, ID = 2.813" 4327' IBKRZXPLNRHGRPKRW/TIEBACKSLV, RS NIP &CMC WR HGR, ID = 4.25" 4330' 3-1/2" WLEG 4343' ELMD TT IOGG® 05/07/98 5300' -13-1/2"X NIP,ID=2.813" 5625' 3-1/2" X NIP, ID = 2.813" 's6bv' TTPSET09/26/03 572 3 1/2" BKR CIBP (05/13/ 5756'elm-]CEMENTfOP(05/13/03) 5796' 3-1/2" X NIP, ID = 2.813" 5874' 3-1/2" X NIP, ID = 2.813" 5972' 3-1/2" X NIP, ID = 2.813" 6040' I-13-1/2" X NIP, ID = 2.813" DATE REV BY COMMENTS DATE REV BY COMMENTS 01/23/98 ORIGINAL COMPLETION 05/13/03 BJMcN/TL SETIBP/ADD PERFS 03/16/01 SIS -CS FINA L 07/22/03 JCM/KK LV C/O 09/24/01 RN/TP CORRECTIONS 09/25/03 LJ/TLH LV /(C 05/21/02 GCJKAK PERF CORRECTIONS 02/08/05 ATD/TLH TTPSET(09/26/03) 03/18/03 DAV/TLHI SQZ PERFS 04/08/03 RS /TP TVD/MD CORRB;TIONS POLARIS UNIT WB -L: S-200 PERMIT No:1972390 API NW -029-22846-00 SEC35, T12N, T12E, 430' NSL & 4500' WEL BP Exploration (A laska) WELLHEAD= 11" 5M FMC ACTUATOR= KB. ELEV = 62.16' BF. ELEV = KOP = 3T Max Angle = Datum MD = @ __ Dat um TVD = 5000' SS Is PROPOSED 9-5/8" WHIPSTOCK L2734° 9-5/8' CSG, 47#, L-80 B v— :, 14 , ( 9tx k 1—I 2734' Minimum ID = TOP OF CEMENT TOP OF 4-1/2" LNR I-1 4-1/2" TBG, 12.6#, 13CR-85 VAMTOP.,— _0152 bpf, D = 3.958" 7" LNR, 26#, L-80 V AM TOP, _0383 bpf, D = 6.276" 4-112" HES 30' WATER SWELL PACKERS NO DEPTH D J 3-1/2" ANCHOR PKR @ ', ID = 2.992" 1 14529' 1 4-1/2' LNR, 12.6#,13CR,80 HYD521, — 0150 bpf, D = 3.958 4-1/2" LNR, 12.6#, 13CR-85 HYD 521, 0150 bpf, D = 3.958" S -200A S #NOTES: CHROME TBG & LNR X NP, D = 3.813" 1 GAS LIFT MANDRELS ST I MD I TVD I DEV I TYPE I VLV I LATCH I PORT I DATE 4-1/2" HES X NP, D 7" X 4-1/2" HES TNT FKR, D = 3-856- 4-1/2- HES X NP, D = 3-813- 4-1/2- HES X NP, D = 3.813" 7'X5" LTPw/TEBACK SLV, ID=4.30' 7" X 5" HGR , D = 429" X4-1 /2" XO, D = NCS HYD 521 FRAC SLEVES NO DEPTH MN ID O/C DATE i DATE REV BY COMMENTS DATE REV BY COMMENTS 01/23/98 ORIGINAL COMPLETION 1 / SIDETRACK (S -200A) 32/12/16 AU BUILT PROPOSAL POLARIS t1NIT WELL: S-200-` PEFW No: API No: 50-023-22846-0 SEC 35, T12K T12F, 430' NSL & 4500' WEL BP Exploration (Alaska) North America - ALASKA - BP 0 Prudhoe Bay PB S Pad S-200 Plan S -200A v4.0 (S -503A) Plan: S -200A wp08A BP Directional Plan Summary Report ! 31 August, 2017 BER T% " GHES GE company b PB S Pad, TR -12-12 70° 21'23.002 N Site Position: BA, ICER BAT p From: an BP Directional Plan Summary Report Easting: Position Uncertainty: 0.00 usft Slot Radius: Well S-200, SB -01 aUcompany Company: North America - ALASKA - BP Local Co-ordinate Reference: Well S-200 +E/ -W 0.00 usft Project: Prudhoe Bay TVD Reference: S-200A @ 83.05usft (rigx) Vertical Section: Site: PB S Pad MD Reference: S-200A @ 83.05usft (rigx) (usft) Well: S-200 North Reference: True 0.00 Wellbore: Plan S-200A v4.0 (S-503A) Survey Calculation Method: Minimum Curvature Design: S-200A wp08A Database: EDM R5K - Alaska PROD - ANCP1 Project Prudhoe Bay, PBU, PRUDHOE ". ... Map System: Alaska NAD27 State Plane Zones System Datum: Mean Sea Level Geo Datum: NAD27OGP-Usa AK [4267`15864] Using Well Reference Point Map Zone: NAD27 ' OGP Usa AK / Alaska zone 4 [26734`1586, Using geodetic scale factor Site PB S Pad, TR -12-12 70° 21'23.002 N Site Position: Longitude: Northing: From: Map Easting: Position Uncertainty: 0.00 usft Slot Radius: Well S-200, SB -01 149° 2'2.971 W Well Position +N/ -S 0.00 usft Northing: +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore Plan S -200A v4.0 (S -503A) 5,980,854.540 usft Latitude: 70° 21'23.002 N 617,919.920 usft Longitude: 149° 2'32.343 W 0.000 in Grid Convergence: 0.90 ° 5,980,504.880 usft Latitude: 70° 21' 19.407 N 618,930.260 usft Longitude: 149° 2'2.971 W 36.63 usft Ground Level: 36.10 usft . Magnetics Model Name Sample Date Declination Dip Angle Field Strength (nT) BGGM2017 10/9/2017 17.61 80.99 57,496 Design S -200A wp08A Audit Notes: Version: Phase: PLAN Tie On Depth: 2,703.34 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 46.42 0.00 0.00 305.55 8/31/2017 10:29:52AM Page 2 COMPASS 5000.1 Build 81D c: b BP BAA p BP Directional Plan Summary Report UGHES aGEwmpany Company: North America - ALASKA - BP Local Co-ordinate Reference: Well S-200 Project: Prudhoe Bay TVD Reference: S-200A @ 83.05usft (rigx) Site: PB S Pad MD Reference: S-200A @ 83.05usft (rigx) Well: S-200 North Reference: True Wellbore: Plan S-200A v4.0 (S-503A) Survey Calculation Method: Minimum Curvature Design: S-200Awp08A Database: EDM RSK- Alaska PROD -ANCP1 Survey Tool Program Date 8/31/2017 From To (usft) (usft) Survey (Wellbore) Tool Name Description 133.53 2,703.34 Survey #1 MWD (S-200PB1) MWD MWD - Standard 2,703.34 3,400.00 S-200A wp08A (Plan S-200A v4.0 (S-503A GYRO-WD-SS Gyro while drilling single shots 3,400.00 14,532.00 S-200A wp08A (Plan S-200A v4.0 (S-503A MWD MWD - Standard 3,400.00 14,532.00 S-200A wp08A (Plan S-200A v4.0 (S-503A MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 14,532.00 15,739.00 5-200A wp08A (Plan S-200A v4.0 (S-503A MWD MWD - Standard 14,532.00 15,739.08 S-200A wp08A (Plan S-200A v4.0 (S-503A MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal Planned Survey MD Inc Azi (azimuth) TVD TVDSS N/S E/W Northing Easting DLeg TFace (usft) V) (I (usft) (usft) (usft) (usft) (usft) (usft) (°/100usft) V) 2,703.34 21.77 311.79 2,683.94 2,600.89 151.33 -157.37 5,980,653.683 618,770.526 0.00 0.00 TIP 2,734.76 22.49 311.69 2,713.05 2,630.00 159.21 -166.20 5,980,661.421 618,761.570 2.29 -3.04 KOP - KOP (in SV4) - 9 5/8" Surface Casing 2,750.76 22.57 316.91 2,727.83 2,644.78 163.49 -170.58 5,980,665.629 618,757.120 12.50 90.00 Start 20.00 hold at 2750.76 MD 2,770.76 22.57 316.91 2,746.29 2,663.24 169.10 -175.83 5,980,671.151 618,751.786 0.00 0.00 Start DLS 3.00 TFO 18.00 2,800.00 23.41 317.59 2,773.21 2,690.16 177.48 -183.58 5,980,679.413 618,743.903 3.00 18.00 • 2,805.28 23.56 317.71 2,778.05 2,695.00 179.04 -184.99 5,980,680.944 618,742.462 3.00 17.37 SV3 2,900.00 26.29 319.61 2,863.95 2,780.90 209.02 -211.33 5,980,710.506 618,715.655 3.00 17.26 2,957.42 27.95 320.59 2,915.05 2,832.00 229.11 -228.11 5,980,730.319 618,698.557 3.00 15.54 SV2 3,000.00 29.19 321.26 2,952.45 2,869.40 244.92 -240.95 5,980,745.921 618,685.476 3.00 14.66 3,100.00 32.11 322.63 3,038.47 2,955.42 285.06 -272.34 5,980,785.562 618,653.448 3.00 14.08 3,200.00 35.04 323.80 3,121.78 3,038.73 329.36 -305.43 5,980,829.319 618,619.661 3.00 12.90 3,300.00 37.98 324.80 3,202.15 3,119.10 377.67 -340.13 5,980,877.072 618,584.206 3.00 11.93 3,352.44 39.52 325.28 3,243.05 3,160.00 404.57 -358.93 5,980,903.666 618,564.980 3.00 11.12 SV1 8/31/2017 10:29:52AM Page 3 COMPASS 5000.1 Build SID 1000- BP by BAER BP Directional Plan Summary Report UGHES a G'..P , Company: North America - ALASKA - BP Local Co-ordinate Reference: Well S-200 Project: Prudhoe Bay TVD Reference: S -200A @ 83.05usft (rigx) Site: PB S Pad MD Reference: S -200A @ 83.05usft (rigx) Well: S-200 North Reference: True Wellbore: Plan 5-200A v4.0 (S -503A) Survey Calculation Method: Minimum Curvature Design: S -200A wp08A Database: EDM R5K - Alaska PROD - ANCP1 Planned Survey MD Inc Azi (azimuth) TVD TVDSS NIS E/W Northing Easting DLeg TFace (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (°/100usft) (°) 3,400.00 40.92 325.69 3,279.37 3,196.32 429.88 -376.34 5,980,928.691 618,547.180 3.00 10.74 3,500.00 43.88 326.47 3,353.21 3,270.16 485.83 -413.95 5,980,984.034 618,508.685 3.00 10.43 3,600.00 46.83 327.17 3,423.47 3,340.42 545.37 -452.87 5,981,042.950 618,468.826 3.00 9.85 3,700.00 49.80 327.81 3,489.97 3,406.92 608.35 -492.99 5,981,105.277 618,427.713 3.00 9.36 3,800.00 52.76 328.40 3,552.51 3,469.46 674.59 -534.21 5,981,170.844 618,385.458 3.00 8.94 3,841.12 53.98 328.62 3,577.05 3,494.00 702.73 -551.44 5,981,198.707 618,367.777 3.00 8.57 UG4 3,900.00 55.73 328.94 3,610.94 3,527.89 743.90 -576.39 5,981,239.472 618,342.178 3.00 8.43 3,921.68 56.37 329.05 3,623.05 3,540.00 759.31 -585.66 5,981,254.738 618,332.670 3.00 8.25 UG4A 4,000.00 58.70 329.44 3,665.09 3,582.04 816.10 -619.44 5,981,310.972 618,297.990 3.00 8.19 4,100.00 61.67 329.91 3,714.80 3,631.75 890.98 -663.24 5,981,385.148 618,253.017 3.00 7.98 4,200.00 64.64 330.36 3,759.95 3,676.90 968.35 -707.66 5,981,461.798 618,207.380 3.00 7.75 4,300.00 67.62 330.79 3,800.41 3,717.36 1,048.00 -752.58 5,981,540.710 618,161.206 3.00 7.54 4,400.00 70.59 331.19 3,836.07 3,753.02 1,129.69 -797.87 5,981,621.670 618,114.620 3.00 7.37 4,500.00 73.57 331.59 3,866.84 3,783.79 1,213.22 -843.43 5,981,704.454 618,067.751 3.00 7.23 4,515.44 74.03 331.65 3,871.14 3,788.09 1,226.26 -850.47 5,981,717.382 618,060.499 3.00 7.10 Start 100.00 hold at 4515.44 MD 4,600.00 74.03 331.65 3,894.41 3,811.36 1,297.81 -889.08 5,981,788.300 618,020.763 0.00 0.00 4,615.44 74.03 331.65 3,898.66 3,815.61 1,310.87 -896.13 5,981,801.247 618,013.508 0.00 0.00 Start DLS 3.50 TFO -92.18 4,696.60 73.94 328.69 3,921.05 3,838.00 1,378.53 -934.93 5,981,868.284 617,973.643 3.50 -92.181 UG3 4,700.00 73.94 328.57 3,921.99 3,838.94 1,381.33 -936.63 5,981,871.047 617,971.898 3.50 -91.36 4,800.00 73.89 324.93 3,949.71 3,866.66 1,461.66 -989.31 5,981,950.532 617,917.960 3.50 -91.33 4,900.00 73.90 321.28 3,977.46 3,894.41 1,538.48 -1,046.97 5,982,026.421 617,859.086 3.50 -90.32 5,000.00 73.97 317.64 4,005.13 3,922.08 1,611.50 -1,109.42 5,982,098.432 617,795.496 3.50 -89.31 5,100.00 74.11 314.01 4,032.64 3,949.59 1,680.44 -1,176.40 5,982,166.296 617,727.427 3.50 -88.30 8/31/2017 10.29:52AM Page 4 COMPASS 5000.1 Build 81D Company: North America - ALASKA - BP Project: Prudhoe Bay Site: PB S Pad Well: S-200 Wellbore: Plan S -200A v4.0 (5-503A) Design: S -200A wp08A Planned Survey MD Inc TVD Reference: (usft) (°) S -200A @ 83.05usft (rigx) 5,200.00 74.30 Survey Calculation Method: 5,290.95 74.53 EDM R5K - Alaska PROD - ANCP1 Start 8013.17 hold at 5290.95 MD 5,300.00 74.53 -87.30 5,400.00 74.53 1,799.85 -1,316.03 5,500.00 74.53 -86.31 5,600.00 74.53 0.00 5,700.00 74.53 4,083.67 5,800.00 74.53 5,982,459.226 5,900.00 74.53 0.00 6,000.00 74.53 4,110.34 6,100.00 74.53 5,982,516.098 6,200.00 74.53 0.00 6,300.00 74.53 4,137.01 6,400.00 74.53 5,982,572.971 6,500.00 74.53 0.00 6,527.38 74.53 4,163.68 UGI -1,784.34 5,982,629.844 6,600.00 74.53 0.00 6,700.00 74.53 4,190.35 6,800.00 74.53 5,982,686.716 6,900.00 74.53 0.00 7,000.00 74.53 4,217.02 7,100.00 74.53 5,982,743.589 7,200.00 74.53 0.00 7,300.00 74.53 4,243.69 7,400.00 74.53 5,982,800.462 BP BAER BP Directional Plan Summary Report UGHES a GE-pany Local Co-ordinate Reference: Well S-200 TVD Reference: S -200A @ 83.05usft (rigx) MD Reference: S -200A @ 83.05usft (rigx) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM R5K - Alaska PROD - ANCP1 Azi (azimuth) TVD TVDSS N/S ENV Northing Easting DLeg TFace (°) (usft) (usft) (usft) (usft) (usft) (usft) (°/100usft) (°) 310.37 4,059.87 3,976.82 1,745.05 -1,247.69 5,982,229.760 617,655.134 3.50 -87.30 307.08 4,084.30 4,001.25 1,799.85 -1,316.03 5,982,283.463 617,585.938 3.50 -86.31 307.08 4,086.72 4,003.67 1,805.11 -1,322.98 5,982,288.607 617,578.900 0.00 0.00 307.08 4,113.39 4,030.34 1,863.21 -1,399.88 5,982,345.480 617,501.101 0.00 0.00 307.08 4,140.06 4,057.01 1,921.32 -1,476.77 5,982,402.353 617,423.302 0.00 0.00 307.08 4,166.72 4,083.67 1,979.42 -1,553.66 5,982,459.226 617,345.503 0.00 0.00 307.08 4,193.39 4,110.34 2,037.53 -1,630.55 5,982,516.098 617,267.704 0.00 0.00 307.08 4,220.06 4,137.01 2,095.64 -1,707.45 5,982,572.971 617,189.905 0.00 0.00 307.08 4,246.73 4,163.68 2,153.74 -1,784.34 5,982,629.844 617,112.106 0.00 0.00 307.08 4,273.40 4,190.35 2,211.85 -1,861.23 5,982,686.716 617,034.307 0.00 0.00 307.08 4,300.07 4,217.02 2,269.95 -1,938.12 5,982,743.589 616,956.508 0.00 0.00 307.08 4,326.74 4,243.69 2,328.06 -2,015.02 5,982,800.462 616,878.709 0.00 0.00 307.08 4,353.41 4,270.36 2,386.16 -2,091.91 5,982,857.334 616,800.910 0.00 0.00 307.08 4,380.08 4,297.03 2,444.27 -2,168.80 5,982,914.207 616,723.111 0.00 0.00 307.08 4,406.75 4,323.70 2,502.37 -2,245.70 5,982,971.080 616,645.312 0.00 0.00 307.08 4,414.05 4,331.00 2,518.28 -2,266.75 5,982,986.651 616,624.012 0.00 0.00 307.08 4,433.42 4,350.37 2,560.48 -2,322.59 5,983,027.953 616,567.513 0.00 0.00 307.08 4,460.09 4,377.04 2,618.59 -2,399.48 5,983,084.825 616,489.714 0.00 0.00 307.08 4,486.76 4,403.71 2,676.69 -2,476.37 5,983,141.698 616,411.915 0.00 0.00 307.08 4,513.43 4,430.38 2,734.80 -2,553.27 5,983,198.571 616,334.116 0.00 0.00 307.08 4,540.09 4,457.04 2,792.90 -2,630.16 5,983,255.443 616,256.317 0.00 0.00 307.08 4,566.76 4,483.71 2,851.01 -2,707.05 5,983,312.316 616,178.518 0.00 0.00 307.08 4,593.43 4,510.38 2,909.11 -2,783.94 5,983,369.189 616,100.719 0.00 0.00 307.08 4,620.10 4,537.05 2,967.22 -2,860.84 5,983,426.061 616,022.920 0.00 0.00 307.08 4,646.77 4,563.72 3,025.32 -2,937.73 5,983,482.934 615,945.121 0.00 0.00 8/31/2017 10:29:52AM Page 5 COMPASS 5000.1 Build 81D 0 by Company: Project: Site: Well: Wellbore: Design: Planned Survey MD (usft) 7,500.0( 7,600.0( 7,682.2E MA 7,700.0( 7,800.0( 7,900.0( 8,000.0( 8,100.0( 8,195.9E MB 8,200.0( 8,300.0( 8,400.0( 8,500.0( 8,559.6E MC 8,600.0( 8,700.0( 8,773.41 NA 8,800.0( 8,822.1: NB 8,897.1 � NC 8,900.0( BP BP Directional Plan Summary Report North America - ALASKA - BP Prudhoe Bay PB S Pad S-200 Plan S -200A v4.0 (S -503A) S -200A wp08A Inc Northing Azi (azimuth) TVD -3,014.62 TVDSS (°) 5,983,596.680 (°) (usft) -3,168.41 (usft) 74.53 5,983,710.425 307.08 4,673.44 -3,399.09 4,590.39 74.53 5,983,881.043 307.08 4,700.11 -3,552.87 4,617.06 74.53 5,983,994.788 307.08 4,722.05 -3,783.55 4,639.00 74.53 5,984,142.474 307.08 4,726.78 -3,937.34 4,643.73 74.53 5,984,264.027 307.08 4,753.45 -4,031.26 4,670.40 74.53 307.08 4,780.12 4,697.07 74.53 307.08 4,806.79 4,723.74 74.53 307.08 4,833.46 4,750.41 74.53 307.08 4,859.05 4,776.00 74.53 307.08 4,860.13 4,777.08 74.53 307.08 4,886.80 4,803.75 74.53 307.08 4,913.47 4,830.42 74.53 307.08 4,940.13 4,857.08 74.53 307.08 4,956.05 4,873.00 74.53 307.08 4,966.80 4,883.75 74.53 307.08 4,993.47 4,910.42 74.53 307.08 5,013.05 4,930.00 74.53 307.08 5,020.14 4,937.09 74.53 307.08 5,026.05 4,943.00 74.53 307.08 5,046.05 4,963.00 74.53 307.08 5,046.81 4,963.76 NIS (usft) 3,083.43 3,141.54 3,189.34 3,199.64 3,257.75 3,315.85 3,373.96 3,432.06 3,487.82 3,490.17 3,548.27 3,606.38 3,664.48 3,699.16 3,722.59 3,780.70 3,823.35 3,838.80 3,851.67 3,895.25 3,896.91 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: EM Northing (usft) (usft) -3,014.62 5,983,539.807 -3,091.52 5,983,596.680 -3,154.77 5,983,643.466 -3,168.41 5, 983, 653.552 -3,245.30 5,983,710.425 -3,322.19 5,983,767.298 -3,399.09 5,983,824.170 -3,475.98 5,983,881.043 -3,549.77 5,983,935.620 -3,552.87 5,983,937.916 -3,629.76 5,983,994.788 -3,706.66 5,984,051.661 -3,783.55 5,984,108.534 -3,829.44 5,984,142.474 -3,860.44 5,984,165.407 -3,937.34 5,984,222.279 -3,993.78 5,984,264.027 -4,014.23 5,984,279.152 -4,031.26 5,984,291.750 -4,088.93 5,984,334.400 -4,091.12 5,984,336.025 BAKER JUGHES .GEwmp-y Well S-200 S -200A @ 83.05usft (rigx) S -200A @ 83.05usft (rigx) True Minimum Curvature EDM R5K - Alaska PROD - ANCP1 Easting DLeg (usft) (°1100usft) 615,867.322 0.00 615,789.523 0.00 615,725.523 0.00 615,711.724 0.00 615,633.925 0.00 615,556.126 0.00 615,478.327 0.00 615,400.528 0.00 615,325.870 0.00 615,322.729 0.00 615,244.930 0.00 615,167.131 0.00 615,089.332 0.00 615,042.904 0.00 615,011.533 0.00 614,933.734 0.00 614,876.625 0.00 614,855.935 0.00 614,838.702 0.00 614,780.359 0.00 614,778.136 0.00 TFace 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 • 0.00 0.00 0.00 0.00 0.00 0.00 0.00 8/31/2017 10:29:52AM Page 6 COMPASS 5000.1 Build 81D BP BA, ICER by BP Directional Plan Summary Report UGHES a G'..P , Company: North America - ALASKA - BP Local Co-ordinate Reference: Well S-200 Project: Prudhoe Bay TVD Reference: S -200A @ 83.05usft (rigx) Site: PB S Pad MD Reference: S -200A @ 83.05usft (rigx) Well: S-200 North Reference: True Wellbore: Plan S -200A v4.0 (S -503A) Survey Calculation Method: Minimum Curvature Design: S -200A wp08A Database: EDM R5K - Alaska PROD - ANCP1 Planned Survey MD Inc Azi (azimuth) TVD TVDSS NIS EIW Northing Easting DLeg TFace (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (°I100usft) (°) 8,919.64 74.53 307.08 5,052.05 4,969.00 3,908.32 -4,106.22 5,984,347.195 614,762.856 0.00 0.00 NE 9,000.00 74.53 307.08 5,073.48 4,990.43 3,955.01 -4,168.01 5,984,392.897 614,700.337 0.00 0.00 9,020.88 74.53 307.08 5,079.05 4,996.00 3,967.15 -4,184.07 5,984,404.773 614,684.092 0.00 0.00 NF 9,100.00 74.53 307.08 5,100.15 5,017.10 4,013.12 -4,244.91 5,984,449.770 614,622.538 0.00 0.00 9,110.87 74.53 307.08 5,103.05 5,020.00 4,019.44 -4,253.27 5,984,455.954 614,614.080 0.00 0.00 OA 9,200.00 74.53 307.08 5,126.82 5,043.77 4,071.22 -4,321.80 5,984,506.643 614,544.739 0.00 0.00 9,242.11 74.53 307.08 5,138.05 5,055.00 4,095.69 -4,354.18 5,984,530.592 614,511.979 0.00 0.00 OBA 9,300.00 74.53 307.08 5,153.49 5,070.44 4,129.33 -4,398.69 5,984,563.515 614,466.940 0.00 0.00 9,362.10 74.53 307.08 5,170.05 5,087.00 4,165.41 -4,446.44 5,984,598.832 614,418.629 0.00 0.00 OBB 9,400.00 74.53 307.08 5,180.16 5,097.11 4,187.43 -4,475.59 5,984,620.388 614,389.141 0.00 0.00 9,500.00 74.53 307.08 5,206.83 5,123.78 4,245.54 -4,552.48 5,984,677.261 614,311.342 0.00 0.00 9,519.58 74.53 307.08 5,212.05 5,129.00 4,256.92 -4,567.54 5,984,688.398 614,296.108 0.00 0.00 • OBC 9,600.00 74.53 307.08 5,233.50 5,150.45 4,303.65 -4,629.37 5,984,734.134 614,233.543 0.00 0.00 9,677.07 74.53 307.08 5,254.05 5,171.00 4,348.43 -4,688.63 5,984,777.963 614,173.587 0.00 0.00 OBD 9,700.00 74.53 307.08 5,260.17 5,177.12 4,361.75 -4,706.26 5,984,791.006 614,155.744 0.00 0.00 9,800.00 74.53 307.08 5,286.84 5,203.79 4,419.86 -4,783.16 5,984,847.879 614,077.945 0.00 0.00 9,849.55 74.53 307.08 5,300.05 5,217.00 4,448.65 -4,821.26 5,984,876.059 614,039.397 0.00 0.00 OBE 9,900.00 74.53 307.08 5,313.50 5,230.45 4,477.96 -4,860.05 5,984,904.752 614,000.146 0.00 0.00 9,977.04 74.53 307.08 5,334.05 5,251.00 4,522.72 -4,919.28 5,984,948.564 613,940.213 0.00 0.00 OBF 10,000.00 74.53 307.08 5,340.17 5,257.12 4,536.07 -4,936.94 5,984,961.624 613,922.347 0.00 0.00 8/31/2017 10:29:52AM Page 7 COMPASS 5000.1 Build 81D Company: North America - ALASKA - BP Project: Prudhoe Bay Site: PB S Pad Well: S-200 Wellbore: Plan S -200A v4.0 (S -503A) Design: S -200A wp08A Planned Survey MD (usft) 10,100.00 10,134.52 OBF_BASE 10, 200.00 10,300.00 10, 400.00 10, 500.00 10, 600.00 10, 700.00 10, 800.00 10,900.00 11, 000.00 11,100.00 11,200.00 11, 300.00 11,400.00 11,500.00 11,596.88 CM2 11,600.00 11,700.00 11,800.00 11,900.00 12,000.00 12,100.00 12, 200.00 12,300.00 BP BA, KER BP Directional Plan Summary Report JGHES Local Co-ordinate Reference: Well 5-200 TVD Reference: S -200A @ 83.05usft (rigx) MD Reference: S -200A @ 83.05usft (rigx) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM R5K - Alaska PROD - ANCP1 Inc Azi (azimuth) TVD TVDSS NIS ENV Northing Easting DLeg TFace (usft) (usft) (usft) (usft) (usft) (usft) (°/100usft) (°) 74.53 307.08 5,366.84 5,283.79 4,594.17 -5,013.83 5,985,018.497 613,844.548 0.00 0.00 • 74.53 307.08 5,376.05 5,293.00 4,614.23 -5,040.38 5,985,038.130 613,817.692 0.00 0.00 74.53 307.08 5,393.51 5,310.46 4,652.28 -5,090.73 5,985,075.370 613,766.749 0.00 0.00 74.53 307.08 5,420.18 5,337.13 4,710.38 -5,167.62 5,985,132.242 613,688.950 0.00 0.00 74.53 307.08 5,446.85 5,363.80 4,768.49 -5,244.51 5,985,189.115 613,611.151 0.00 0.00 74.53 307.08 5,473.52 5,390.47 4,826.60 -5,321.41 5,985,245.988 613,533.352 0.00 0.00 74.53 307.08 5,500.19 5,417.14 4,884.70 -5,398.30 5,985,302.861 613,455.553 0.00 0.00 74.53 307.08 5,526.86 5,443.81 4,942.81 -5,475.19 5,985,359.733 613,377.754 0.00 0.00 74.53 307.08 5,553.53 5,470.48 5,000.91 -5,552.08 5,985,416.606 613,299.955 0.00 0.00 74.53 307.08 5,580.20 5,497.15 5,059.02 -5,628.98 5,985,473.479 613,222.156 0.00 0.00 74.53 307.08 5,606.87 5,523.82 5,117.12 -5,705.87 5,985,530.351 613,144.357 0.00 0.00 74.53 307.08 5,633.54 5,550.49 5,175.23 -5,782.76 5,985,587.224 613,066.558 0.00 0.00 74.53 307.08 5,660.21 5,577.16 5,233.33 -5,859.65 5,985,644.097 612,988.759 0.00 0.001 74.53 307.08 5,686.88 5,603.83 5,291.44 -5,936.55 5,985,700.969 612,910.960 0.00 0.00 74.53 307.08 5,713.54 5,630.49 5,349.55 -6,013.44 5,985,757.842 612,833.161 0.00 0.00 74.53 307.08 5,740.21 5,657.16 5,407.65 -6,090.33 5,985,814.715 612,755.362 0.00 0.00 74.53 307.08 5,766.05 5,683.00 5,463.94 -6,164.82 5,985,869.811 612,679.994 0.00 0.00 74.53 307.08 5,766.88 5,683.83 5,465.76 -6,167.23 5,985,871.588 612,677.563 0.00 0.00 74.53 307.08 5,793.55 5,710.50 5,523.86 -6,244.12 5,985,928.460 612,599.764 0.00 0.001 74.53 307.08 5,820.22 5,737.17 5,581.97 -6,321.01 5,985,985.333 612,521.965 0.00 0.00 74.53 307.08 5,846.89 5,763.84 5,640.07 -6,397.90 5,986,042.206 612,444.166 0.00 0.00 74.53 307.08 5,873.56 5,790.51 5,698.18 -6,474.80 5,986,099.078 612,366.367 0.00 0.00 74.53 307.08 5,900.23 5,817.18 5,756.28 -6,551.69 5,986,155.951 612,288.568 0.00 0.00 74.53 307.08 5,926.90 5,843.85 5,814.39 -6,628.58 5,986,212.824 612,210.769 0.00 0.00 74.53 307.08 5,953.57 5,870.52 5,872.49 -6,705.47 5,986,269.696 612,132.970 0.00 0.00 813112017 10.29:52AM Page 8 COMPASS 5000.1 Build 81D 0b BP BAER P BP Directional Plan Summary Report UGHES a GEwmpany Company: North America - ALASKA - BP Project: Prudhoe Bay Site: PB S Pad Well: S-200 Wellbore: Plan S -200A v4.0 (S -503A) Design: S -200A wp08A Planned Survey MD Inc (usft) (°) 12,400.00 74.53 12,500.00 74.53 12,600.00 74.53 12,700.00 74.53 12,800.00 74.53 12,900.00 74.53 13,000.00 74.53 13,100.00 74.53 13,200.00 74.53 13,300.00 74.53 13,304.13 74.53 Start DLS 3.50 TFO -136.18 13,356.98 73.20 CM-11TLBK 6,060.25 13,400.00 72.13 13,500.00 69.65 13,600.00 67.21 13,700.00 64.82 13,800.00 62.48 13,900.00 60.21 14,000.00 58.01 14,087.10 56.16 THRZ 6,140.25 14,100.00 55.90 14,200.00 53.87 14,300.00 51.96 14,400.00 50.16 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Azi (azimuth) TVD TVDSS N/S E/W Northing (°) (usft) (usft) (usft) (usft) (usft) 307.08 5,980.24 5,897.19 5,930.60 -6,782.37 5,986,326.569 307.08 6,006.91 5,923.86 5,988.71 -6,859.26 5,986,383.442 307.08 6,033.58 5,950.53 6,046.81 -6,936.15 5,986,440.315 307.08 6,060.25 5,977.20 6,104.92 -7,013.05 5,986,497A 87 307.08 6,086.92 6,003.87 6,163.02 -7,089.94 5,986,554.060 307.08 6,113.58 6,030.53 6,221.13 -7,166.83 5,986,610.933 307.08 6,140.25 6,057.20 6,279.23 -7,243.72 5,986,667.805 307.08 6,166.92 6,083.87 6,337.34 -7,320.62 5,986,724.678 307.08 6,193.59 6,110.54 6,395.44 -7,397.51 5,986,781.551 307.08 6,220.26 6,137.21 6,453.55 -7,474.40 5,986,838.423 307.08 6,221.36 6,138.31 6,455.95 -7,477.58 5,986,840.770 305.74 6,236.05 6,153.00 6,486.09 -7,518.44 5,986,870.253 304.64 6,248.87 6,165.82 6,509.75 -7,551.99 5,986,893.378 302.02 6,281.61 6,198.56 6,561.67 -7,630.92 5,986,944.032 299.32 6,318.38 6,235.33 6,609.11 -7,710.88 5,986,990.195 296.52 6,359.04 6,275.99 6,651.90 -7,791.59 5,987,031.694 293.61 6,403.42 6,320.37 6,689.87 -7,872.73 5,987,068.374 290.58 6,451.38 6,368.33 6,722.90 -7,954.02 5,987,100.099 287.40 6,502.72 6,419.67 6,750.84 -8,035.13 5,987,126.749 284.52 6,550.05 6,467.00 6,770.96 -8,105.42 5,987,145.750 284.08 6,557.26 6,474.21 6,773.60 -8,115.78 5,987,148.226 280.59 6,614.79 6,531.74 6,791.10 -8,195.66 5,987,164.449 276.91 6,675.10 6,592.05 6,803.26 -8,274.48 5,987,175.359 273.05 6,737.96 6,654.91 6,810.04 -8,351.93 5,987,180.913 Well S-200 S -200A @ 83.05usft (rigx) S -200A @ 83.05usft (rigx) True Minimum Curvature EDM R5K - Alaska PROD - ANCP1 Easting (usft) 612, 055.171 611,977.372 611,899.573 611,821.774 611,743.975 611,666.176 611 , 588.377 611,510.578 611,432.779 611,354.980 611,351.770 611,310.438 611,276.513 611,196.782 611,116.082 611,034.714 610,952.983 610, 871.193 610,789.649 610, 719.059 610,708.655 610,628.514 610, 549.524 610,471.981 DI -eq (°/100usft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 TFace 1°I 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 'iKL-s1. -135.81 -135.48 -134.62 -133.63 -132.49 -131.20 -129.74 -128.11 -126.54 -126.30 -124.29 -122.08 8/31/2017 10:29:52AM Page 9 COMPASS 5000.1 Build 81D by Company: North America - ALASKA - BP Local Co-ordinate Reference: Project: Prudhoe Bay Site: PB S Pad Well: S-200 Wellbore: Plan S -200A v4.0 (S -503A) TVD Reference: Design: S -200A wp08A S -200A @ 83.05usft (rigx) Planned Survey MD Inc Azi (azimuth) (usft) 1°) 1°I 14,409.27 50.00 272.68 Start 120.00 hold at 14409.27 MD 14,500.00 50.00 272.68 14,529.00 50.00 272.68 7" Production Casing North Reference: 14,529.27 50.00 272.68 Start 20.00 hold at 14529.27 MD - TKUD - TKC4 14,532.38 ✓ 50.00 272.68 7 " intermed casing 14,549.27 50.00 272.68 Start DLS 12.10 TFO 354.00 Minimum Curvature 14,562.15 51.55 272.47 TKLB-TKC3D 14,595.84 55.61 271.97 TKC3C 14,600.00 56.11 271.91 14,665.49 64.00 271.06 TKC3B N/S 14,700.00 68.16 270.66 14,787.98 78.76 269.73 TKC3A 14,800.00 80.21 269.61 14,811.43 81.59 269.50 TKC3A (usft) (°/100usft) 14,900.00 92.28 268.63 15,000.00 104.34 267.64 15,022.10 107.00 267.41 Start 120.00 hold at 15022.10 MD 610,464.874 BP BAER BP Directional Plan Summary Report UGHES aGEcompany 8/31/2017 10:29:52AM Page 10 COMPASS 5000.1 Build 81D Local Co-ordinate Reference: Well S-200 TVD Reference: S -200A @ 83.05usft (rigx) MD Reference: S -200A @ 83.05usft (rigx) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM R5K - Alaska PROD - ANCP1 TVD TVDSS N/S ENV Northing Easting DLeg TFace (usft) (usft) (usft) (usft) (usft) (usft) (°/100usft) (°) 6,743.92 6,660.87 6,810.40 -8,359.03 5,987,181.156 610,464.874 3.50 -119.65 • 6,802.23 6,719.18 6,813.65 -8,428.46 5,987,183.306 610,395.412 0.00 0.00 6,820.87 6,737.82 6,814.69 -8,450.65 5,987,183.994 610,373.209 0.00 0.00 6,821.05 6,738.00 6,814.70 -8,450.85 5,987,184.000 610,373.000 0.00 0.00 6,823.05 6,740.00 6,814.81 -8,453.24 5,987,184.074 610,370.618 0.00 0.00 6,833.91 6,750.86 6,815.42 -8,466.16 5,987,184.474 610,357.688 0.00 0.00 6,842.05 6,759.00 6,815.87 -8,476.13 5,987,184.764 610,347.716 12.10 -6.00 6,862.05 6,779.00 6,816.92 -8,503.21 5,987,185.382 610,320.620 12.10 -5.87 6,864.38 6,781.33 6,817.03 -8,506.65 5,987,185.444 610,317.182 12.10 -5.57 6,897.05 6,814.00 6,818.49 -8,563.33 5,987,185.999 610,260.489 12.10 -5.54 6,911.04 6,827.99 6,818.96 -8,594.86 5,987,185.971 610,228.953 12.10 -5.11 6,936.05 6,853.00 6,819.23 -8,679.08 5,987,184.906 610,144.753 12.10 -4.95 6,938.24 6,855.19 6,819.17 -8,690.90 5,987,184.650 610,132.934 12.10 -4.68 6,940.05 6,857.00 6,819.08 -8,702.18 5,987,184.384 610,121.654 12.10 -4.66 6,944.78 6,861.73 6,817.63 -8,790.49 5,987,181.540 610,033.391 12.10 -4.64 6,930.36 6,847.31 6,814.44 -8,889.20 5,987,176.777 609,934.747 12.10 -4.60 6,924.39 6,841.34 6,813.52 -8,910.46 5,987,175.522 609,913.514 12.10 -4.74 8/31/2017 10:29:52AM Page 10 COMPASS 5000.1 Build 81D BP BA. JCER by BP Directional Plan Summary Report UGHES a GE tympany Company: North America - ALASKA - BP Local Co-ordinate Reference: Well S-200 Project: Prudhoe Bay TVD Reference: S -200A @ 83.05usft (rigx) Site: PB S Pad MD Reference: S -200A @ 83.05usft (rigx) Well: S-200 North Reference: True Wellbore: Plan S -200A v4.0 (S -503A) Survey Calculation Method: Minimum Curvature Design: S-200Awp08A Database: EDM RSK- Alaska PROD -ANCP1 Planned Survey MD Inc Azi (azimuth) TVD TVDSS NIS ENV Northing Easting DLeg TFace (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (°I100usft) (°) 15,078.00 107.00 267.41 6,908.05 6,825.00 6,811.11 -8,963.86 5,987,172.259 609,860.156 0.00 0.00 TKC3B 15,100.00 107.00 267.41 6,901.62 6,818.57 6,810.15 -8,984.88 5,987,170.975 609,839.158 0.00 0.00 15,142.10 107.00 267.41 6,889.31 6,806.26 6,808.34 -9,025.10 5,987,168.518 609,798.981 0.00 0.00 Start DLS 8.00 TFO 140.94 15,196.08 103.63 270.21 6,875.05 6,792.00 6,807.26 -9,077.14 5,987,166.621 609,746.965 8.00 140.941 TKC3C 15,200.00 103.38 270.41 6,874.14 6,791.09 6,807.29 -9,080.95 5,987,166.581 609,743.154 8.00 141.68 15,300.00 97.06 275.39 6,856.39 6,773.34 6,812.30 -9,179.15 5,987,170.041 609,644.893 8.00 141.72 15,320.96 95.73 276.42 6,854.05 6,771.00 6,814.45 -9,199.87 5,987,171.854 609,624.145 8.00 142.61 TKC3D 15,344.78 94.21 277.57 6,851.99 6,768.94 6,817.34 -9,223.43 5,987,174.370 609,600.548 8.00 142.72 Start 394.30 hold at 15344.78 MD 15,400.00 94.21 277.57 6,847.94 6,764.89 6,824.60 -9,278.01 5,987,180.760 609,545.857 0.00 0.001 15,500.00 94.21 277.57 6,840.60 6,757.55 6,837.74 -9,376.87 5,987,192.332 609,446.809 0.00 0.00 15,600.00 94.21 277.57 6,833.26 6,750.21 6,850.88 -9,475.73 5,987,203.905 609,347.761 0.00 0.00 15,700.00 94.21 277.57 6,825.92 6,742.87 6,864.03 -9,574.60 5,987,215.477 609,248.713 0.00 0.00 15,739.08 94.21 277.57 6,823.05 6,740.00 6,869.17 -9,613.23 5,987,219.999 609,210.005 0.00 0.00 TD at 15739.08 - 4 112' Production Liner Casing Points e Measured Vertical Casing Hole ; Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 14,529.00 6,820.87 7" Production Casing 7.000 8.500 15,739.08 6,823.05 4 1/2" Production Liner 4.500 6.125 2,734.76 2,713.05 9 5/8" Surface Casing 9.625 12.250 8/31/2017 10:29:52AM Page 11 COMPASS 5000.1 Build 81D Company: Project: Site: Well: Wellbore: Design: Formations North America - ALASKA - BP Prudhoe Bay PB S Pad S-200 Plan S -200A v4.0 (S -503A) S -200A wp08A Measured Vertical Depth Depth (usft) (usft) Name 14,529.27 6,821.05 TKC4 11,596.88 5,766.05 CM2 15,196.08 6,875.05 TKC3C 9,977.04 5,334.05 OBF 7,682.26 4,722.05 MA 9,362.10 5,170.05 OBB 10,134.52 5,376.05 OBF_BASE 15,078.00 6,908.05 TKC3B 9,242.11 5,138.05 OBA 9,020.88 5,079.05 NF 14,595.84 6,862.05 TKC3C 9,677.07 5,254.05 OBD 3,921.68 3,623.05 UG4A 15,320.96 6,854.05 TKC3D 4,696.60 3,921.05 UG3 8,559.68 4,956.05 MC 8,897.14 5,046.05 NC 2,494.15 2,485.05 SV4 8,822.15 5,026.05 NB 9,110.87 5,103.05 OA 9,849.55 5,300.05 OBE 14,811.43 6,940.05 TKC3A 14,665.49 6,897.05 TKC3B 2,805.28 2,778.05 SV3 13,356.98 6,236.05 CM-1/TLBK 14,529.27 6,821.05 TKUD 14,562.15 6,842.05 TKC3D 2,957.42 2,915.05 SV2 3,352.44 3,243.05 SV1 3,841.12 3,577.05 UG4 8,919.64 5,052.05 NE 14,532.38 6,823.05 7" intermed casing BP BP Directional Plan Summary Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Dip Dip Direction Lithology (1 (`) 0.00 0.00 0.00 Well S-200 S -200A @ 83.05usft (rigx) S -200A @ 83.05usft (rigx) True Minimum Curvature EDM R5K - Alaska PROD - ANCP1 BAKER gUGHES aGE—pny 8/31/2017 10:29:52AM Page 12 COMPASS 5000.1 Build 81D s 8/31/2017 10:29:52AM Page 13 COMPASS 5000.1 Build 81D BP 0b P BP Directional Plan Summary Report BAER UGHES a GE company Company: North America - ALASKA - BP Local Co-ordinate Reference: Well S-200 Project: Prudhoe Bay TVD Reference: S -200A @ 83.05usft (rigx) Site: PB S Pad MD Reference: S -200A @ 83.05usft (rigx) Well: S-200 North Reference: True Wellbore: Plan S -200A v4.0 (S -503A) Survey Calculation Method: Minimum Curvature Design: S -200A wp08A Database: EDM R5K - Alaska PROD - ANCP1 8,773.41 5,013.05 NA 9,519.58 5,212.05 OBC 14,562.15 6,842.05 TKLB 2,734.76 2,713.05 KOP (in SV4) 14,787.98 6,936.05 TKC3A 14,087.10 6,550.05 THRZ • 6,527.38 4,414.05 UG1 8,195.96 4,859.05 MB Plan Annotations Measured Vertical Local Coordinates Depth Depth +NI -S +E/ -W (usft) (usft) (usft) (usft) Comment 2,703.34 2,683.94 151.33 -157.37 TIP 2,734.76 2,713.05 159.21 -166.20 KOP 2,750.76 2,727.83 163.49 -170.58 Start 20.00 hold at 2750.76 MD 2,770.76 2,746.29 169.10 -175.83 Start DLS 3.00 TFO 18.00 4,515.44 3,871.14 1,226.26 -850.47 Start 100.00 hold at 4515.44 MD 4,615.44 3,898.66 1,310.87 -896.13 Start DLS 3.50 TFO -92.18 5,290.95 4,084.30 1,799.85 -1,316.03 Start 8013.17 hold at 5290.95 MD 13,304.13 6,221.36 6,455.95 -7,477.58 Start DLS 3.50 TFO -136.18 14,409.27 6,743.92 6,810.40 -8,359.03 Start 120.00 hold at 14409.27 MD 14,529.27 6,821.05 6,814.70 -8,450.85 Start 20.00 hold at 14529.27 MD • 14,549.27 6,833.91 6,815.42 -8,466.16 Start DLS 12.10 TFO 354.00 15,022.10 6,924.39 6,813.52 -8,910.46 Start 120.00 hold at 15022.10 MD 15,142.10 6,889.31 6,808.34 -9,025.10 Start DLS 8.00 TFO 140.94 15,344.78 6,851.99 6,817.34 -9,223.43 Start 394.30 hold at 15344.78 MD 15,739.08 6,823.05 6,869.17 -9,613.23 TD at 15739.08 8/31/2017 10:29:52AM Page 13 COMPASS 5000.1 Build 81D • • North America - ALASKA - BP Prudhoe Bay PB S Pad S-200 Plan S -200A v4.0 (S -503A) S -200A wp08A Anticollision Summary Report 31 August, 2017 4UGHES a GE company Company: North America - ALASKA - BP Project: Prudhoe Bay Reference Site: PB S Pad Site Error: 0.00usft Reference Well: S-200 Well Error: 0.00usft Reference Wellbore Plan 5-200A v4.0 (S -503A) Reference Design: S -200A wp08A 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 S-200 S -200A @ 83.05usft (rigx) S -200A @ 83.05usft (rigx) True Minimum Curvature 1.00 sigma EDM R5K- Alaska PROD - ANCP1 Offset Datum BATER UGHES a GE company Reference S -200A wp08A Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria WARNING: There is hidden tight data in this project Interpolation Method: MD Interval 25,00usft Error Model: ISCWSA Depth Range: 2,700.00 to 15,739.08usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,769.27usft Error Surface: Elliptical Conic Survey Tool Program Date 8/31/2017 From To (usft) (usft) Survey (Wellbore) Tool Name Description 133.53 2,703.34 Survey #1 MWD (S-200PB1) MWD MWD - Standard 2,703.34 3,400.00 S -200A wp08A (Plan S -200A v4.0 (S -503A GYRO -WD -SS Gyro while drilling single shots 3,400.00 14,532.00 S -200A wp08A (Plan S -200A v4.0 (S -503A MWD MWD - Standard 3,400.00 14,532.00 S -200A wp08A (Plan S -200A v4.0 (S -503A MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 14,532.00 15,739.00 S -200A wp08A (Plan 5-200A v4.0 (S -503A MWD MWD - Standard 14,532.00 15,739.08 5-200Awp08A (Plan 5-200A v4.0 (S -503A MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 813112017 10:44:46AM Page 2 of 5 COMPASS 5000.1 Build 81D BP BAKER by Anticollision Report JUGHES 0a GE company Company: North America - ALASKA - BP Local Co-ordinate Reference: Well S-200 Project: Prudhoe Bay ND Reference: 5-200A @ 83.05usft (rigx) Reference Site: PB S Pad MD Reference: S -200A @ 83.05usft (rigx) Site Error: 0.00usft North Reference: True Reference Well: 5-200 Survey Calculation Method: Minimum Curvature Well Error: 0,00usft Output errors are at 1.00 sigma Reference Wellbore Plan S -200A v4.0 (5-503A) Database: EDM R5K - Alaska PROD - ANCP1 Reference Design: S -200A wp08A Offset ND Reference: Offset Datum Summary Site Name Offset Well - Wellbore - Design PB S Pad Plan S-136 - Plan S-136 - Plan #7 5-136 5-100 - S-100 - 5-100 S-101 - S-101 - 5-101 S-101 - S-101 PB1 - S-101 PB1 S-102 - 5-102 - S-102 S-102 - S-10211 - 5-102L1 S-102 - S-1021_1 PB1 - S -102L1 PB1 S-102 - S-102PB1 - S-102PB1 S-103 - S-103 - S-103 5-105 - S-105 - S-105 S-106 - S-106 - 5-106 S-107 - S-107 - S-107 Reference Measured Depth (usft) 15,738.76 8,270.98 2,707.17 2,707.17 8,201.84 8,201.84 8,201.84 8,201.84 5,452.65 2,702.51 13,489.89 10,389.60 Offset Measured Depth (usft) 14,775.00 7,350.00 2,750.00 2,750.00 7,525.00 7,525.00 7,525.00 7,525.00 4,975.00 2,650.00 12,225.00 9,325.00 Centre to Centre Distance (usft) 0.01 942.39 708.62 708.62 941.86 941.86 941.86 941.86 424.72 719.51 1,485.03 102.14 No -Go Distance (usft) 0.31 462.77 57.84 57.83 457.03 455.93 455.93 457.59 199.68 47.21 734.73 80.39 Allowable Deviation from Plan (usft) 0.01 480.00 666.37 666.37 552.88 553.83 553.83 552.32 246.02 678.89 1,060.92 45.73 Warning Pass - NOERRORS Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass -Minor 1/200 S-108 - 5-108 - S-108 2,703.01 2,725.00 233.01 37.84 196.64 Pass - Major Risk 5-109 - S-109 - S-109 2,700.00 3,200.00 1,182.62 47.87 1,143.55 Pass - Major Risk S-109 - 5-109PB1 - S-109PB1 2,700.00 3,200.00 1,182.62 47.87 1,143.55 Pass - Major Risk 5-110 - S-110 - S-110 Out of range S-110 - S-11 OA - S -110A Out of range S-110 - S -110B - S-1106 Out of range S-111 - S-111 - S-111 2,717.20 2,700.00 1,061.78 53.70 1,020.73 Pass - Major Risk S-111 - S-111 PB1 - S-111 PBI 2,717.20 2,700.00 1,061.78 53.70 1,020.73 Pass - Major Risk S-111 - S-111 PB2 - S-111 PB2 2,717.20 2,700.00 1,061.78 53.70 1,020.73 Pass - Major Risk S-112 - S-112 - S-112 2,700.00 2,900.00 565.89 41.23 530.32 Pass - Major Risk S-112 - 5-1121_1 - S-1121_1 2,700.00 2,900.00 565.89 41.29 530.32 Pass - Major Risk S-112 - S-1121-1 PB1 - S -112L1 PBI 2,700.00 2,900.00 565.89 41.29 530.32 Pass - Major Risk S-112 - S -112L1 PB2 - S -112L1 PB2 2,700.00 2,900.00 565.89 41.29 530.32 Pass - Major Risk S-113 - 5-113 - 5-113 2,719.20 2,750.00 1,145.75 59.21 1,105.73 Pass - Major Risk S-113 - S-11 3A - S-11 3A 2,719.20 2,750.00 1,145.75 59.21 1,105.73 Pass - Major Risk S-113 - S -113B - S -113B 2,719.20 2,750.00 1,145.75 59.21 1,105.73 Pass - Major Risk 5-113 - S-113BL1 - S-113BL1 2,719.20 2,750.00 1,145.75 59.75 1,105.70 Pass - Major Risk S-115 - S-115 - S-115 2,711.67 2,675.00 663.15 48.42 625.76 Pass - Major Risk S-116 - S-116 - S-116 2,704.26 3,175.00 1,195.79 49.00 1,151.84 Pass - Major Risk S-116 - S -116A - S -116A 2,704.26 3,175.00 1,195.79 49.40 1,151.86 Pass - Major Risk S-116 - S-116APB1 - S-116APB1 2,704.26 3,175.00 1,195.79 49.40 1,151.86 Pass - Major Risk S-116 - S-116APB2 - S-116APB2 2,704.26 3,175.00 1,195.79 49.40 1,151.86 Pass - Major Risk S-117 - S-117 - S-117 2,709.20 2,725.00 454.09 45.89 411.60 Pass - Major Risk 5-118 - S-118 - S-118 2,709.94 3,050.00 973.30 43.38 932.59 Pass - Major Risk S-119 - S-119 - S-119 12,542.90 11,300.00 1,573.79 702.25 1,056.42 Pass - Major Risk S-120 - 5-120 - S-120 2,714.26 2,725.00 988.75 57.16 948.83 Pass - Major Risk S-121 - 5-121 - S-121 2,713.02 3,200.00 1,169.97 48.21 1,123.68 Pass - Major Risk S-121-S-121PB1 -S-121PBI 2,713.02 3,200.00 1,169.97 48.21 1,123.68 Pass - Major Risk S-122 - S-122 - S-122 2,711.58 2,675.00 368.92 45.47 332.91 Pass - Major Risk S-122 - S-122PB1 - S-122PB1 2,711.58 2,675.00 368.92 45.47 332.91 Pass - Major Risk S-122 - S-122PB2 - S-122PB2 2,711.58 2,675.00 368.92 45.47 332.91 Pass - Major Risk S-122 - S-122PB3 - S-122PB3 2,711.58 2,675.00 368.92 45.47 332.91 Pass - Major Risk S-125 - S-125 - 5-125 2,700.03 2,900.00 1,113.71 54.83 1,070.69 Pass - Major Risk S-125 - S-125PB1 - 5-125PB1 2,700.03 2,900.00 1,113.71 54.83 1,070.69 Pass - Major Risk S-13 - S -1 3A - S-1 3A Out of range S-200 - S-200 - S-200 3,015.48 3,000.00 19.62 0.40 19.62 Pass - NOERRORS S-200 - S-200PB1 - S-200PB1 3,015.48 3,000.00 19.62 0.40 19.62 Pass - NOERRORS S-201 - S-201 - S-201 2,716.26 2,650.00 556.34 49.43 514.84 Pass - Major Risk S-201 - 5-201 PB1 - S-201 PB1 2,716.26 2,650.00 556.34 49.43 514.84 Pass - Major Risk S-213 - S-213 - S-213 2,711.05 2,750.00 195.06 38.68 157.72 Pass - Major Risk S-213 - S -213A - S -213A 2,714.41 2,749.91 196.74 38.75 159.31 Pass - Major Risk 813112017 1 0:44 46AM Page 3 of 5 COMPASS 5000.1 Build 81D BP • BAER Anticollision Report UGHES a GEmmpany Company: North America - ALASKA- BP Local Co-ordinate Reference: Well S-200 Project: Prudhoe Bay TVD Reference: S -200A @ 83.05usft (rigx) Reference Site: PB S Pad MD Reference: S -200A @ 83.05usft (rigx) Site Error: 0.00usft North Reference: True Reference Well: S-200 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore Plan S -200A v4.0 (5-503A) Database: EDM R5K - Alaska PROD - ANCP1 Reference Design: S -200A wp08A Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) PB S Pad S-213 - S-213ALl - S-213ALl 2,714.41 2,749.91 196.74 38.75 159.31 Pass - Major Risk S-213 - S-213ALl-01 - S-213ALI-01 2,714.41 2,749.91 196.74 38.75 159.31 Pass - Major Risk S-213 - S-213AL2 - S-213AL2 2,714.41 2,749.91 196.74 38.75 159.30 Pass - Major Risk S-213 - 5-213AL3 - S-213AL3 2,714.41 2,749.91 196.74 38.75 159.31 Pass - Major Risk S-216 - S-216 - S-216 Out of range S-400 - S-400 - S-400 2,703.41 3,100.00 1,421.19 49.25 1,377.99 Pass - Major Risk S -400 -5 -400A -S -400A 2,711.24 3,100.00 1,412.78 90.47 1,350.17 Pass - Major Risk 5-401 - S-401 - S-401 7,361.82 6,566.00 752.37 301.29 550.81 Pass - Major Risk 5-401 - S-401 PB1 - S-401 P61 7,351.98 6,490.00 952.25 317.21 709.26 Pass - Major Risk S-41 - 5-41 - S-41 2,700.00 3,050.00 877.14 65.41 826.40 Pass - Major Risk S-41 - S -41A - S -41A 2,702.55 3,050.00 881.77 66.56 830.74 Pass - Major Risk S-41 - S-41ALl - S-41ALl 2,702.55 3,050.00 881.77 66.56 830.74 Pass - Major Risk 5-41 - 5-41 L1 - S-41 L1 2,700.00 3,050.00 877.14 65.42 826.40 Pass - Major Risk 5-41 - S-41 PBI - 5-41 PB1 2,700.00 3,050.00 877.14 65.41 826.40 Pass - Major Risk S-42 - S-42 - S-42 2,715.73 2,800.00 328.17 36.63 294.97 Pass - Major Risk S-42 - S -42A - S -42A 2,706.80 2,800.00 324.27 36.55 291.16 Pass - Major Risk S-42 - S-42PB1 - S-42PBI 2,715.73 2,800.00 328.17 36.63 294.97 Pass - Major Risk S-43 - S-43 - S-43 2,714.90 2,950.00 614.43 49.74 575.58 Pass - Major Risk S-43 - S -43L1 - S-431_1 2,714.90 2,950.00 614.43 49.74 575.58 Pass - Major Risk S-44 - S-44 - S-44 2,708.64 2,775.00 280.09 37.37 247.22 Pass - Major Risk S-44 - S -44A - S -44A 2,700.00 2,775.00 267.43 37.30 234.79 Pass - Major Risk S-44 - S-441_1 - 5-441_1 2,708.64 2,775.00 280.09 37.37 247.22 Pass - Major Risk S-44 - S-441_1 PB1 - S-44LI PB1 2,708.64 2,775.00 280.09 37.37 247.22 Pass - Major Risk 8/31/2017 10:44:46AM Page 4 of 5 COMPASS 5000.1 Build 81D 0 Company: North America - ALASKA - BP Project: Prudhoe Bay Reference Site: PB S Pad Site Error: 0.00usft Reference Well: S-200 Well Error: 0.00usft Reference Wellbore Plan S -200A v4.0 (S -503A) Reference Design: S -200A wp08A BP Anticollision Report Local Coordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: • Well S-200 S -200A @ 83.05usft (rigx) S -200A @ 83.05usft (rigx) True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum BA ER Ty 'HES Ty Ucompany reference Depths are relative to S -200A @ 83.05usft (rigx) Coordinates are relative to: S-200 )ffset Depths are relative to Offset Datum Coordinate System is Alaska NAD27 State Plane Zones, NAD27 ' OGP-Usa AK ventral Meridian is 150° 0'0.000 W ° Grid Convergence at Surface is: 0.91' a(31/2017 10:44:46AM Page 5 of 5 COMPASS 5000.1 Build 81D Ladder Plot 1800 1_ LA C I I I `IT I I (:n3 1350- , I L I ------- - I - C) q I C O_ -- _ _ J_ __ _ _ J.. _I_ _J___ _ _ _ _ _ _J_ _ _I_ _ _ _ _ _ _ t/ - M Q U) 900 -__--__--__ - �.. N I i I I I I I I I ".-_ _ _ _I_ ___ _ _I_ ___ _- I I I I LD m 450 __ -- - `.l -- U ^ .LEGE I I`„! I J- - - - - -' - - -- - - -\.- ...� - - - - - - - - - - - - - - - _ S- 0,S-108�S-10V I �- S -42,S \ �- S-116AP61,S-116P1P61 - - -- VO $ S 07,S-107,IS-10iV36I I S 200,51 -�(�- 200PB1,S-200PB1 I - - S -116,S-11 $-116V6 '$U - �f SOH O, S-1108, S-11 o§ -ft(-43,S-431-11 , S-%bd0 12009- S-116, S-11 ��&616A VO 18000 �- S-110, S -110A, S -110A VO S �, -4 -*R-a �ec3�L pth (3000 us�n) $ S-120, S-120, S-120 V4 '-t- S-100, S-100, S-100 V10 S-44, S-441-1, S-441- VO S-118, S-118, S-118 V5 $ S -101,S -101,S-101 V5 S- 4,S-44A,S-44AVO $ S-113,S-113B,S-113BV6 $ S-102,S-1021-1PB1,S-1021-1PB1V11 S-44, S-44, S-44 V1 0 -tom S -113,S -113,S -113V14 �f S-1 02, S-1 021-1, S-1 021-1 V5 S-1 25, S-1 25PB1, S-1 25PB1 V7 $ S-113,S-113BL1,S-113BL1 VO $ S-102,S-102PB1,S-102PB1V14 $ S-125,S-125,S-125Vll $ S -112,S -112,S -112V20 $ S-102, S-102, S-102 Vll $ S-400, S-400, 5-400 V4 S-112, S-1121-1, S -112L1 VO $ S -105,S -105,S -105V6 $ S-400,S-400A,S-400AV6 $ S-112,S-112L1PB2,S-112L1PB2V0 $ S-1 03, S-1 03, S-1 03 V6 - S -121,S -121,S-121 V8 S-112,S-112L1PB1,S-112L1PB1 VO $ S-201, S-201, S-201 V4 S-121,S-121PB1,S-121PB1 V4 $ S -115,S -115,S -115V7 - - S-201, S-201 PB1, S-201 PB1 V11 - S -401,S -401,S-401 V4 $ S -109,S -109,S -109V9 a(31/2017 10:44:46AM Page 5 of 5 COMPASS 5000.1 Build 81D Project: Prudhoe Bay Obp Site: PBS PadWell: 5.200 Wellbore: Plan 5-2004 v4.0 (55034) Plan: S-20OA wpO8A (S-200/Plan S -200A v4.D (S -603A)) WELL DETAILS: S-200 Ground Level'. 36.10 NI -S *E/ -W Norming Easang Latitwde 1--gaude Slot 000 0.00 5980504.880 618930260 70°2119.407N 149.2'2971W SECTION DETAILS Sao MD Inc Azi TVD +PD -S +E/ -W Dlag TF" VSed Target 1 2703.34 21.77 311.79 2683.94 151.33 -157.37 0.00 0.00 216,02 2 2734.76 2249 311.69 271305 159.21 -16620 2.29 3.04 227.79 3 2750.76 22.57 316.91 2727.83 163.49 -170.58 12.50 90.00 233.84 4 2770.76 2257 316.91 2746.29 169.10 -175.83 0.00 0.00 241.37 5 4515.44 74.03 331.65 3871.14 1226.26 350.47 3.00 18.00 1404.90 6 4615.44 74.03 331.65 3898.66 1310.87 -896,13 0.00 000 1491.23 7 5290.95 74.53 307.08 4084.30 1799.85 -1316.03 3.50 92.18 2117.16 8 13304.13 74.53 307.08 6221.36 6455.95 -7477.58 0.00 0.00 9837.36 9 14409.27 50.00 27268 6743.92 681040 -83x`8.03 3.50 -136.1810760.61 10 14529.27 00.00 27268 6821.05 6814.70 9450.85 0.00 00010837.82 S-2JOA lin Csg 11 14549.27 50.00 272.68 6833.91 6815.42 43466.16 0.00 00010050.69 12 15022.10 107.00 267.41 6924.39 6813.52 -8910.46 12.10 354.0011211.08 13 15142.10 107.00 267.41 6889.31 6808.34 -9025.10 0.00 0.00 11301.34 14 15344.78 94.21 277.57 6851.99 6817.34 -9223.43 8.00 140.9411467.94 15 15739.08 94.21 277.57 6823.05 6869.17 9613.23 0.00 0.0011815.23 S-200AKtupUanl '., BOA Dip Pn Pzin11¢bTnw NOM uavrea<wnn:tl.s \��I{I/Y/�♦ snenpns)ab6.osi pe. Dabl-,,, nbdM.eocxuo' WELLBORE DETAILS: Plan S-20Av4.0 i REFERFRCEWR8t4TIDN Parent Wellbore: S -200P81 Coodnae,(WE) Refe Well S-200, True Neth Tie on MD: 2703.34 Verticd(FVD)Me= 5200A@8M5us4(d,r) Section (VS) ReferSlot (GOON , OOE) Measured Depth Refer S 2004 @ 83 05us4 (rpp) Calculation Method: Minimum CurvaNre CASING DETAJLS TVD MD S�6-25 2713.05 2734,6/6 5urface Cas? 9 6823.0514532.38 miermedata Cas in, 6823.05157391081 Productbn Liner4 OOAFauI1NG 4112 Production Lincr 5-2004 Geo Polp 71311 90% 7" Intermediate Casing - 6500 - S-20VA lin Csg _ S -200A Faullk3 515II',S-200AFau1m5 q S-20UiACasing Point Wy52W C 7 S-200AFaL111N4 4 s 0 4sw h c I +3900 - --. S-200AFaultN2 51..3250. ^26(10 ti 51930 O � 5-200A SVI Poh gon 650_ _ S -200A Fault# I g '_ I _ � T 95/8"Surface Cusmg "50 -10400 -9750 AlW -84311 -7800 -7150 65W -5850 -3200 4350 -3500 -1250 -26W -1950 -1300 650 U West( -)/East(+) (650 usfttin) ANNOTATIONS TVO MD Annotall n 2683.94 2703.34 TIP 2713.05 2734.76 KOP _____._ ___. 2727.83 275076 Start20A0 holdat275076MD TIP 27KOP 00 SV 3 p00 95/8"Surface Casing' SV2 Il - Start 3150 _ 01JASV 5 Polygon 18 01) _ L ` ➢8 Start DLS 350 TFO-9218 o ' ��SfuV;;11I -t 5-_OUA SVI Polygon { N 4050 _UG3. o I > h 450&UGI? o SwDLS3.5OTFO-136.IS i NIA \ I SwtDLS 1210TF035400 y 4950- G. pg ` Start DLS R 00 TFO 14094 41 Q 54110 F BASE � o ed 0 0 11 0 �. ry �G3CM2 017TLBKT 1j�SI ^cxtP[{11y�?t'4.__� I._. M 'TD aI 1573908 �+ 6750 720 }- - t i -.__ 1.- S2W A Landing Point r� 7650 - �� 1 S 2004 K C Sand /2 ProducllonLmor 0 350 1100 1650 22W 2750 330 3850 4400 4950 5500 6050 660 7150 770 SM0 8800 9350 990 10450 HOW 11350 12100 12650 Vertical Section at 305.55° (550 usft/in) 2746.29 2770.76 Start DLS 3.00 TFO 18.00 3871.14 4515.44 Start 100.00 hold at 4515A4 MD 3898.66 4615.44 Start DLS 3.50 TFO-92.18 4084.30 5290.95 Start 8013.17 hold at 5290.95 MD 622136 13304.13 Stad DLS3.50TFO-136.18 6743.92 1440927 Start 120.00 hold at 1440927 MD 6821.05 1452927 Start 20.00 hold at 1452927 MD 6833.91 14549.27 8W DLS 12.10 TFO 354.00 6924.39 15022.10 Start 120.00 hold at 15022.10 MD 6889.31 15142.10 Stan DLS 8.00 TFO 140.94 6851.99 15344.78 Stan 39430 hold at 15344.78 MD 6823.05 15739.08 TD at 15739.08 SURVEYPROGRAM Dab:2016-02-04T0090:00 Validated:Yes Version: Depth From Daplhio SuneyA4at Tool 133.53 270334 &" #1 MND(6-200PB1) IAWD 270334 340040 S-2DOAwpO8A (PlanS-200Av4A (S503A)) GYRO-WDSS 3400.00 14532.00 S-200AwpO8A(Plan S-200Av4.0(86034)) MWD 3400.00 14532.00 S-200Awp08A (Ran S-20Av4.0 (&WM)) WNDdFR+MS 1453200 15739.00 S-200Awp0&A (Plan6-2(ii (S503A)) MWD 1453200 15739.OB s-200AwpoaA (Ran S-200Av4.0 (,5034)) kmD+FR+MS • • 270 300 2703 2735 2735 2800 2800---- 3600 3600 9800 11400-14442 14442 - 15652 Ompnta - - Proay 51 ANTI-COLLISN SETTINGS BAKER , bt PB 5 d ._- 4 GL cOr;xny e. E4�pOcalConicOOM l We 1: S- 0 I :MDiterval25.00 Plan S-136/Platt S-136/Plan #7 S-136 Sec NIS MD Mc Ae WD * +EI Dk0 T1414 VSed Ta 1 15739.08 0.00 216D2 904 227.79 3 2750.]6 2257 315.91 272743 163.49 -17056 1250 90.00 23384 shRnld, Results B 769.27. 0.00 24137 18.00 140490 6 4015.44 7403 331.65 38-.fifi 131097 896.13 0.00 Wellbore: PIan S-200Av4.0 (S -503A) Reference: Plan S.20OAwpO8A(S-200/Plan S-20OAv4.0 (S -503A)) 82.18 211].16 8 13304.13 7453 307.08 6221.36 6455.95 447758 0.00 9 1440927 5000 272.66 6743.92 6810A0 835903 3.50 Plan: S -200A wpOBA (S-200/PIan S-20OA v4.0 10 14529.2] 111 272.69 6821.05 681470 845095 0.00 11 1454927 50.00 27288 6833 91 6815.42 8466.16 000 0.001083792 S-200A7in Cs9 000108-98 12 15022.10 107.00 267.41 692439 681352 8910A612,10 354.W11211D8 13 15142.10 107.- 267.41 6889.31 6608.]4 8025.10 0.00 14 15344.78 9421 277.57 665199 681734 A223.43 8.00 WELLOETAILS: 5400 15 1573908 9421 277.57 6623.05 6869.17 9613.23 0.00 O.W11e1523 6-2WAKupC6end Depth From Depth To Survey/Plan Tool Ground Laval: 133.53 2703.34 Survey#1 MWD(5-200PB1) MWD 2703.34 3400.00 30.10 3400.00 14532.00 S-20OAwpO8A(Plan S-20OAv4.Ory�-MS-WOCA .w.8 1Fj.W mod" Faslinp lJtltlltde Lal17-b am 15739.00 S-200Awp08A(PIan S-20OAv4.0 (S-503A))MWD 14532.00 010 0.00fsoo6o4.000 610930100 70.2l'10A070 149'2'2.071W From Colour TO MD 240 \ 270 300 2703 2735 2735 2800 2800---- 3600 3600 9800 11400-14442 14442 - 15652 Ompnta - - X993190 BAKER , UGHES k 4 GL cOr;xny e. E4�pOcalConicOOM SECT -DETAILS Plan S-136/Platt S-136/Plan #7 S-136 Sec NIS MD Mc Ae WD * +EI Dk0 T1414 VSed Ta 1 1 2703.34 212] 311.79 268384 151.33 -15737 O.W 2 2734.]6 22A 31189 271305 159.21 -15620 2.29 0.00 216D2 904 227.79 3 2750.]6 2257 315.91 272743 163.49 -17056 1250 90.00 23384 4 27]0.76 2257 316.91 274629 169.10 -17593 0.00 5 4515.41 74D3 331.65 3871.14 1226.26 450.47 3.00 0.00 24137 18.00 140490 6 4015.44 7403 331.65 38-.fifi 131097 896.13 0.00 000 149123 7 52-85 74.53 30708 4064.30 1799.85 4316.03 3.50 82.18 211].16 8 13304.13 7453 307.08 6221.36 6455.95 447758 0.00 9 1440927 5000 272.66 6743.92 6810A0 835903 3.50 Dee W3736 -136.1610]60,61 10 14529.2] 111 272.69 6821.05 681470 845095 0.00 11 1454927 50.00 27288 6833 91 6815.42 8466.16 000 0.001083792 S-200A7in Cs9 000108-98 12 15022.10 107.00 267.41 692439 681352 8910A612,10 354.W11211D8 13 15142.10 107.- 267.41 6889.31 6608.]4 8025.10 0.00 14 15344.78 9421 277.57 665199 681734 A223.43 8.00 O.W 1130134 140.941146194 15 1573908 9421 277.57 6623.05 6869.17 9613.23 0.00 O.W11e1523 6-2WAKupC6end )8/S-108 �.. A-vowall - 8 12447�) "X "' 3T4H01 :14714 ' 12745 , 3 93 -14615 S -107/S -107/S-107 270 30 330 4 / 35 30 300 / , 25 60 20 j 15 S-200Awp08A 10�� 4 „015 15 20 25 240 .. 1 120 32 ' '3 15069 30 � 35 P 90 .Ian S-136/ . an S-136/Plan #7 S-136 S-200/5-200PQt/S-20OP61 1502(% 40 S -200/S -200/S-200 210 45 150 50 180 Azimuth from North [°] vs Centre to Centre Separation [8 usft/in] 0 X993190 240 146 4036 138 1 4 6 120 14364 ' L9 140391425 Plan S-136/Platt S-136/Plan #7 S-136 1 i 1 , 1 _ 210' 5 S-200/S-200PB1/S-200PB1 5-213/S-213AL1-0t/S-213AL1-0t - - S-213/S-213A/S-213A 180 S -213/S -213/S-21 S-213/S-213AL2/S-213AL2 Azimuth from North [o] vs Centre to Centre Separation [25 usft/in] SURVEY PROGRAM Date: 2016-02-04TOO 0000 Validated. Yes Version'. Depth From Depth To Survey/Plan Tool 133.53 2703.34 Survey#1 MWD(5-200PB1) MWD 2703.34 3400.00 3400.00 S-200Awp08A/1PIan 6-20OAv4.0 -55003A1)GYRO-WD-SS 1453200 S-200Awp08A(Plan S-200Av4.0 (S503A))MWD 3400.00 14532.00 S-20OAwpO8A(Plan S-20OAv4.Ory�-MS-WOCA 14532.00 15739.00 S-200Awp08A(PIan S-20OAv4.0 (S-503A))MWD 14532.00 15739.08 S-20OAwpO8A (Plan S -200A v4.0LjW .MS-WOCA 270 30 330 4 / 35 30 300 / , 25 60 20 j 15 S-200Awp08A 10�� 4 „015 15 20 25 240 .. 1 120 32 ' '3 15069 30 � 35 P 90 .Ian S-136/ . an S-136/Plan #7 S-136 S-200/5-200PQt/S-20OP61 1502(% 40 S -200/S -200/S-200 210 45 150 50 180 Azimuth from North [°] vs Centre to Centre Separation [8 usft/in] 0 TOP OF ROTARY TABLE CHOKE UNE: 3-1/8' 5M FLANGED MANUAL GATE VALVE 3-1/8' 5M FLANGED HYDRAULIC GATE VALVE 3-1/8' 5M FLEX HOSE CELLAR AND WELL HEAD CONFIGURATION ARE FOR REFERENCE ONLY h ARE DEPENDENT ON OPERATOR'S REQUIREMENTS NIPPLE UP: SPACER SPOOL 13 5/8' 5M FLANGE TOP 13 5/8' 5M FLANGED BOTTOM SPACER SPOOL 13 5/8' 5M FLANGE TOP 13 5/8' 5M FLANGED BOTTOM DOUBLE STUDDED ADAPTER 13 5/8' 5M FLANGED TOP 11' SM FLANGED BOTTOM CASING SPOOL ASSEMBLY 11' 5M FLANGED TOP 11' 5M FLANGED BOTTOM CASING HEAD ASSEMBLY 11' 5M FLANGED TOP 6012 BOP STACK (?RAFT FLOWBOX BELL NIPPLE: 12' DM. PIPE SEAL WELDED TO THE BOTTOM OF THE FLOWBOX 30-3/8' INNER DIA TRIPLE INFLATABLE RUBBER SEAL WELL BELL NIPPLE: 16' DIA UPPER. 18' DIA LOWER 3' CASING FILL OUTLET (QTY OF 2) 13 5/B' 5M BOTTOM LTTE FLANGE 16' KEMPER SEAL -0 -GRIP (1 EA) 3' DIA STD. OUTLET (1 EA) 2' DIA STD. OUTLET DUTCH LOCK DOWN FLANGE ANNULAR BOP: 13-5/8' 5M SHAFFER LXT 13-5/8' 5M STUDDED TOP 13-5/8' SM FLANGED BOTTOM RAM TYPE BOP: 13 5/8' 5M NOV 6012 DOUBLE BOP 13 5/8' 5M STUDIED TOP 13 5/B' 5M FLANGED BOTTOM W/ 3-1/2' MANUAL LOCKS W/ 11' BOOSTER DRILLING CROSS: 13 5/8' 5M STUDDED TOP 13 5/8' 5M FLANGED BOTTOM W (2) 3 1/8' 5M SIDE OUTLETS KILL LINE: 2-1/16' 5M FLEX HOSE 2-1/16' 5M X 3-1/8' 5M D.SA 3-1/8' 5M FLANGED MANUAL GATE VALVE 3-1/8' 5M FLANGED HYDRAUUC GATE VALVE RAM TYPE BOP: 13 5/8' 5M NOV 6012 SINGLE BOP 13 5/8' 5M STUDDED TOP 13 5/8' 5M FLANGED BOTTOM • YEAR ELEVATION COMMENTS 2016 36.48 MARKED WITH YELLOW PAINT NOTES 1. VERTICAL DATUM IS BP MSL. 2. BASIS OF VERTICAL ELEVATION: MON S-4; ELEV. = 36.64' 3. BASE FLANGE ELEVATIONS ARE OBTAINED DURING A COMPREHENSIVE WELL -BORE SUBSIDENCE PROGRAM BASED ON LOCAL CONTROL CONFIRMED THROUGH STATIC SATELLITE OBSERVATIONS. v 200 r S PAD VICINITY MAP NTS ,M • ,7 Air ,° 0thy F. rnhart 10200 eSS I ONPL q SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS AS -BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF AJNE 05, 2016. UNAMN: --- DRAPER .�..�.�®__........._. CHECKED: �*ar�, +r h engineers HACKLEMAN ilrf -Zi �J — - SUPYeyOft °A�`03 5 18 i'� p �.,. .-T.. ORANtFMA;7 iS BFf S -P _ ---SHEET.__. JOB NO:----- -• WOA — S PAD WELL 200 oo f5 1 ISSUED FOR INFORMATON � ENOT TO SCALE BASE FLANGE ELEVATIONS 1 O 1 NO. oA7E RE`ASIOY I BY ICHKI S PAD VICINITY MAP NTS YEAR ELEVATION COMMENTS 2011 36.76 MARKED WITH YELLOW PAINT 2013 36.63 MARKED WITH YELLOW PAINT NOTES 1. VERTICAL DATUM IS BP MSL 2. BASIS OF VERTICAL ELEVATION: MON S-4; ELEV. = 38.64' 3. BASE FLANGE ELEVATIONS ARE OBTAINED DURING A COMPREHENSIVE WELL -BORE SUBSIDENCE PROGRAM BASED ON LOCAL CONTROL CONFIRMED THROUGH STATIC SATELLITE OBSERVATIONS. NOT M SCALE SURVEYOR'S CERTIFICATE 'HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS AS -BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF OCTOBER 13, 2013. Obp___ WOA - S PAD S" WELL 200 BASE FLANGE ELEVATIONS TOv1 S -PAD N 1100 -- O M �2O N N NN v1 zn vro) N 1010 _ . _■■ate ■■■■■�■■■■■. - -� ■-- ��µ� N;I�,7rmOfOO�NO.-tn I�� N d� M N I I I I I I nto I I I_I I 1 1 1 1 1 77 1 1 I 1 I fn In NVl iVl Nln (n (n inNVINN Nin (n 111 to to to N 840 ---- I CL � TANK ow LEGEND ,n O Q X �0 1 RENAMED AS -BUILT CONDUCTOR <1�1a i zo EXISTING CONDUCTOR S-200 _'-201, S-213 & S-216 RENAM THIS AS -BUILT DRAWING IS A REISSUE OF PREVIOUS AS -BUILT DRAWINGS FOR WELLS S-200, S-201 S-213 AND S-216. S-200 WAS PREVIOUSLY ISSUED AS WELL SB -01 ON 11/13/97. S-201 WAS PREVIOUSLY ISSUED AS SLOT 19 ON 10/05/00. S-213 WAS PREVIOUSLY ISSUED AS SLOT 3 ON 7/04/00. S-216 WAS PREVIOUSLY ISSUED AS SLOT 1 ON 11/29/00. 1 1 t 1 1 1 1 1 1 t. 1 ■ 1 . . 1 . 1 . . . . . . . . . . . . . NOTES: 1. DATE OF SURVEYS: (S-200 11/12/1997) (S-201 10/03/2000) (S-213 7/02/2000) (S-216 11/28/2000) 2. REFERENCE FIELD BOOKS: (S-200 Wo97-01 PGS. 45-46) (S-201 WOOD -11 PGs. 18-20) (S-213 WoOO-06 PGS. 1-4) (S-216 WOOD -10 PG. 50) 3. COORDINATES ARE ALASKA STATE PLANE, ZONE -4 NAD 27. 4. GEODETIC COORDINATES ARE NAD -27. 5. MPU S -PAD AVERAGE SCALE FACTOR IS: 0.9999165. 6. HORIZONTAL CONTROL IS BASED ON MONUMENTS S-3 & S-4. (HELD S-4) 7. BASIS OF VERTICAL CONTROL IS OPERATOR MONUMENTATION. ELEVATIONS ARE BP EXPLORATION MEAN SEA LEVEL DATUM. 27 26 25 S PAD �1 34 i ?g Q PROJECT AREA l� T.12N, 3 11IN 2 VICINITY MAP N.T.S. OF C-1 . y e°49ai ei�JreJ. Catton , SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JANUARY 31, 2000. LOCATED WITHIN PROTRACTFD SFC_ .35 T 19 N R 19 F uMIAT mrpiniAN A, AcuA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS S-200 Y=5,980,504.88 • N. 1,010.30 70'21'19.407" 70.3553907' 36'1 4,301' FSL X= 618,930.26 • E. 350.08 149'02'02.971"' 149.0341587' 4,500' FEL S-201 Y=5,980,789.92 N. 1,010.07 70'21'22.210" 70.3561694' 35.9' 4,587' FSL X= 618,929.93 E. 65.01 149'02'02.849" 149.0341247' 4 496' FEL S-zi3 Y=5,980,549.84 N. 1,010.01 70'21'19.849" 70.3555136'4,347' 359'' FSL X= 618,929.96 E. 305.12 149'02'02.959" 149.0341554' 4,501' FEL S-216 Y=5,980,520.26 N. 1,009.75 70'21'19.558" 70.3554328' 36.0' 4,'317' FSL X= 618,929.71 E. 334.70 149'02'02.980" 149.0341611' 4,501' FEL _ F. Rot ert °ftnW ` jic CHECK D: RSA . ._.�� JA E . _ - io _�03R s WOA S -PAD _._1t107t!!oA {� --- - - RENAMED AS -BUILT CONDUCTORS 0 ti T6 kSS Mo"Al" JXC RFA - 1'= 150' WELL S-200, S-201 S-213 & S-116 OF N0. DATE RE"slom BY c I � S SSV -XIT 666.75 I r 1467.61 333.(5 4.06 ;V EXIT A 1/16-5000 (R-39( 1 - TEST PORT TEST PORT IO LOCKDOWN SCREWS --11-5000 (R-54) _ �2 1/16-5000 MOD 20 GV 22.75 577.85 9.15 232.41 N TEST PORT 10 LOCKDOWN SCREWS II -5000 (R-54) 1/16-5000 MOD 120 GV REF:DMi0004-1348 r` 002DM1080698 l9 O s -II R DM 1001 Ob71 i AP ITEM ISP AR` NUMBER DESCRIPTION I 13-300-030 DIVERTER LANDING RING 2 P138322-0005 9 5/8 CASING HANGER 3 P172070 SLIP -IN LANDING RING 4 P164819 CASING HEAD ASSEMBL" 5 13-300-718 GEN 5 TUBING HEAD ASSEMBLY 6 P123277-0002 7 CASING HANGER 20" OD CASING 12-'. 50-016 7 PACKOFF ASSEMBLY, 8 P156963 TUBING HANGER ASSEMBLI 902-047-619 TUBING HEAD ADAPTER ASSEMBLY 9 5/8-21 .,ASING HANGER 9 5/8" GO CASING IOI I18334�5 P 000 NIP 12 12-093-N2—J z C-2' EASING HANGER_ 7'00 CASING �'---- 4 1/2" 00 CASING LSU L A 2 K a ANCHC)RAG�-, A 20 X 9 5/8 X 7 X 4 1/2 Pfl IVATE ANO CONPIBENTIAL UNLESS GTUER—C SPECIFIED I REVISIONS IDESCRI-- I. oo No - -PIs ORA.- TOLERANCE 1 03- ONI III N -11 J. HN EAES : GENERAT ICON 5 WELLHEAD •�*��^ gGE5 .O15M— -�.ms .005 -11EIEDEA S+O 20 X 9 5/8 X 7 x 4 l2 o 6. DS 10 CONFORU a - nNaE-'so' 1 -5000 COMPLETI ON - 1. ILIMRILT IST STRAOOL NISR-zs� REF:DMi0004-1348 r` 002DM1080698 l9 O s -II R DM 1001 Ob71 i 28.3' -- 4 1/.6-5000 i i 1 O ® 4 I/16-5000 MOD 120 GV 1 p Q I O 'III I o I 92.'25 �-4 1/16-5000 MOD 120 GV o -4 1/16-5000 MOD 120 GV ACTD ® O I SOi O,O i i I I 1 O O -14 1/16-5000 MOD 120 GV I 1 PRIVATE AND CONFIDENTIAL REvis IONS DESCRIPT.ON MnRGUEZ UB -D -'MCT2 hno1 125 4 1/16-5000 TREE og Null Me ROUEZV W W/ 4 1/16-5000 WING o MuroNw Da -m -as u �oN oa-o.-os D M I O Q 023 00 7 Loepp, Victoria T (DOA) From: Gorham, Bradley M <Bradley.Gorham@bp.com> Sent: Tuesday, October 03, 201710:51 AM To: Loepp, Victoria T (DOA) Subject: RE: PBU S-200A(PTD 217-125) 5, ko tf u� 5x1 Le(Mvry a� yp0� Victoria, This log has nothing t�do with the S -200A intermed' to casing. The IBC log is planned for the exis g 7 -"casing in the 5- 200 wellbore. In order to drill the p anne - A well, we need to cut and pull the existing S-200 7" casing. The IBC log is being run to confirm there is no cement or cement stringers behind the existing s-200 7" casing that would prevent us from pulling the casing down to our planned kick off depth of 2,734' MD. As for the planned well of S -200A, if we do not meet our zonal isolation requirements based on lift pressure, we have the contingency to run an IBC or USIT to verify that we have adequate zonal isolation. This would be communicated to you at a later date if that scenario does indeed occur. Please call me if you have any further questions, Brad Brad Gorham BP Exploration (Alaska), Inc. Drilling Engineer W: (907)564-4649 C: (907)223-9529 Bradley.Gorham@bp.com From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, October 3, 201710:42 AM To: Gorham, Bradley M <Bradley.Gorham@bp.com> Subject: RE: PBU S-200A(PTD 217-125) Bradley, Why isn't the cement evaluation log run right after cementing the 7"? Will the log be run to the 7" shoe? Are you looking for TOC primarily or cement quality from the shoe? Thanx, Victoria From: Gorham, Bradley M [mailto:Bradley.Gorham@bp.com] Sent: Tuesday, October 03, 201710:07 AM To: Loepp, Victoria T (DOA) <victoria.Ioepp@alaska.gov> Subject: RE: PBU S-200A(PTD 217-125) Victoria, The IBC log that we are running to eluate at which depth the existing 7" casin90free is essentially the same exact log as a USIT. It is a log that fully characterizes the annular environment (fluids and cement) and gives us more detail and a better understanding of what we have behind our casing when compared to a USIT. Let me know if you need any other information or have any other questions. Thanks, Brad Brad Gorham BP Exploration (Alaska), Inc. Drilling Engineer W: (907)564-4649 C: (907)223-9529 Bradley.Gorham@bp.com From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, October 3, 2017 9:00 AM To: Gorham, Bradley M <Bradley.Gorham@bp.com> Subject: PBU S-200A(PTD 217-125) Bradley, What is the "IBC log" that will be used to verify the intermediate casing TOC? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp aaalaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.LoerDp@alaska.gov 17J Davies, Stephen F (DOA) From: Lastufka, Joseph N <Joseph. Lastufka@ bp.com > Sent: Wednesday, September 6, 2017 11:24 AM To: Davies, Stephen F (DOA) Subject: FW: PBU S -200A Mud Program Discrepancies Steve, Sorry for the confusion, please see Brad's note below and let me know if you need any additional clarification. Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 BP Exploration Alaska1900 E. Benson Blvd.lRoom: 788DIAnchorage, AK From: Gorham, Bradley M Sent: Wednesday, September 6, 2017 11:04 AM To: Lastufka, Joseph N <Joseph.Lastufka @bp.com> Subject: RE: PBU S -200A Mud Program Discrepancies Joe, The mud program outlined on page 8 is the correct one. The one of page 4 is simply a typo. Let me know if there is any other clarification needed. Thanks, Brad From: Lastufka, Joseph N Sent: Wednesday, September 6, 2017 10:57 AM To: Gorham, Bradley M <Bradley.Gorham@bp.com> Subject: FW: PBU S -200A Mud Program Discrepancies Brad, Could you please answer Steve's question? Thank you, Joe Lastufka 1 Information and Data Controlll • Cell: (907) 227-84961 Office: (907) 564-4091 ---------------------------------------------------------------------------------------------- i' BP Exploration Alaska1900 E. Benson Blvd.lRoom: 788DIAnchorage, AK From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Wednesday, September 6, 2017 10:43 AM To: Lastufka, Joseph N <Joseph.Lastufka @bp.com> Subject: PBU S -200A Mud Program Discrepancies Hi Joe, The depths and mud weights listed in the mud programs on pages 4 and 8 of the PBU S -200A Permit to Drill application do not match. Which ones are correct? Thanks, 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.davies@alaska.gov. From: Lastufka, Joseph N [mailto:Joseph.Lastufka@bp.com] Sent: Tuesday, September 5, 2017 2:05 PM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov>; Bettis, Patricia K (DOA) <patricia.bettis@alaska.gov> Subject: S -200A Directional Survey Steve, This Permit to Drill will be delivered this afternoon. Please let me know if you need anything else. Thanks, Joe 2 AOGCC Permit to Drill No. 217-125 6 September 2017 INPUT OUTPUT Geographic, NAD27 State Plane, NAD27 5004 - Alaska 4, U.S. Feet Latitude: 70 21 19.407 Longitude: 149 02 02.971 PBU S -200A 1/1 Northing/Y: 5980504. 914 Easting/X: 618930.274 Convergence: 0 54 34.68711 Scale Factor: 0. 999916068 Remark: Corpscon v6.0.1, U.S. Army Corps of Engineers • • Well: PBU S -200A <== Data Input Name: BP < Data Input Mud Weight (ppg) 11.10 Data Input Weak point or LOT - Measured depth (ft) 2,734' — Data Input Weak point or LOT True vertical depth (ft) 2,683' — Data Input Weak point or LOT - Hole angle (deg) 22.00 — Data Input Weak point or LOT - Hole size (in) 9.625" <-= Data Input Weak point pressure or LOT -EMW (ppg) 13.40 — Data Input Zone of interest - Measured depth (ft) 14,259' — Data Input Zone of interest - True vertical depth (ft) 6,650' — Data Input Zone of interest - Hole angle (deg) 54.00 — Data Input Zone of interest - Hole size (in) 9.875" — Data Input EL,jZone of interest - Pore pressure EMW (ppg) 9.20 — Data Input Gas gradient (naltit) 1 0.10 1 <== nata Innut Bottom hole assembly OD (in) 8A W. — Data Input Bottom hole assembly length (ft) 151' — Data Input Drill pipe OD (in) 5.000" — Data Input BHA annular vol. @ zone of interest (bbl/ft) 0.0326 DP annular vol. @ zone of interest (bbl/ft) 0.0704 DP annular vol. 90 weak point (bbl/ft) 0.0657 — Data Input Weak point pressure (psi): PIO 1,870 psi Weak point pressure - Safety margin: VPmax Pmax EMW 1,870 psi 13.40 ppg Max anticipated formation pressure (psi): Pf j,181 psi Weak Pt to Zone of Interest distance (TVD ft): OH {TVD) 3,967' Weak Pt to Zone of Interest distance (MD ft): OH {MD) 11,525- 1,525Maximum Maximuminflux height at the bit (TVD ft): H {TVD} 2,049' Maximum influx height at the bit (MD ft): H {MD} 3,486- ,486Calc. Cale.volume of (H) around BHA: Calc. volume of (H) around drill pipe: Calc. volume that H equals @ initial shut in: V1 bha V1 dp V1 4.9 bbl 235.0 bbl 239.9 bbl Calc. vol. that H equals @ weak point (MD ft): VwP 145.2 bbl Calc. volume of Vwp @ initial shut in: V2 85.3 bbl Kick Tolerance: V2 85.3 bbl V Loepp 1015/17 TRANSMITTAL LETTER CHECKLIST WELL NAME: Z/ /Development _Service _Exploratory _ Strahgraphic Test _Non -Conventional FIELD: POOL: 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 through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, AURORA OIL_- 640120 Well Name: PRUDHOE BAY UN POL S -200A Program DEV Well bore seg ❑ PTD#: 2171250 Company BP EXPLORATION (ALASKA) INC. Initial Class/Type DEV/PEND —GeoArea 890 Unit 11650 _ On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31.05.030Q.1_.A),Q,2.A-D) - - - - - - - - - - - - - - NA_ - - _ - - - - - - - - - - - - - - - - - - - 1 Permit fee attached - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 2 Lease number appropriate- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - Surface Location lies within AD_L0028257, Portion of Well Passes Thru ADL0028258;_ _ 3 Unique well name and number - - - - - - - - - - - - - - - - - - -- - - - - - - - - - Yes -- _ _ _ Top -Prod- Int_& TD he within_ADL0028256. - - - - - - - - - - - - - - - - - - - - - - - - - - - 4 Well located in -a_ defined -pool - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - PRUDHOE BAY, AURORA -OIL - 640120, governed by CO 4576_- Corrected_ 5 Well located proper distance from drilling unit_bound-ary----------------- - Yes - - - - Rule 1:_"Spacing units within the -pool shall -be aminimum of 40 acres.- 20_AAC 25,055(-a)(1) _ _ 6 Well located proper distance from other wells_ - - ---- Yes - - - - - - - and -(2) shall—riot apply to property lines within the external boundaries of the Aurora_ 7 Sufficient acreage -available in -drilling unit- - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - Participating_ Area." As planned, this well will conform to spacing_ requirements. _ _ - - - 8 -if deviated, is_ wellbore plat_included____ Yes ----------------------------------------- 9 Operator only affected party - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 10 Operator has -appropriate bond in force - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 11 Permit can be issued without conservation order_ - - - - -- - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - _ - - - _ _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 12 Permit can be issued without administrative approval - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - SFD 9/6/2017 13 Can permit be approved before 15 -day wait_ - Yes - - - - - - - - - - - - - - - - - - - - - - - - - 14 Well located within area and -strata authorized by Injection Order # (put 10# in_comments)_(For_ -NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 15 All wells -within -1/4 -mile -area -of review identified (For service well only) - - - - - - - - - - - - - - N_A_ _ _ _ _ _ - - - - - - - - - - - - - - - _ _--------------------------------- 16 18 Pre -produced injector. duration of preproduction less than 3 months_(For_service well only) - Conductor string- provided --------------------------------- ----- - NA- N_A_ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ----- Con_ductorset-in PBUS-200--- - Engineering 19 Surface casing_ protects all -known- USDWs - - - - - - --------------- --------- NA_ _ _ - _ _ - Surface casing set in PBU $-200 - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 20 CMT_ vol_ adequate_ to circulate -on conductor _& surf _csg - - - - - - - - - - NA_ _ _ - - - Surface casing set and fully cemented 21 CMT_ vol _adequate _totie-inlongstring to -surf csg_ ----__ NA-------------------------------------------------------------- 22 CMT will coverall known -productive horizons_ - - - - - - - No - - - - - Productive interval will be completed with_ uncemented sliding_sleeves w/ swell -packers_ _ - - - 23 Casing designs adequate for CJ, B &_ permafrost_ - - - - Yes---------------------- _ - _ - - - - - - - 24 _Adequate tankage or reserve pit - - - - - - - Yes - - - - - - - Rig has steel tanks; all waste -to approved disposal wells 25 If a re -drill, has_a 10-403 for abandonment been approved -- - - - Yes - - - - - - _ PTD 197439, -Sundry 317-380_ 26 Adequate -wellbore separation proposed - - - - - - - - - - - - - - - - Yes - - - - - - - Anti -collision analysis complete;S-107A fails -major risk -SI WJ TT plug& wing & swab LOTO 27 If_diverter required, does it meet regulations_ - - - - - - - - - - - - - NA _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 28 -Drilling fluid program schematic_& equip list adequate- - - - - - - - - - - - - - -- Yes Max formation pressure is 3279 psig(9.2 ppg EMW); will drill w/_9.3-11_.1 ppg EMW VTL 10/3/2017 29 _B_O_PEs,_dothey meetregulation - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ _ - 30 BOPE_press rating appropriate; test to -(put psig in comments)- - Yes - - - _ MPSP is 2594 psig, will test BOPs-to 3500si P- 9 31 Choke manifold complies w/API_ RP -53 (May 84) - - - - - - Yes -- --- 32 Work will occur without operation shutdown_ - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 33 Is presence of H2$ gas probable _ Yes - - - - - - - H2S measures required - - - - - - - - - - - - - - - - - 34 35 Mechanical -condition of wells within AOR verified (For service well only) - - - - - - - - Permit can be issued w/o hydrogen_ sulfide measures - - - - N_A_ N_o - - - - - - - H2S reported for wells_$ -213A and $-201 (19 and 180 ppm, respectively). Geology 36 Data -presented on potential overpressure zones - - - - - - - - - - - - - - - - Yes _ - - - - - Planned drilling mud program_ appears adequate to control operator's forecast pore pressure gradient. Appr Date 37 Seismic -analysis of shallow gas -zones ---------- - - - - - - - - - - - - - - - - NA_ - - - - - - Should higher -pore- pressures be encountered, BP has access to_fluid_mixing facilities within_ SFD 9/6/2017 38 Seabed condition survey _(if off_ -shore)----- - - - - - -- - - - - - - - - - - - - - - N_A_ the PBU------------------- _ - _ - _ - - - - - 39 Contact name/phone for weekly_ progress reports [exploratory only] - - - - - - - - - - - - - - - - - NA_ _ _ _ Geologic Engineering Public Four projected fault crossings: two in intermediate section have low pentential for lost circulation; two in the Kuparuk reservoir Date: Date Date Commissioner: commissioner: Commissioner (one expected and one possible) have moderate potential. 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